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Regulation (EU) No 347/2013 of the European Parliament and of the Council of 17 April 2013 on guidelines for trans-European energy infrastructure and repealing Decision No 1364/2006/EC and amending Regulations (EC) No 713/2009, (EC) No 714/2009 and (EC) No 715/2009 Text with EEA relevance

Type Regulation

Publication 2013-04-25

Last updated 2024-04-28

State Repealed

Department Council of the European Union, European Parliament

Source EUR-Lex

articles 22

Reform history JSON API

Member States concerned: Denmark, Estonia, Finland, Germany, Latvia, Lithuania, Poland, Sweden.

3. PRIORITY OIL CORRIDOR

(9)Oil supply connections in Central Eastern Europe (‘OSC’): interoperability of the oil pipeline network in Central Eastern Europe to increase security of supply and reduce environmental risks.

Member States concerned: Austria, Croatia (6) , Czech Republic, Germany, Hungary, Poland, Slovakia.

4. PRIORITY THEMATIC AREAS

(10)Smart grids deployment: adoption of smart grid technologies across the Union to efficiently integrate the behaviour and actions of all users connected to the electricity network, in particular the generation of large amounts of electricity from renewable or distributed energy sources and demand response by consumers.

Member States concerned: all;

(11)Electricity highways: first electricity highways by 2020, in view of building an electricity highways system across the Union that is capable of:

(a) accommodating ever-increasing wind surplus generation in and around the Northern and Baltic Seas and increasing renewable generation in the East and South of Europe and also North Africa;

(b) connecting these new generation hubs with major storage capacities in the Nordic countries, the Alps and other regions with major consumption centres; and

Member States concerned: all;

(12)Cross-border carbon dioxide network: development of carbon dioxide transport infrastructure between Member States and with neighbouring third countries in view of the deployment of carbon dioxide capture and storage.

Member States concerned: all.

ANNEX II

ENERGY INFRASTRUCTURE CATEGORIES

The energy infrastructure categories to be developed in order to implement the energy infrastructure priorities listed in Annex I are the following:

(1) concerning electricity:
(a) high-voltage overhead transmission lines, if they have been designed for a voltage of 220 kV or more, and underground and submarine transmission cables, if they have been designed for a voltage of 150 kV or more;
(b) concerning in particular electricity highways; any physical equipment designed to allow transport of electricity on the high and extra-high voltage level, in view of connecting large amounts of electricity generation or storage located in one or several Member States or third countries with large-scale electricity consumption in one or several other Member States;
(c) electricity storage facilities used for storing electricity on a permanent or temporary basis in above-ground or underground infrastructure or geological sites, provided they are directly connected to high-voltage transmission lines designed for a voltage of 110 kV or more;
(d) any equipment or installation essential for the systems defined in (a) to (c) to operate safely, securely and efficiently, including protection, monitoring and control systems at all voltage levels and substations;
(e) any equipment or installation, both at transmission and medium voltage distribution level, aiming at two-way digital communication, real-time or close to real-time, interactive and intelligent monitoring and management of electricity generation, transmission, distribution and consumption within an electricity network in view of developing a network efficiently integrating the behaviour and actions of all users connected to it — generators, consumers and those that do both — in order to ensure an economically efficient, sustainable electricity system with low losses and high quality and security of supply and safety;

(2) concerning gas:
(a) transmission pipelines for the transport of natural gas and bio gas that form part of a network which mainly contains high-pressure pipelines, excluding high-pressure pipelines used for upstream or local distribution of natural gas;
(b) underground storage facilities connected to the above-mentioned high-pressure gas pipelines;
(c) reception, storage and regasification or decompression facilities for liquefied natural gas (LNG) or compressed natural gas (CNG);
(d) any equipment or installation essential for the system to operate safely, securely and efficiently or to enable bi-directional capacity, including compressor stations;

(3) concerning oil:
(a) pipelines used to transport crude oil;
(b) pumping stations and storage facilities necessary for the operation of crude oil pipelines;
(c) any equipment or installation essential for the system in question to operate properly, securely and efficiently, including protection, monitoring and control systems and reverse-flow devices;

