Regulation (EU) 2022/869 of the European Parliament and of the Council of 30 May 2022 on guidelines for trans-European energy infrastructure, amending Regulations (EC) No 715/2009, (EU) 2019/942 and (EU) 2019/943 and Directives 2009/73/EC and (EU) 2019/944, and repealing Regulation (EU) No 347/2013

(9)For all projects not covered in point (8) of this Annex, the Commission shall evaluate the application of the criteria set out in Article 4 of this Regulation. The Commission shall also take into account the potential for future extension to include additional Member States. The Commission shall present its assessment to the Group. For projects applying for the status of project of mutual interest, third-country representatives and regulatory authorities shall be invited to the presentation of the assessment.

(10)Each Member State to whose territory a proposed project does not relate, but on which the proposed project may have a potential net positive impact or a potential significant effect, such as on the environment or on the operation of the energy infrastructure on its territory, may present an opinion to the Group specifying its concerns.

(11)The Group shall examine, at the request of a Member State of the Group, the substantiated reasons presented by a Member State pursuant to Article 3(3) for not approving a project related to its territory.

(12)The Group shall consider whether the energy efficiency first principle is applied as regards the establishment of the regional infrastructure needs and as regards each of the candidate projects. The Group shall, in particular, consider solutions such as demand-side management, market arrangement solutions, implementation of digital solutions, and renovation of buildings as priority solutions where they are judged more cost-efficient on a system wide perspective than the construction of new supply side infrastructure.

(13)The Group shall meet to examine and rank the proposed projects based on a transparent assessment of the projects and using the criteria set out in Article 4 taking into account the assessment of the regulators, or the assessment of the Commission for projects not falling within the competence of national regulatory authorities.

(14)The draft regional lists of proposed projects falling under the competence of national regulatory authorities drawn up by the Groups, together with any opinions as specified in point (10) of this Section, shall be submitted to the Agency six months before the adoption date of the Union list. The draft regional lists and the accompanying opinions shall be assessed by the Agency within three months of the date of receipt. The Agency shall provide an opinion on the draft regional lists, in particular on the consistent application of the criteria and the cost-benefit analysis across regions. The opinion of the Agency shall be adopted in accordance with the procedure referred to in Article 22(5) of Regulation (EU) 2019/942.

(15)Within one month of the date of receipt of the Agency’s opinion, the decision-making body of each Group shall adopt its final regional list of proposed projects, respecting the provisions set out in Article 3(3), on the basis of the Groups’ proposal and taking into account the opinion of the Agency and the assessment of the national regulatory authorities submitted in accordance with point (8), or the assessment of the Commission for projects not falling within the competence of national regulatory authorities proposed in accordance with point (9), and the advice from the Commission that aims to ensure a manageable total number of projects on the Union list, especially at borders related to competing or potentially competing projects. The decision-making bodies of the Groups shall submit the final regional lists to the Commission, together with any opinions as specified in point (10).

(16)Where, on the basis of the draft regional lists, and after having taken into account the Agency opinion, the total number of proposed projects on the Union list would exceed a manageable number, the Commission shall advise each Group concerned, not to include in the regional list projects that were ranked lowest by the Group concerned in accordance with the ranking established pursuant to Article 4(5).

ANNEX IV

(1)A project of common interest with a significant cross-border impact shall be a project on the territory of a Member State and shall fulfil the following conditions:

(a) for electricity transmission, the project increases the grid transfer capacity, or the capacity available for commercial flows, at the border of that Member State with one or several other Member States, having the effect of increasing the cross-border grid transfer capacity at the border of that Member State with one or several other Member States, by at least 500 Megawatts (MW) compared to the situation without commissioning of the project, or the project decreases energy isolation of non-interconnected systems in one or more Member States and increases the cross-border grid transfer capacity at the border between two Member States by at least 200 MW;

(b) for electricity storage, the project provides at least 225 MW installed capacity and has a storage capacity that allows a net annual electricity generation of 250 GW-hours/year;

(c) for smart electricity grids, the project is designed for equipment and installations at high-voltage and medium-voltage level, and involves TSOs, TSOs and DSOs, or DSOs from at least two Member States. The project may involve only DSOs provided that they are from at least two Member States and provided that interoperability is ensured. The project shall satisfy at least two of the following criteria: it involves 50 000 users, generators, consumers or prosumers of electricity, it captures a consumption area of at least 300 GW hours/year, at least 20 % of the electricity consumption linked to the project originates from variable renewable resources, or it decreases energy isolation of non-interconnected systems in one or more Member States. The project does not need to involve a physical common border. For projects related to small isolated systems as defined in Article 2, point (42), of Directive (EU) 2019/944, including islands, those voltage levels shall be equal to the highest voltage level in the relevant electricity system;

(d) for hydrogen transmission, the project enables the transmission of hydrogen across the borders of the Member States concerned, or increases existing cross-border hydrogen transport capacity at a border between two Member States by at least 10 % compared to the situation prior to the commissioning of the project, and the project sufficiently demonstrates that it is an essential part of a planned cross-border hydrogen network and provides sufficient proof of existing plans and cooperation with neighbouring countries and network operators or, for projects decreasing energy isolation of non-interconnected systems in one or more Member States, the project aims to supply, directly or indirectly, at least two Member States;

(e) for hydrogen storage or hydrogen reception facilities referred to in point (3) of Annex II, the project aims to supply, directly or indirectly, at least two Member States;

(f) for electrolysers, the project provides at least 50 MW installed capacity provided by a single electrolyser or by a set of electrolysers that form a single, coordinated project and brings benefits directly or indirectly to at least two Member States, and, specifically, as regards projects on islands and island systems, supports innovative and other solutions involving at least two Member States with a significant positive impact on the Union’s 2030 targets for energy and climate and its 2050 climate neutrality objective, and contributes significantly to the sustainability of the island energy system and that of the Union;

(g) for smart gas grids, a project involves TSOs, TSOs and DOS or DSOs from at least two Member States. DSOs may be involved, but only with the support of the TSOs of at least two Member States that are closely associated to the project and ensure interoperability;

(h) for offshore renewable electricity transmission, the project is designed to transfer electricity from offshore generation sites with capacity of at least 500 MW and allows for electricity transmission to onshore grid of a specific Member State, increasing the volume of renewable electricity available on the internal market. The project shall be developed in the areas with low penetration of offshore renewable electricity and shall demonstrate a significant positive impact on the Union’s 2030 targets for energy and climate and its 2050 climate neutrality objective and shall contribute significantly to the sustainability of the energy system and market integration while not hindering the cross-border capacities and flows;

(i) for carbon dioxide projects, the project is used to transport and, where applicable, store anthropogenic carbon dioxide originating from at least two Member States.