(4) concerning carbon dioxide:
(a) dedicated pipelines, other than upstream pipeline network, used to transport anthropogenic carbon dioxide from more than one source, i.e. industrial installations (including power plants) that produce carbon dioxide gas from combustion or other chemical reactions involving fossil or non-fossil carbon-containing compounds, for the purpose of permanent geological storage of carbon dioxide pursuant to Directive 2009/31/EC of the European Parliament and of the Council ([^E0011]);
(b) facilities for liquefaction and buffer storage of carbon dioxide in view of its further transportation. This does not include infrastructure within a geological formation used for the permanent geological storage of carbon dioxide pursuant to Directive 2009/31/EC and associated surface and injection facilities;
(c) any equipment or installation essential for the system in question to operate properly, securely and efficiently, including protection, monitoring and control systems.

ANNEX III

REGIONAL LISTS OF PROJECTS OF COMMON INTEREST

1. RULES FOR GROUPS

(1)For electricity projects falling under the categories set out in Annex II.1, each Group shall be composed of representatives of the Member States, national regulatory authorities, TSOs, as well as the Commission, the Agency and the ENTSO for Electricity.

For gas projects falling under the categories set out in Annex II.2, each Group shall be composed of representatives of the Member States, national regulatory authorities, TSOs, as well as the Commission, the Agency and the ENTSO for Gas.

For oil and carbon dioxide transport projects falling under the categories referred to in Annex II.3 and 4, each Group shall be composed of the representatives of the Member States, project promoters concerned by each of the relevant priorities designated in Annex I and the Commission.

(2)The decision-making bodies of the Groups may merge. All Groups or decision-making bodies shall meet together, when relevant, to discuss matters common to all Groups; such matters may include issues relevant to cross-regional consistency or the number of proposed projects included on the draft regional lists at risk of becoming unmanageable.

(3)Each Group shall organise its work in line with regional cooperation efforts pursuant Article 6 of Directive 2009/72/EC, Article 7 of Directive 2009/73/EC, Article 12 of Regulation (EC) No 714/2009, and Article 12 of Regulation (EC) No 715/2009 and other existing regional cooperation structures.

(4)Each Group shall invite, as appropriate in view of implementing the relevant priority designated in Annex I, promoters of a project potentially eligible for selection as a project of common interest as well as representatives of national administrations, of regulatory authorities, and TSOs from EU candidate countries and potential candidates, the member countries of the European Economic Area and the European Free Trade Association, representatives from the Energy Community institutions and bodies, countries covered by the European Neighbourhood policy and countries, with which the Union has established specific energy cooperation. The decision to invite third country-representatives shall be based on consensus.

(5)Each Group shall consult the organisations representing relevant stakeholders — and, if deemed appropriate, stakeholders directly — including producers, distribution system operators, suppliers, consumers, and organisations for environmental protection. The Group may organise hearings or consultations, where relevant for the accomplishments of its tasks.

(6)The internal rules, an updated list of member organisations, regularly updated information on the progress of work, meeting agendas, as well as final conclusions and decisions of each Group shall be published by the Commission on the transparency platform referred to in Article 18.

(7)The Commission, the Agency and the Groups shall strive for consistency between the different Groups. For this purpose, the Commission and the Agency shall ensure, when relevant, the exchange of information on all work representing an interregional interest between the Groups concerned.

The participation of national regulatory authorities and the Agency in the Groups shall not jeopardise the fulfilment of their objectives and duties under this Regulation or under Articles 36 and 37 of Directive 2009/72/EC and Articles 40 and 41 of Directive 2009/73/EC, or under Regulation (EC) No 713/2009.