(2)A project of mutual interest with significant cross-border impact shall be a project and shall fulfil the following conditions:

(a) for projects of mutual interest in the category set out in point (1)(a) and (f) of Annex II, the project increases the grid transfer capacity, or the capacity available for commercial flows, at the border of that Member State with one or more third countries and brings significant benefits, either directly or indirectly (via interconnection with a third country), under the specific criteria listed in in Article 4(3), at Union level. The calculation of the benefits for the Member States shall be performed and published by the ENTSO for Electricity in the frame of Union-wide ten-year network development plan;

(b) for projects of mutual interest in the category set out in point (3) of Annex II, the hydrogen project enables the transmission of hydrogen across at the border of a Member State with one or more third countries and proves bringing significant benefits, either directly or indirectly (via interconnection with a third country) under the specific criteria listed in Article 4(3), at Union level. The calculation of the benefits for the Member States shall be performed and published by the ENTSO for Gas in the frame of Union-wide ten-year network development plan;

(c) for projects of mutual interest in the category set out in point (5) of Annex II, the project can be used to transport and store anthropogenic carbon dioxide by at least two Member States and a third country.

(3)Concerning projects falling under the energy infrastructure categories set out in point (1)(a), (b), (c), (d) and (f) of Annex II, the criteria listed in Article 4 shall be evaluated as follows:

(a) transmission of renewable energy generation to major consumption centres and storage sites, measured in line with the analysis made in the latest available Union-wide ten-year network development plan in electricity, in particular by: (i) for electricity transmission, estimating the amount of generation capacity from renewable energy sources (by technology, in MW), which is connected and transmitted due to the project, compared to the amount of planned total generation capacity from those types of renewable energy sources in the Member State concerned in 2030 according to the National Energy and Climate Plans submitted by Member States in accordance with Regulation (EU) 2018/1999; (ii) or energy storage, comparing new capacity provided by the project with total existing capacity for the same storage technology in the area of analysis as set out in Annex V;

(b) market integration, competition and system flexibility, measured in line with the analysis made in the latest available Union-wide ten-year network development plan in electricity, in particular by: (i) calculating, for cross-border projects, including reinvestment projects, the impact on the grid transfer capability in both power flow directions, measured in terms of amount of power (in MW), and their contribution to reaching the minimum 15 % interconnection target, and for projects with significant cross-border impact, the impact on grid transfer capability at borders between relevant Member States, between relevant Member States and third countries or within relevant Member States and on demand-supply balancing and network operations in relevant Member States; (ii) assessing the impact, for the area of analysis as set out in Annex V, in terms of energy system-wide generation and transmission costs and evolution and convergence of market prices provided by a project under various planning scenarios, in particular taking into account the variations induced on the merit order;

(c) security of supply, interoperability and secure system operation, measured in line with the analysis made in the latest available Union-wide ten-year network development plan in electricity, in particular by assessing the impact of the project on the loss of load expectation for the area of analysis as set out in Annex V in terms of generation and transmission adequacy for a set of characteristic load periods, taking into account expected changes in climate-related extreme weather events and their impact on infrastructure resilience. Where applicable, the impact of the project on independent and reliable control of system operation and services shall be measured.

(4)Concerning projects falling under the energy infrastructure category set out in point (1)(e) of Annex II, the criteria listed in Article 4 shall be evaluated as follows:

(a) the level of sustainability, measured by assessing the extent of the ability of the grids to connect and transport variable renewable energy;

(b) security of supply, measured by assessing the level of losses in distribution, transmission networks, or both, the percentage utilisation (i.e. average loading) of electricity network components, the availability of network components (related to planned and unplanned maintenance) and its impact on network performances, and on the duration and frequency of interruptions, including climate related disruptions;

(c) market integration, measured by assessing the innovative uptake in system operation, the decrease of energy isolation and interconnection, as well as the level of integrating other sectors and facilitating new business models and market structures;

(d) network security, flexibility and quality of supply, measured by assessing the innovative approach to system flexibility, cybersecurity, efficient operability between TSO and DSO level, the capacity to include demand response, storage, energy efficiency measures, the cost-efficient use of digital tools and ICT for monitoring and control purposes, the stability of the electricity system and the voltage quality performance.

(5)Concerning hydrogen falling under the energy infrastructure category set out in point (3) of Annex II, the criteria listed in Article 4 shall be evaluated as follows:

(a) sustainability, measured as the contribution of a project to greenhouse gas emission reductions in various end-use applications in hard-to-abate sectors, such as industry or transport; flexibility and seasonal storage options for renewable electricity generation; or the integration of renewable and low-carbon hydrogen with a view to consider market needs and promote renewable hydrogen;

(b) market integration and interoperability, measured by calculating the additional value of the project to the integration of market areas and price convergence to the overall flexibility of the system;

(c) security of supply and flexibility, measured by calculating the additional value of the project to the resilience, diversity and flexibility of hydrogen supply;

(d) competition, measured by assessing the project’s contribution to supply diversification, including the facilitation of access to indigenous sources of hydrogen supply.

(6)Concerning smart gas grid projects falling under the energy infrastructure category set out in point (2) of Annex II, the criteria listed in Article 4 shall be evaluated as follows:

(a) level of sustainability, measured by assessing the share of renewable and low-carbon gases integrated into the gas network, the related greenhouse gas emission savings towards total system decarbonisation and the adequate detection of leakage;

(b) quality and security of supply, measured by assessing the ratio of reliably available gas supply and peak demand, the share of imports replaced by local renewable and low-carbon gases, the stability of system operation, the duration and frequency of interruptions per customer;

(c) enabling flexibility services such as demand response and storage by facilitation of smart energy sector integration through the creation of links to other energy carriers and sectors, measured by assessing the cost savings enabled in connected energy sectors and systems, such as the heat and power system, transport and industry.

(7)Concerning electrolyser projects falling under the energy infrastructure category set out in point (4) of Annex II the criteria listed in Article 4 shall be evaluated as follows:

(a) sustainability, measured by assessing the share of renewable hydrogen or low-carbon hydrogen, in particular from renewable sources meeting the criteria defined in point (4)(a)(ii) of Annex II integrated into the network or estimating the amount of deployment of synthetic fuels of those origins and the related greenhouse gas emission savings;

(b) security of supply, measured by assessing its contribution to the safety, stability and efficiency of network operation, including through the assessment of avoided curtailment of renewable electricity generation;

(c) enabling flexibility services such as demand response and storage by the facilitation of smart energy sector integration through the creation of links to other energy carriers and sectors, measured by assessing the cost savings enabled in connected energy sectors and systems, such as the gas, hydrogen, power and heat networks, the transport and industry sectors.

(8)Concerning carbon dioxide infrastructure falling under the energy infrastructure categories set out in point (5) of Annex II the criteria listed in Article 4 shall be evaluated as follows:

(a) sustainability, measured by assessing the total expected project life-cycle greenhouse gas reductions and the absence of alternative technological solutions such as, but not limited to, energy efficiency, electrification integrating renewable sources, to achieve the same level of greenhouse gas reductions as the amount of carbon dioxide to be captured at connected industrial installations at a comparable cost within a comparable timeline taking into account the greenhouse gas emissions from the energy necessary to capture, transport and store the carbon dioxide, as applicable, considering the infrastructure including, where applicable, other potential future uses;

(b) resilience and security, measured by assessing the security of the infrastructure;

(c) the mitigation of environmental burden and risk via the permanent neutralisation of carbon dioxide.

ANNEX V

The methodologies for cost-benefit analyses developed by the ENTSO for Electricity and the ENTSO for Gas shall be consistent with each other, taking into account sectorial specificities. The methodologies for a harmonised and transparent energy system-wide cost-benefit analysis for projects on the Union list shall be uniform for all infrastructure categories, unless specific divergences are justified. They shall address costs in the broader sense, including externalities, in view of the Union’s 2030 targets for energy and climate and its 2050 climate neutrality objective and shall comply with the following principles:

(1) the area for the analysis of an individual project shall cover all Member States and third countries, on whose territory the project is located, all directly neighbouring Member States and all other Member States in which the project has a significant impact. For this purpose, ENTSO for Electricity and ENTSO for Gas shall cooperate with all the relevant system operators in the relevant third countries. In the case of projects falling under the energy infrastructure category set out at point (3) of Annex II, the ENTSO for Electricity and the ENTSO for Gas shall cooperate with the project promoter, including where it is not a system operator;

(2) each cost-benefit analysis shall include sensitivity analyses concerning the input data set, including the cost of generation and greenhouse gases as well as the expected development of demand and supply, including with regard to renewable energy sources, and including the flexibility of both, and the availability of storage, the commissioning date of various projects in the same area of analysis, climate impacts and other relevant parameters;

(3) they shall establish the analysis to be carried out, based on the relevant multi-sectorial input data set by determining the impact with and without each project and shall include the relevant interdependencies with other projects;

(4) they shall give guidance for the development and use of energy network and market modelling necessary for the cost-benefit analysis. The modelling shall allow for a full assessment of economic benefits, including market integration, security of supply and competition, as well as lifting energy isolation, social and environmental and climate impacts, including the cross-sectorial impacts. The methodology shall be fully transparent including details on why, what and how each of the benefits and costs are calculated;

(5) they shall include an explanation on how the energy efficiency first principle is implemented in all the steps of the Union-wide ten-year network development plans;

(6) they shall explain that the development and deployment of renewable energy will not be hampered by the project;

(7) they shall ensure that the Member States on which the project has a net positive impact, the beneficiaries, the Member States on which the project has a net negative impact, and the cost bearers, which may be Members States other than those on which territory the infrastructure is constructed, are identified;

(8) they shall take into account, at least, the capital expenditure, operational and maintenance expenditure costs, as well as the costs induced for the related system over the technical lifecycle of the project as a whole, such as decommissioning and waste management costs, including external costs. The methodologies shall give guidance on discount rates, technical lifetime and residual value to be used for the cost- benefit calculations. They shall furthermore include a mandatory methodology to calculate benefit-to-cost ratio and the net present value, as well as a differentiation of benefits in accordance with the level of reliability of their estimation methods. Methods to calculate the climate and environmental impacts of the projects and the contribution to Union energy targets, such as renewable penetrations, energy efficiency and interconnection targets shall also be taken into account;

(9) they shall ensure that the climate adaptation measures taken for each project are assessed and reflect the cost of greenhouse gas emissions and that the assessment is robust and consistent with other Union policies in order to enable comparison with other solutions which do not require new infrastructures.

ANNEX VI

(1)The manual of procedures referred to in Article 9(1) shall contain at least:

(a) specifications of the relevant pieces of legislation upon which decisions and opinions are based for the various types of relevant projects of common interest, including environmental law;

(b) the list of relevant decisions and opinions to be obtained;

(c) the names and contact details of the competent authority, other authorities concerned and major stakeholders concerned;

(d) the work flow, outlining each stage in the process, including an indicative timeline and a concise overview of the decision-making process for the various types of relevant projects of common interest;

(e) information about the scope, structure and level of detail of documents to be submitted with the application for decisions, including a checklist;

(f) the stages and means for the general public to participate in the process;

(g) the manner in which the competent authority, other authorities concerned and the project promoter shall demonstrate that the opinions expressed in the public consultation were taken into account, for example by showing what amendments were done in the location and design of the project or by providing reasons why such opinions have not been taken into account;

(h) to the extent possible, translations of its content in all languages of the neighbouring Member States to be realised in coordination with the relevant neighbouring Member States.