2. PROCESS FOR ESTABLISHING REGIONAL LISTS

(1)Promoters of a project potentially eligible for selection as a project of common interest wanting to obtain the status of projects of common interest shall submit an application for selection as project of common interest to the Group that includes:

— an assessment of their projects with regard to the contribution to implementing the priorities set out in Annex I,

— an analysis of the fulfilment of the relevant criteria defined in Article 4,

— for projects having reached a sufficient degree of maturity, a project-specific cost-benefit analysis in accordance with Articles 21 and 22 based on the methodologies developed by the ENTSO for electricity or the ENTSO for gas pursuant to Article 11, and

— any other relevant information for the evaluation of the project.

(2)All recipients shall preserve the confidentiality of commercially sensitive information.

(3)After adoption of the first Union list, for all subsequent Union lists adopted, proposed electricity transmission and storage projects falling under the categories set out in Annex II.1(a), (b) and (d) shall be part of the latest available 10-year network development plan for electricity, developed by the ENTSO for Electricity pursuant Article 8 of Regulation (EC) No 714/2009.

(4)After adoption of the first Union list, for all subsequent Union lists adopted, proposed gas infrastructure projects falling under the categories set out in Annex II.2 shall be part of the latest available 10-year network development plan for gas, developed by the ENTSO for Gas pursuant Article 8 of Regulation (EC) No 715/2009.

(5)The project proposals submitted for inclusion in the first Union list which were not previously evaluated pursuant to Article 8 of Regulation (EC) No 714/2009 shall be assessed at Union-wide system level by:

— the ENTSO for Electricity in line with the methodology applied in the latest available 10-year network development plan for projects falling under Annex II.1(a), (b) and (d),

— the ENTSO for Gas or by a third party in a consistent manner based on an objective methodology for projects falling under Annex II.2.

By 16 January 2014, the Commission shall issue Guidelines on criteria to be applied by the ENTSO for electricity and the ENTSO for gas when developing their respective 10-year network development plans referred to in points (3) and (4), in order to ensure equal treatment and transparency of the process.

(6)Proposed carbon dioxide transport projects falling under the category set out in Annex II.4 shall be presented as part of a plan, developed by at least two Member States, for the development of cross-border carbon dioxide transport and storage infrastructure, to be presented by the Member States concerned or entities designated by those Member States to the Commission.

(7)For proposed projects falling under the categories set out in Annex II.1 and 2, national regulatory authorities, and if necessary the Agency, shall, where possible in the context of regional cooperation (Article 6 of Directive 2009/72/EC, Article 7 of Directive 2009/73/EC), check the consistent application of the criteria/ cost-benefit analysis methodology and evaluate their cross-border relevance. They shall present their assessment to the Group.

(8)For proposed oil and carbon dioxide transport projects falling under the categories set out in Annex II.3 and 4, the Commission shall evaluate the application of the criteria set out in Article 4. For proposed carbon dioxide projects falling under the category set out in Annex II.4, 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.

(9)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.

(10)The decision-making body of 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 of common interest related to its territory.

(11)The Group shall meet to examine and rank the proposed projects taking into account the assessment of the regulators, or the assessment of the Commission for oil and carbon dioxide transport projects.

(12)The draft regional lists of proposed projects falling under the categories set out in Annex II.1 and 2 drawn up by the Groups, together with any opinions as specified in point (9), 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 15(1) of Regulation (EC) No 713/2009.

(13)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, respecting the provisions set out in Article 3(3), based on 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 (7), or the assessment of the Commission for oil and carbon dioxide transport projects proposed in accordance with point (8). The Groups shall submit the final regional lists to the Commission, together with any opinions as specified in point (9).

(14)If, based on the regional lists received, and after having taken into account the Agency opinion, the total number of proposed projects of common interest on the Union list would exceed a manageable number, the Commission shall consider, after having consulted each Group concerned, not to include in the Union list projects that were ranked lowest by the Group concerned according to the ranking established pursuant to Article 4(4).