(2)The detailed schedule referred to in Article 10(6), point (b), shall at least specify the following:

(a) the decisions and opinions to be obtained;

(b) the authorities, stakeholders, and the public likely to be concerned;

(c) the individual stages of the procedure and their duration;

(d) major milestones to be accomplished and their deadlines in view of the comprehensive decision to be taken;

(e) the resources planned by the authorities and possible additional resource needs.

(3)Without prejudice to the requirements for public consultations under environmental law, to increase public participation in the permit granting process and ensure in advance information and dialogue with the public, the following principles shall be applied:

(a) the stakeholders affected by a project of common interest, including relevant national, regional and local authorities, landowners and citizens living in the vicinity of the project, the general public and their associations, organisations or groups, shall be extensively informed and consulted at an early stage, in an inclusive manner, when potential concerns by the public can still be taken into account and in an open and transparent manner. Where relevant, the competent authority shall actively support the activities undertaken by the project promoter;

(b) competent authorities shall ensure that public consultation procedures for projects of common interest are grouped together where possible including public consultations already required under national law. Each public consultation shall cover all subject matters relevant to the particular stage of the procedure, and one subject matter relevant to the particular stage of the procedure shall not be addressed in more than one public consultation; however, one public consultation may take place in more than one geographical location. The subject matters addressed by a public consultation shall be clearly indicated in the notification of the public consultation;

(c) comments and objections shall be admissible only from the beginning of the public consultation until the expiry of the deadline;

(d) the project promoters shall ensure that consultations take place during a period that allows for open and inclusive public participation.

(4)The concept for public participation shall at least include information about:

(a) the stakeholders concerned and addressed;

(b) the measures envisaged, including proposed general locations and dates of dedicated meetings;

(c) the timeline;

(d) the human resources allocated to various tasks.

(5)In the context of the public consultation to be carried out before submission of the application file, the relevant parties shall at least:

(a) publish in electronic and, where relevant, printed form, an information leaflet of no more than 15 pages, giving, in a clear and concise manner, an overview of the description, purpose and preliminary timetable of the development steps of the project, the national grid development plan, alternative routes considered, types and characteristics of the potential impact, including of cross-border or transboundary nature, and possible mitigation measures, such information leaflet is to be published prior to the start of the consultation and to list the web addresses of the website of the project of common interest referred to in Article 9(7), the transparency platform referred to in Article 23 and the manual of procedures referred to in point (1) of this Annex;

(b) publish the information on the consultation on the website of the project of common interest referred to in Article 9(7), on the bulletin boards of the offices of local administrations, and, at least, in one or, if applicable, two local media outlets;

(c) invite, in written or electronic form, the relevant affected stakeholders, associations, organisations and groups to dedicated meetings, during which concerns shall be discussed.

(6)The project website referred to in Article 9(7) shall at least publish the following information:

(a) the date when the project website was last updated;

(b) translations of its content in all languages of the Member States concerned by the project or on which the project has a significant cross-border impact in accordance with point (1) of Annex IV;

(c) the information leaflet referred to in point (5) updated with the latest data on the project;

(d) a non-technical and regularly updated summary reflecting the current status of the project, including geographic information, and clearly indicating, in case of updates, changes to previous versions;

(e) the implementation plan as set out in Article 5(1) updated with the latest data on the project;

(f) the funds allocated and disbursed by the Union for the project;

(g) the project and public consultation planning, clearly indicating dates and locations for public consultations and hearings and the envisaged subject matters relevant for those hearings;

(h) contact details in view of obtaining additional information or documents;

(i) contact details in view of conveying comments and objections during public consultations.

ANNEX VII

A. PRINCIPLES APPLIED IN ESTABLISHING THE UNION LIST

(1) Clusters of PCIs and PMIs

Some PCIs form part of a cluster because of their interdependent, potentially competing or competing nature. The following types of clusters of PCIs/PMIs are established:

— a cluster of interdependent PCIs/PMIs is defined as a ‘Cluster X, including the following PCIs/PMIs:’. Such cluster has been formed to identify PCIs/PMIs that are all needed to address the same bottleneck across country borders and provide synergies if implemented together. In this case, all the PCIs/PMIs have to be implemented to realise the EU-wide benefits;

— a cluster of potentially competing PCIs/PMIs is defined as a ‘Cluster X, including one or more of the following PCIs:’. Such cluster reflects an uncertainty around the extent of the bottleneck across country borders. In this case, not all the PCIs/PMIs included in the cluster have to be implemented. It is left to the market to determine whether one, several or all PCIs/PMIs are to be implemented, subject to the necessary planning, permit and regulatory approvals. The need for the PCIs/PMIs shall be reassessed in a subsequent PCIs/PMIs identification process, including with regard to the capacity needs; and

— a cluster of competing PCIs/PMIs is defined as a ‘Cluster X, including one of the following PCIs/PMIs:’. Such cluster addresses the same bottleneck. However, the extent of the bottleneck is more certain than in the case of a cluster of potentially competing PCIs/PMIs, and therefore, it has been determined that only one PCI/PMI has to be implemented. It is left to the market to determine which PCI/PMI is to be implemented, subject to the necessary planning, permit and regulatory approvals. Where necessary, the need for PCIs/PMIs shall be reassessed in a subsequent PCIs/PMIs identification process.

— a generic corridor reflects certain significant infrastructure needs that have been identified which could not be adequately addressed by the submitted projects.

All PCIs/PMIs are subject to the rights and obligations established under Regulation (EU) 2022/869.

(2) Treatment of substations and compressor stations

Substations and back-to-back electricity stations and compressor stations are considered as parts of PCIs/PMIs if they are geographically located on transmission lines or next to pipelines, as the case may be. Substations, back-to-back stations and compressor stations are considered as stand-alone PCIs and are explicitly listed on the Union list if their geographical location is different from transmission lines or pipelines as the case may be. They are subject to the rights and obligations laid down in Regulation (EU) 2022/869.

(3) Non-eligible parts of the PCI/PMI projects

Some PCI/PMI projects include one or more non-eligible investments within their composition. These investments, listed below, are not to be considered as part of the Union List.