ANNEX IV

RULES AND INDICATORS CONCERNING CRITERIA FOR PROJECTS OF COMMON INTEREST

(1)A project with significant cross-border impact is a project on the territory of a Member State, which fulfils 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, or at any other relevant cross-section of the same transmission corridor having the effect of increasing this cross-border grid transfer capacity, by at least 500 Megawatt compared to the situation without commissioning of the project;

(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 Gigawatt-hours/year;

(c) for gas transmission, the project concerns investment in reverse flow capacities or changes the capability to transmit gas across the borders of the Member States concerned by at least 10 % compared to the situation prior to the commissioning of the project;

(d) for gas storage or liquefied/compressed natural gas, the project aims at supplying directly or indirectly at least two Member States or at fulfilling the infrastructure standard (N-1 rule) at regional level in accordance with Article 6(3) of Regulation (EU) No 994/2010 of the European Parliament and of the Council ([^E0012]);

(e) for smart grids, the project is designed for equipments and installations at high-voltage and medium-voltage level designed for a voltage of 10 kV or more. It involves transmission and distribution system operators from at least two Member States, which cover at least 50 000 users that generate or consume electricity or do both in a consumption area of at least 300 Gigawatthours/year, of which at least 20 % originate from renewable resources that are variable in nature.

(2)Concerning projects falling under the categories set out in Annex II.1(a) to (d), the criteria listed in Article 4 shall be evaluated as follows:

(a) Market integration, competition and system flexibility shall be measured in line with the analysis made in the latest available Union-wide 10-year network development plan in electricity, notably by:
— calculating, for cross-border projects, the impact on the grid transfer capability in both power flow directions, measured in terms of amount of power (in megawatt), and their contribution to reaching the minimum interconnection capacity of 10 % installed production capacity or, 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,
— assessing the impact, for the area of analysis as defined in Annex V.10, in terms of energy system-wide generation and transmission costs and evolution and convergence of market prices provided by a project under different planning scenarios, notably taking into account the variations induced on the merit order.

(b) Transmission of renewable energy generation to major consumption centres and storage sites shall be measured in line with the analysis made in the latest available 10-year network development plan in electricity, notably by:
— for electricity transmission, by estimating the amount of generation capacity from renewable energy sources (by technology, in megawatts), which is connected and transmitted due to the project, compared to the amount of planned total generation capacity from these types of renewable energy sources in the concerned Member State in 2020 according to the national renewable energy action plans as defined in Article 4 of Directive 2009/28/EC,
— for electricity storage, by comparing new capacity provided by the project with total existing capacity for the same storage technology in the area of analysis as defined in Annex V.10.

(c) Security of supply, interoperability and secure system operation shall be measured in line with the analysis made in the latest available 10-year network development plan in electricity, notably by assessing the impact of the project on the loss of load expectation for the area of analysis as defined in Annex V.10 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.

(3)Concerning projects falling under the categories set out in Annex II.2, the criteria listed in Article 4 shall be evaluated as follows:

(a) Market integration and interoperability shall be 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, including the capacity level offered for reverse flows under various scenarios.

(b) Competition shall be measured on the basis of diversification, including the facilitation of access to indigenous sources of supply, taking into account, successively: diversification of sources; diversification of counterparts; diversification of routes; the impact of new capacity on the Herfindahl-Hirschmann index (HHI)calculated at capacity level for the area of analysis as defined in Annex V.10.

(c) Security of gas supply shall be measured by calculating the additional value of the project to the short and long-term resilience of the Union’s gas system and to enhancing the remaining flexibility of the system to cope with supply disruptions to Member States under various scenarios as well as the additional capacity provided by the project measured in relation to the infrastructure standard (N-1 rule) at regional level in accordance with Article 6(3) of Regulation (EU) No 994/2010.

(d) Sustainability shall be measured as the contribution of a project to reduce emissions, to support the back-up of renewable electricity generation or power-to-gas and biogas transportation, taking into account expected changes in climatic conditions.

(4)Concerning projects falling under the category set out in Annex II.1(e), each function listed in Article 4 shall be evaluated against the following criteria:

(a) Level of sustainability : This criterion shall be measured by assessing the reduction of greenhouse gas emissions, and the environmental impact of electricity grid infrastructure.

(b) Capacity of transmission and distribution grids to connect and bring electricity from and to users : This criterion shall be measured by estimating the installed capacity of distributed energy resources in distribution networks, the allowable maximum injection of electricity without congestion risks in transmission networks, and the energy not withdrawn from renewable sources due to congestion or security risks.

(c) Network connectivity and access to all categories of network users : This criterion shall be measured by assessing the methods adopted to calculate charges and tariffs, as well as their structure, for generators, consumers and those that do both, and the operational flexibility provided for dynamic balancing of electricity in the network.

(d) Security and quality of supply : This criterion shall be measured by assessing the ratio of reliably available generation capacity and peak demand, the share of electricity generated from renewable sources, the stability of the electricity system, the duration and frequency of interruptions per customer, including climate related disruptions, and the voltage quality performance.

(e) Efficiency and service quality in electricity supply and grid operation : This criterion shall be measured by assessing the level of losses in transmission and in distribution networks, the ratio between minimum and maximum electricity demand within a defined time period, the demand side participation in electricity markets and in energy efficiency measures, 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 the actual availability of network capacity with respect to its standard value.

(f) Contribution to cross-border electricity markets by load-flow control to alleviate loop-flows and increase interconnection capacities : This criterion shall be estimated by assessing the ratio between interconnection capacity of a Member State and its electricity demand, the exploitation of interconnection capacities, and the congestion rents across interconnections.

(5)Concerning oil transport projects falling under the categories set out in Annex II.3, the criteria listed in Article 4 shall be evaluated as follows:

(a) Security of oil supply shall be measured by assessing the additional value of the new capacity offered by a project for the short and long-term resilience of the system and the remaining flexibility of the system to cope with supply disruptions under various scenarios.

(b) Interoperability shall be measured by assessing to what extent the project improves the operation of the oil network, in particular by providing the possibility of reverse flows.

(c) Efficient and sustainable use of resources shall be measured by assessing the extent to which the project makes use of already existing infrastructure and contributes to minimising environmental and climate change burden and risks.

ANNEX V

ENERGY SYSTEM-WIDE COST-BENEFIT ANALYSIS

The methodology for a harmonised energy system-wide cost-benefit analysis for projects of common interest shall satisfy the following principles laid down in this Annex.

(1)The methodology shall be based on a common input data set representing the Union’s electricity and gas systems in the years n+5, n+10, n+15, and n+20, where n is the year in which the analysis is performed. This data set shall comprise at least:

(a) in electricity : scenarios for demand, generation capacities by fuel type (biomass, geothermal, hydro, gas, nuclear, oil, solid fuels, wind, solar photovoltaic, concentrated solar, other renewable technologies) and their geographical location, fuel prices (including biomass, coal, gas and oil), carbon dioxide prices, the composition of the transmission and, if relevant, the distribution network, and its evolution, taking into account all new significant generation (including capacity equipped for capturing carbon dioxide), storage and transmission projects for which a final investment decision has been taken and that are due to be commissioned by the end of year n+5;

(b) in gas : scenarios for demand, imports, fuel prices (including coal, gas and oil), carbon dioxide prices, the composition of the transmission network and its evolution, taking into account all new projects for which a final investment decision has been taken and that are due to be commissioned by the end of year n+5.

(2)The data set shall reflect Union and national law in force at the date of analysis. The data sets used for electricity and gas respectively shall be compatible, notably with regard to assumptions on prices and volumes in each market. The data set shall be elaborated after formally consulting Member States and the organisations representing all relevant stakeholders. The Commission and the Agency shall ensure access to the required commercial data from third parties when applicable.

(3)The methodology shall give guidance for the development and use of network and market modelling necessary for the cost- benefit analysis.

(4)The cost-benefit analysis shall be based on a harmonised evaluation of costs and benefits for the different categories of projects analysed and cover at least the period of time referred to in point (1).

(5)The cost-benefit analysis shall at least take into account the following costs: capital expenditure, operational and maintenance expenditure over the technical lifecycle of the project and decommissioning and waste management costs, where relevant. The methodology shall give guidance on discount rates to be used for the calculations.