— Section Guitiriz – Zamora (part of PCI 9.1.3)

— Section Saint Martin de Crau – Cruzy (part of PCI of 9.1.5)

— Section Freiburg – Offenbach (part of PCI 9.2.1)

— Section Limburg area and its connection to the North-South backbone in East of NL (part of PCI 9.6)

— Ship (part of PCI 9.13.1)

— Section Poggio Renatico – Gries Pass (part of PCI 10.1.1)

— Section Karperi – Komotimi (part of PCI 10.3.1)

— Section Kiruna – Lulea (part of PCI 11.1)

— 4 internal sections of the Finnish pipeline Kyröskoski; Imatra; Loviisa, through Kotka and Porvoo through Tolkinnen (geographical references are approximate and solely given as indications) (part of PCI 11.2)

— Pipeline in LT connecting to Klaipeda (part of PCI 11.2)

— Section Magdeburg – Potsdam (geographical references are approximate and solely given as indications) (part of PCI 11.2)

— Paperless workflow management, voicebot and chatbot, workforce management automation, joint auctions SK-UA and assets for tourism cave (part of PCI 12.3)

(4) Projects that changed their PCI number compared to the previous Union list

Projects part of the previous Union list under the repealed Regulation (EU) No 347/2013 change their PCI number due to reordering or to newly added priority corridors in the Regulation (EU) 2022/869. This relates to some projects part of the following categories: electricity, smart electricity grids and CO2 networks. In this case, the previous PCI number is mentioned, for information purpose only, under the project name.

B. THE UNION LIST OF PROJECTS OF COMMON INTEREST AND PROJECTS OF MUTUAL INTEREST

(1) North-South electricity interconnections in Western Europe (NSI West Electricity)

Projects of common interest developed in the region:

No.	Definition
1.1	Portugal – Spain interconnection between Beariz – Fontefría (ES), Fontefria (ES) – Ponte de Lima (PT) and Ponte de Lima – Vila Nova de Famalicão (PT), including substations in Beariz (ES), Fontefría (ES) and Ponte de Lima (PT) (No 2.17 on the fifth PCI list)
1.2	Interconnection between Gatica (ES) and Cubnezais (FR) [currently known as ‘Biscay Gulf’] (No 2.7 on the fifth PCI list)
1.3	Interconnection between La Martyre (FR) and Great Island or Knockraha (IE) [currently known as ‘Celtic Interconnector’] (No 1.6 on the fifth PCI list)
1.4	Cluster of internal lines in Germany, including the following PCIs: 1.4.1  Internal line from Emden-East to Osterath to increase capacity from Northern Germany to the Rhineland [currently known as ‘A-Nord’] (No 2.31.1 on the fifth PCI list) 1.4.2  Internal line between Heide/West to Polsum to increase capacity from Northern Germany to the Ruhr-Area [currently known as ‘Korridor B’] (No 2.31.2 on the fifth PCI list) 1.4.3  Internal line from Wilhelmshaven to Uentrop to increase capacity from Northern Germany to the Ruhr-Area [currently known as ‘Korridor B’] (No 2.31.3 on the fifth PCI list
1.5	Internal line in Germany between Brunsbüttel/Wilster to Großgartach/Grafenrheinfeld to increase capacity at Northern and Southern borders [currently known as ‘Suedlink’] (No 2.10 on the fifth PCI list)
1.6	Internal line between Osterath and Philippsburg (DE) to increase capacity at Western borders [currently known as ‘Ultranet’] (No 2.9 on the fifth PCI list)
1.7	1.7.1  Interconnection between Navarra (ES) and Landes (FR) [currently known as ‘Pyrenean crossing 1’] (No 2.27.2 on the fifth PCI list) 1.7.2  Interconnection between Aragón region (ES) and Marsillon (FR) [currently known as ‘Pyrenean crossing 2’] (No 2.27.1 on the fifth PCI list)
1.8	Interconnection between Lonny (FR) and Gramme (BE) (No 2.32 on the fifth PCI list)
1.9	Internal lines at the Belgian north border between Zandvliet and Lillo-Liefkenshoek (BE), and between Liefkenshoek and Mercator, including a substation in Lillo (BE) [currently known as ‘BRABO II + III’] (No 2.23 on the fifth PCI list)
1.10	Interconnection between mainland Italy – Corsica (FR) and Sardinia (IT) [currently known as ‘SACOI 3’] (No 2.4 on the fifth PCI list)
1.11	Kaunertal Storage Extension Project (AT) (No 2.18 on the fifth PCI list)
1.12	Purifying-Pumped Hydroelectric Energy Storage NAVALEO (ES) (No 2.28.2 on the fifth PCI list)
1.13	Silvermines Pumped Hydroelectric Energy Storage (IE) (No 2.29 on the fifth PCI list)
1.14	Pumped Hydroelectric Energy Storage RIEDL (DE) (No 2.30 on the fifth PCI list)
1.15	Reversible Hydraulic Pumped Energy Storage LOS GUAJARES (ES)
1.16	Green Hydrogen Hub Denmark Compressed Air Energy Storage (DK) (No 1.21 on the fifth PCI list)
1.17	Pumped Hydroelectric Energy Storage WSK PULS (DE)
1.18	Reversible Hydraulic Pumped Energy Storage AGUAYO II (ES)

Projects of mutual interest developed in the region:

No	Definition
1.19	Interconnection between Sicily (IT) and Tunisia node (TN) [currently known as ‘ELMED’] (No 2.33 on the fifth PCI list)
1.20	Interconnection between Zeebrugge area (BE) and Kemsley, Kent (UK) [currently known as ‘Cronos’]
1.21	Interconnection between Emden areas (DE) and Corringham, Essex (UK) [currently known as ‘Tarchon’]

(2) North-South electricity interconnections in Central Eastern and South Eastern Europe (NSI East Electricity)

Projects of common interest developed in the region:

No	Definition
2.1	Cluster Austria – Germany, including the following PCIs): 2.1.1  Interconnection between Isar/Altheim/Ottenhofen (DE) – St.Peter (AT) (No 3.1.1 on the fifth PCI list) 2.1.2  Internal line between St. Peter and Tauern (AT) (No 3.1.2 on the fifth PCI list) 2.1.3  Internal line between Westtirol – Zell/Ziller (AT) (No 3.1.4 on the fifth PCI list) 2.1.4  Interconnector between Pleinting (DE) – St.Peter (AT)
2.2	Internal line in Germany between Wolmirstedt and Isar [currently known as ‘SuedOstLink’] (No 3.12 on the fifth PCI list)
2.3	Cluster of internal lines in Czechia, including the following: 2.3.1  Internal line between Vernerov and Vitkov (No 3.11.1 on the fifth PCI list) 2.3.2  Internal line between Prestice and Kocin (No 3.11.3 on the fifth PCI list) 2.3.3  Internal line between Kocin and Mirovka (No 3.11.4 on the fifth PCI list)
2.4	Interconnector between Würmlach (AT) – Somplago (IT) (No 3.4 on the fourth PCI list)
2.5	Cluster Hungary – Romania including the following PCIs: 2.5.1  Interconnector between Józsa (HU) and Oradea (RO) 2.5.2  Internal line between Urechesti (RO) and Targu Jiu (RO) 2.5.3  Internal line between Targu Jiu (RO) and Paroseni (RO) 2.5.4  Internal line between Paroseni (RO) and Baru Mare (RO) 2.5.5  Internal line between Baru Mare (RO) and Hasdat (RO)
2.6	Cluster Israel – Cyprus – Greece currently known as ‘EuroAsia Interconnector’], including the following PCIs 2.6.1  Interconnection between Hadera (IL) and Kofinou (CY) (No 3.10.1 on the fifth PCI list) 2.6.2  Interconnection between Kofinou (CY) and Korakia, Crete (EL) (No 3.10.2 on the fifth PCI list)
2.7	Interconnector between Otrokovice (CZ) – Ladce (SK)
2.8	Interconnector between Lienz (AT) – Veneto region (IT) (No 3.2.1 on the second PCI list)
2.9	Hydro-pumped storage in Amfilochia (EL) (No 3.24 on the fifth PCI list)
2.10	Ptolemaida Battery Energy Storage System (EL)
2.11	Modernisation of Pumped Hydroelectric Energy Storage in Čierny Váh (SK) [currently known as ‘SE Integrator’]

Projects of mutual interest developed in the region:

No	Definition
2.12	Interconnector between Subotica (RS) and Sándorfalva (HU)
2.13	Interconnection between Wadi El Natroon (EG) and Mesogeia/St Stefanos (EL) [currently known as ‘GREGY Interconnector’]

(3) Baltic Energy Market Interconnection Plan in electricity (BEMIP Electricity)

Projects of common interest developed in the region:

No	Definition
3.1	Internal line between Stanisławów and Ostrołęka (PL) (No 4.5.2 on the fifth PCI list)
3.2	Hydro-pumped electricity storage in Estonia (No 4.6 on the fifth PCI list)
3.3	Integration and synchronisation of the Baltic States’ electricity system with the European networks, including the following PCIs: 3.3.1  Interconnection between Tsirguliina (EE) and Valmiera (LV) (No 4.8.3 on the fifth PCI list) 3.3.2  Internal line between Viru and Tsirguliina (EE) (No 4.8.4 on the fifth PCI list) 3.3.3  Internal line between Paide and Sindi (EE) (No 4.8.7 on the fifth PCI list) 3.3.4  Internal line between Vilnius and Neris (LT) (No 4.8.8 on the fifth PCI list) 3.3.5  Further infrastructure aspects related to the implementation of the synchronisation of the Baltic States’ system with the continental European network (No 4.8.9 on the fifth PCI list) 3.3.6  Interconnection between Lithuania and Poland [currently known as ‘Harmony Link’] (No 4.8.10 on the fifth PCI list) 3.3.7  New 330kV Mūša substation (LT) (No 4.8.13 on the fifth PCI list) 3.3.8  Internal line between Bitenai and KHAE (LT) (No 4.8.14 on the fifth PCI list) 3.3.9  New 330kV Darbėnai substation (LT) (No 4.8.15 on the fifth PCI list) 3.3.10  Internal line between Darbenai and Bitenai (LT) (No 4.8.16 on the fifth PCI list) 3.3.11  Internal line between Dunowo and Żydowo Kierzkowo (PL) (No 4.8.18 on the fifth PCI list) 3.3.12  Internal line between Piła Krzewina and Żydowo Kierzkowo (PL) (No 4.8.19 on the fifth PCI list) 3.3.13  Internal line between Morzyczyn-Dunowo-Słupsk-Żarnowiec (PL) (No 4.8.21 on the fifth PCI list) 3.3.14  Internal line between Żarnowiec-Gdańsk/Gdańsk Przyjaźń-Gdańsk Błonia (PL) (No 4.8.22 on the fifth PCI list) 3.3.15  Synchronous condensers providing inertia, voltage stability, frequency stability and short-circuit power in Lithuania, Latvia and Estonia (No 4.8.23 on the fifth PCI list)
3.4	Third interconnection between Finland – Sweden [currently known as ‘Aurora line’], including the following PCIs: 3.4.1  Interconnection between northern Finland and northern Sweden (No 4.10.1 on the fifth PCI list) 3.4.2  Internal line between Keminmaa and Pyhänselkä (FI) (No 4.10.2 on the fifth PCI list)
3.5	Fourth interconnection between Finland – Sweden [currently known as ‘Aurora line 2’]
3.6	Interconnection between Finland and Estonia [currently known as ‘Estlink 3’]

(4) Northern Seas offshore grids (NSOG)

Projects of common interest developed in the region:

No	Definition
4.1	One or more hubs in the North Sea with interconnectors to bordering North Sea countries (Denmark, the Netherlands and Germany) [currently known as ‘North Sea Wind Power Hub’] (No 1.19 on the fifth PCI list)
4.2	Offshore hybrid interconnector between Belgium and Denmark [currently known as ‘Triton Link’]
4.3	High voltage offshore substation and connection to Menuel (FR) [currently known as ‘Offshore Wind connection Centre Manche 1’]
4.4	High voltage offshore substation and connection to Tourbe (FR) [currently known as ‘Offshore Wind connection Centre Manche 2’]