(6)For electricity transmission and storage, the cost-benefit analysis shall at least take into account the impact and compensations resulting from the application of Article 13 of Regulation (EC) No 714/2009, the impacts on the indicators defined in Annex IV, and the following impacts:

(a) greenhouse gas emissions and transmission losses over the technical lifecycle of the project;

(b) future costs for new generation and transmission investment over the technical lifecycle of the project;

(d) system resilience, including disaster and climate resilience, and system security, notably for European critical infrastructures as defined in Directive 2008/114/EC.

(7)For gas, the cost-benefit analysis shall at least take into account the results of market testing the impacts on the indicators defined in Annex IV and the following impacts:

(a) disaster and climate resilience, and system security, notably for European critical infrastructures as defined in Directive 2008/114/EC;

(b) congestion in the gas network.

(8)For smart grids, the cost-benefit analysis shall take into account the impacts on the indicators defined in Annex IV.

(9)The detailed method used to take into account the indicators referred to in points 6 to 8 shall be elaborated after formally consulting Member States and the organisations representing all relevant stakeholders.

(10)The methodology shall define the analysis to be carried out, based on the relevant input data set, by determining the impacts with and without each project. The area for the analysis of an individual project shall cover all Member States and third countries, on whose territory the project shall be built, all directly neighbouring Member States and all other Member States significantly impacted by the project.

(11)The analysis shall identify the Member States on which the project has net positive impacts (beneficiaries) and those Member States on which the project has a net negative impact (cost bearers). Each cost-benefit analysis shall include sensitivity analyses concerning the input data set, the commissioning date of different projects in the same area of analysis and other relevant parameters.

(12)Transmission, storage system and compressed and liquefied natural gas terminal operators and distribution system operators shall exchange the information necessary for the elaboration of the methodology, including the relevant network and market modelling. Any transmission or distribution system operator collecting information on behalf of other transmission or distribution system operators shall give back to the participating transmission and distribution system operators the results of the collection of data.

(13)For the common electricity and gas market and network model set out in paragraph 8 of Article 11, the input data set referred to in point (1) shall cover the years n+10, n+20 and n+30 and the model shall allow for a full assessment of economic, social and environmental impacts, notably including external costs such as those related to greenhouse gas and conventional air pollutant emissions or security of supply.

ANNEX VI

GUIDELINES FOR TRANSPARENCY AND PUBLIC PARTICIPATION

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

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

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

(d) the work flow, outlining each stage in the process, including an indicative time frame and a concise overview of the decision-making process;

(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.

(2)The detailed schedule referred to in Article 10(4)(b) shall specify as a minimum the following:

(a) the decisions and opinions to be obtained;

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

(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)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, 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. 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 from the beginning of the public consultation until the expiry of the deadline only.

(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;

(d) the human resources allocated to the respective 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 an information leaflet of no more than 15 pages, giving, in a clear and concise manner, an overview of the purpose and preliminary timetable of the project, the national grid development plan, alternative routes considered, expected impacts, including of cross-border nature, and possible mitigation measures, which shall be published prior to the start of the consultation; The information leaflet shall furthermore list the web addresses of the transparency platform referred to in Article 18 and of the manual of procedures referred to in point (1);

(b) inform all stakeholders affected about the project through the website referred to in Article 9(7) and other appropriate information means;

(c) invite in written form relevant affected stakeholders to dedicated meetings, during which concerns shall be discussed.

(6)The project website shall make available as a minimum the following:

(a) the information leaflet referred to in point (5);

(b) a non-technical and regularly updated summary of no more than 50 pages reflecting the current status of the project and clearly indicating, in case of updates, changes to previous versions;

(c) 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;

(d) contact details in view of obtaining the full set of application documents;

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

ANNEX VII

THE UNION LIST OF PROJECTS OF COMMON INTEREST AND PROJECTS OF MUTUAL INTEREST (‘UNION LIST’),

referred to in Article 3(4)

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.