Projects of mutual interest developed in the region:

No	Definition
4.5	Multi-purpose interconnector between Modular Offshore Grid 2 (BE) and Leisten (UK) [currently known as ‘Nautilus’] (No 1.15 on the fourth PCI list)
4.6	Multi-purpose HVDC interconnection between Great Britain and the Netherlands [currently known as ‘LionLink’]

(5) Baltic Energy Market Interconnection Plan offshore grids (BEMIP offshore)

Projects of common interest developed in the region:

No	Definition
5.1	Latvia and Estonia Hybrid Offshore interconnector [currently known as ‘Elwind’]
5.2	Bornholm Energy Island (BEI) Hybrid Offshore interconnector between Denmark and Germany

(6) South and West offshore grids (SW offshore)

Projects of common interest developed in the region:

No	Definition
6.1	Offshore Wind Connection Occitanie (FR)
6.2	Offshore Wind Connection PACA (FR)

(7) South and East offshore grids (SE offshore)

No projects were submitted for this corridor.

(8) Atlantic offshore grids

Projects of common interest developed in the region:

No	Definition
8.1	Offshore Wind Connection South Britanny (FR)
8.2	Offshore Wind Connection South Atlantic (FR)

(9) Hydrogen interconnections in Western Europe (HI West)

Projects of common interest developed in the region:

No	Definition
9.1	Corridor Portugal – Spain – France – Germany: 9.1.1  Internal hydrogen infrastructure in Portugal 9.1.2  Hydrogen interconnector Portugal – Spain 9.1.3  Internal hydrogen infrastructure in Spain 9.1.4  Hydrogen interconnector Spain – France [currently known as BarMar] 9.1.5  Internal hydrogen infrastructure in France connecting to Germany [currently known as HyFen] 9.1.6  Internal hydrogen infrastructure in Germany connecting to France [currently known as H2Hercules South]
9.2	France – Germany cross-border hydrogen valleys: 9.2.1  Hydrogen valley in Germany to the French border [currently known as RHYn] 9.2.2  Hydrogen valley in France to the German border [currently known as Mosahyc]
9.3	Internal hydrogen infrastructure in France to the Belgium border [currently known as Franco-Belgian H2 corridor]
9.4	Internal hydrogen infrastructure in Germany [currently known as H2ercules West]
9.5	Internal hydrogen infrastructure in Belgium [currently known as Belgian Hydrogen Backbone]
9.6	Internal hydrogen infrastructure in the Netherlands [currently known as National Hydrogen Backbone]
9.7	Hydrogen interconnectors National Hydrogen Backbone (NL) – Germany: 9.7.1  Hydrogen interconnector from the North-South backbone in East to Oude (NL) – H2ercules North (DE) 9.7.2  Hydrogen interconnector from the North-South backbone in East to Vlieghuis (NL) – Vlieghuis – Ochtrup (DE) 9.7.3  Hydrogen interconnector from Netherlands to Germany (currently known as Delta Rhine Corridor H2)
9.8	Offshore hydrogen pipeline Germany [currently known as AquaDuctus]
9.9	Hydrogen interconnector Denmark – Germany: 9.9.1  Internal hydrogen infrastructure in Germany [currently known as HyperLink III] 9.9.2  Internal hydrogen infrastructure in Denmark [currently known as DK Hydrogen Pipeline West]
9.10	Ammonia reception facilities in Belgium: 9.10.1  Ammonia reception facility Antwerp 9.10.2  Ammonia reception facility Amplifhy Antwerp 9.10.3  Zeebrugge New Molecules development ammonia reception facility
9.11	Ammonia reception facilities in Germany: 9.11.1  Ammonia reception facility terminal Brunsbüttel 9.11.2  Ammonia reception facility Wilhelmshaven (BP) 9.11.3  Ammonia reception facility Wilhelmshaven (Uniper)
9.12	Reception facilities in the Netherlands: 9.12.1  Rotterdam LH2 reception facility 9.12.2  Ammonia reception facility Amplifhy Rotterdam 9.12.3  Ammonia reception facility ACE Rotterdam
9.13	Ammonia reception facility Dunkerque (FR)
9.14	H2Sines.RDAM electrolyser (PT)
9.15	Electrolyser facilities in Spain: 9.15.1  Tarragona hydrogen network electrolyser 9.15.2  Bilbao large scale electrolyser 9.15.3  Cartagena large scale electrolyser 9.15.4  Valle andaluz del hidrógeno verde electrolyser 9.15.5  Asturias H2 valley electrolyser
9.16	Electrolyser facilities in France: 9.16.1  CarlHYng electrolyser 9.16.2  Emil’Hy electrolyser 9.16.3  HyGreen electrolyser 9.16.4  H2V Valenciennes electrolyser 9.16.5  H2Thionville electrolyser
9.17	Electrolyser facilities in the Netherlands: 9.17.1  Enecolyser electrolyser 9.17.2  H2-Fifty electrolyser 9.17.3  SeaH2Land electrolyser
9.18	Electrolyser facilities in the Germany: 9.18.1  GreenWilhelmshaven electrolyser 9.18.2  CHC Wilhelmshaven electrolyser
9.19	Jytske Banke electrolyser (DK)
9.20	Danish Hydrogen Storage (DK)
9.21	Hystock Opslag H2 storage (NL)
9.22	Hydrogen storages in Germany: 9.22.1  Salthy hydrogen storage Harsefeld 9.22.2  H2 Storage Gronau-Epe
9.23	Storage GeoH2 (FR)
9.24	Hydrogen storages in Spain: 9.24.1  H2 storage North – 1 9.24.2  H2 storage North – 2

Projects of mutual interest developed in the region:

No	Definition
9.25	Offshore hydrogen pipeline Norway – Germany [currently known as CHE Pipeline]

(10) Hydrogen interconnections in Central Eastern and South Eastern Europe (HI East)

Projects of common interest developed in the region:

No	Definition
10.1	Hydrogen corridor Italy – Austria – Germany: 10.1.1  Internal hydrogen infrastructure in Italy [currently known as Italian H2 Backbone] 10.1.2  Internal hydrogen infrastructure in Austria [currently knowns as H2 Readiness of the TAG pipeline system] 10.1.3  Internal hydrogen infrastructure in Austria [currently known as H2 Backbone WAG and Penta West] 10.1.4  Internal hydrogen infrastructure in Germany [currently knowns as HyPipe Bavaria – The Hydrogen Hub
10.2	Hydrogen interconnector between Czechia and Germany: 10.2.1  Internal hydrogen infrastructure in Czechia towards Germany 10.2.2  Internal hydrogen infrastructure in Germany [currently known as FLOW East – Making Hydrogen Happen]
10.3	Hydrogen interconnector between Greece and Bulgaria: 10.3.1  Internal hydrogen infrastructure in Greece towards the Bulgarian border 10.3.2  Internal hydrogen infrastructure in Bulgaria towards the Greece border
10.4	Generic corridor aiming to transmit hydrogen from Ukraine to Slovakia, Czechia, Austria and Germany

(11) Baltic Energy Market Interconnection Plan in hydrogen (BEMIP Hydrogen)

Projects of common interest developed in the region:

No	Definition
11.1	Hydrogen interconnector between Sweden and Finland [currently known as Nordic Hydrogen Route – Bothnian Bay]
11.2	Hydrogen interconnector between Finland, Estonia, Latvia, Lithuania, Poland and Germany [currently known as Nordic-Baltic Hydrogen Corridor]
11.3	Hydrogen interconnector between Sweden, Finland and Germany [currently known as the Baltic Sea Hydrogen Collector]

(12) Priority Thematic Area Smart electricity grids deployment

Projects of common interest developed in the thematic area:

No	Definition
12.1	ACON – Again COnnected Networks (CZ, SK), to foster the integration of the Czech and Slovak electricity markets by improving efficiency of distribution networks (No 10.4 on the fifth PCI list)
12.2	CARMEN (BG, RO), to reinforce cross-border TSO-TSO cooperation and data sharing, enhance TSO-DSO cooperation, invest in grid expansion and increase capacity for integration of new renewables and improve grid stability, security and flexibility (No 10.10 on the fifth PCI list)
12.3	Danube InGrid (HU, SK), to efficiently integrate the behaviour and actions of all market users connected to the electricity networks in Hungary and Slovakia (No 10.7 on the fifth PCI list)
12.4	Gabreta Smart Grids (CZ, DE), to increase grid hosting capacity, enable remote monitoring and control of MV grids and improve grid observability and network planning (No 10.11 on the fifth PCI list)
12.5	GreenSwitch (AT, HR, SI), to increase hosting capacity for distributed renewable sources and efficient integration of new loads, improving observability of the distribution network and increasing cross-border capacity (No 10.12 on the fifth PCI list)

(13) Priority Thematic Area Cross-border carbon dioxide network

Projects of common interest developed in the thematic area:

No	Definition
13.1	CO2 TransPorts will establish infrastructure to facilitate large-scale capture, transport and storage of CO2 from the Rotterdam, Antwerp and North Sea Port areas (No 12.3 on the fifth PCI list)
13.2	Aramis – cross-border CO2 transport and storage project, intake from emitters in the hinterland of the Rotterdam harbour area, pipe transport to storage on the Dutch continental shelf (No 12.7 on the fifth PCI list)
13.3	ECO2CEE – open-access cross-border CO2 transport and storage project with projected storages sites in Denmark, Norway, Netherlands and UK (extension of No 12.9 on the fifth PCI list)
13.4	Bifrost – transport and storage project with offshore storage in DK from emitters from Denmark, Germany and Poland
13.5	Callisto – development of multi-modal CO2 hubs in the Mediterranean storing CO2 emissions from France and Italy
13.6	CCS Baltic Consortium – cross-border CO2 transport via rail between Latvia and Lithuania with a multi-modal LCO2 terminal based in Klaipeda
13.7	Delta Rhine Corridor – project to transport CO2 via pipelines from emitters in the Ruhr area in Germany and the Rotterdam area in the Netherlands to offshore storage off the Dutch coast
13.8	EU2NSEA – cross-border CO2 network developed between Belgium, Germany and Norway to also collect CO2 from DK, FR, LV, NL, PL and SE, with storage on the Norwegian continental shelf
13.9	GT CCS Croatia – construction of pipeline transport infrastructure in Croatia and Hungary, with underground storage in HR
13.10	Norne – transport infrastructure in Denmark with onshore and possibly offshore storage, emitters primarily from DK, SE, BE and UK will transport to DK via ship
13.11	Prinos – Offshore storage at Prinos field for emissions from EL, by pipeline, and from BG, HR, CY, EL, IT and SI by ship
13.12	Pycasso – transport and storage of CO2 in onshore storage site in southwestern FR, industrial emitters from FR and ES

Projects of mutual interest developed in the thematic area:

No	Definition
13.13	Northern Lights – a CO2 cross-border connection project between several European capture initiatives (among others Belgium, Germany, Ireland, France, Sweden) transport by ship to storage on the Norwegian continental shelf (No 12.4 on the fifth PCI list)
13.14	Nautilus CCS – Emissions from Le Havre, Dunkirk, Duisburg and Rogaland areas to be captured and transported by ship to various sinks in the North Sea (extension of No 12.8 on the fifth PCI list)

(14) Priority Thematic Area Smart gas grids

No submitted projects were found eligible for this category.

(15) Projects that maintain their status of project of common interest (Article 24 derogation)

No	Definition
15.1	Connection of Malta to the European gas network – pipeline interconnection with Italy at Gela (No 5.19 on the fifth PCI list)
15.2	Pipeline from the East Mediterranean gas reserves to Greece mainland via Cyprus and Crete [currently known as ‘EastMed Pipeline’], with metering and regulating station at Megalopoli (No 7.3.1. on the fifth PCI list)