Country Narratives

Until 2030, a first step towards a dedicated hydrogen network could be taken via blending and deblending into/from the existing infrastructure connecting Slovakia, Hungary, Slovenia, Italy and Germany. By 2030, GCA’s WAG pipeline could be entirely looped and one of TAGs parallel pipelines could be repurposed to transit hydrogen in both directions. With this, the Austrian network could serve two corridors to supply Germany with green hydrogen, Ukrainian green hydrogen from Slovakia via Austria and North African green hydrogen from Italy via Austria.

Upon completion, Austria’s grid would be ready as of 2035 to serve as a complete hydrogen hub in the region. Bidirectional hydrogen transportation possibilities at all interconnection points could be in place. In addition, GCA’s network would also transport H2 to Austrian (industrial) customers, such as one of Europe’s largest steel plants in Linz, which is already running trials for hydrogen-based steelmaking and a large refinery located near Vienna.

The Belgian national backbone is expected to emerge through developments mainly in and around the industrial clusters of Antwerp and Ghent, and along the industrial valley in Wallonia. Given the proximity between Antwerp and Rotterdam, port-to-port interconnections with the Netherlands are likely. In addition, interconnections with France and Germany will provide Belgium access for import/export of hydrogen from/to neighbouring countries. Hydrogen demand in Belgium in 2040 is indeed expected to exceed production capacity, so imports and exports with all neighbouring countries including the UK – if technical and economic conditions are right – and imports through the Zeebrugge terminal could be paramount in shaping the North-Western European Hydrogen infrastructure development. As such, thanks to all the interconnections and import facilities, Belgium will have become a true hydrogen hub importing and transiting H2 to neighbouring countries.

Bulgartransgaz EAD welcomes the EU’s plans for decarbonisation of the energy and industrial sectors and strives to be adequate to the pan-European priorities in the fields of climate and energy. In line with the European and National goals for climate neutrality and large-scale hydrogen deployment, Bulgartransgaz EAD is currently developing several projects in the field of hydrogen transmission:

• H2 ready pipeline in Maritsa Coal Region in Bulgaria;
• Retrofitting of the existing gas transmission network for H2/natural gas blends;
• New dedicated H2 infrastructure for transmission of pure hydrogen between the region of Sofia and the Bulgarian-Greek border near Kulata (connection with DESFA), allowing future expansion to Romania and the East Maritsa region.

These projects have the potential to become part of future European hydrogen transmission corridors.

Planning and reconstruction of the gas system for receiving and adding decarbonised gases into the natural gas stream will begin. This includes the development of a “smart gas network”.

• In compliance with the plans of the neighbouring operators, the existing interconnections will be repurposed to transport hydrogen by 2040,
• Hydrogen will be supplied to all major urban centres, the entire 75-bar system and parts of 50-bar system will be repurposed to receive and transport 100% H2, while it is anticipated that local biomethane production will be able to supply other areas,
• After 2040, the existing location of the LNG terminal will be repurposed to receive decarbonised gases and, if necessary, new evacuation infrastructure will be constructed,
• Potential new corridors for the transmission of decarbonised gases from the eastern Europe and the southern and eastern Mediterranean countries towards the central Europe will be developed.

There are several long-term gas transmission contracts in place. The major contracts expire at the beginning of 2035 and in 2039, respectively. The possibility for hydrogen transportation from the Eastern border with Slovakia to the Western border with Germany is shown in the updated maps in 2030. This option would – under certain circumstances still to be analysed – allow for initial hydrogen imports from Ukraine and North Africa in the early 2030ies by connecting major non-EU supply sources and regions with the hydrogen demand centres in the EU.  In addition, by 2035 the Gazelle pipeline could provide a large-scale connection for hydrogen transportation between the Northern and Southern regions of Germany.

The recent analysis has shown higher probability of East-West flows in the medium term horizon. For such a transport, the southern branch of the N4G system is a more suitable option. For 2040, the possibility for hydrogen transportation from the Eastern border with Slovakia to the border with Germany could be further strengthened by a pipeline on the northern branch which could provide an additional entry point to the EU hydrogen markets. Should the priorities on the respective entry into these markets change, such option may become available earlier.

As indicated by the National Hydrogen Strategy, additional hydrogen demand in the industrial regions, for instance close to the Polish border, is becoming more realistic in the late 2030s’. In the updated maps, there is a new connection to the hydrogen backbone based on a combination of partly repurposed and newly built pipelines. Such pipelines might also be providing a connection to the Polish system. Such option still has to be analysed. In addition, NET4GAS currently runs the incremental capacity process for a new connection to Austria. On the Czech side such a connection will be hydrogen ready and, if implemented, might provide additional hydrogen transportation options to the region.

By 2030, initial development of the Danish backbone consists of newly constructed hydrogen pipelines and the repurposing of an existing natural gas pipeline, connecting large scale hydrogen producers and industrial clusters with large scale storage facilities and export opportunities though the interconnection with Germany.

By 2035, Denmark seeks to draw upon its significant offshore wind resource in combination with electrolysis to attract new industries, such as e-fuels. The energy islands together with the buildout of large-scale onshore PV will be the drivers for the expansion of the national hydrogen infrastructure, which in the west expands into the North Sea enabling offshore hydrogen production at the energy island.

The eastern route is meanwhile extended by connecting the Copenhagen area with Sweden and through a new transmission pipeline that could be constructed from the Copenhagen area southwards towards Germany.

By 2040, the east and west backbones are connected across Denmark by repurposing the Baltic Pipe, which is further extended towards Poland to enable a supply connection, while a northern connection from Jutland towards demand areas in Sweden also emerges. In the North Sea a hydrogen interconnector is established between the Danish Energy Island and the Dutch offshore hydrogen production in area 6, thus enabling export of hydrogen produced offshore.

The 2030 – 2040 maps show many possible developments for hydrogen transport, which will co-exist with the biomethane grid. What specific pipeline developments are realised depends on the societal economic value, and demand situation in the future.

In the beginning of the 2030s, the first offshore windfarms are expected to be present west of Estonia, in the Baltic Sea. Due to the large volumes of energy produced in offshore wind farms, compared to the relatively small electricity demand in the Baltics, hydrogen production could be economically feasible early on. This renewable energy oversupply could open a possibility to export green hydrogen to Central Europe with pipelines inthe second half of 2030s.

Until the Estonian renewable energy production capacity ramps up, Estonia could act as an onshore transit corridor from Finland to other Baltic states and Poland. As such new build hydrogen pipelines would be a great undertaking for a small country like Estonia, the realization would largely depend on the demand side interest funding and multinational agreements. For this hydrogen transit pipeline to be possible in 2030, strong incentives from both EU, regional and national level are needed, in the form of rapid planning, permitting, securing appropriate funding and agreement on tariffing.

By 2040 further offshore wind power expansion is expected together with hydrogen production in western Estonia, that could supply other regions needing green hydrogen.

Hydrogen infrastructure in Finland is envisioned to develop in three strategic geographical areas; Bothnian Bay region and the west-coast with significant renewable energy sources and identified H2 demand, south and south-east Finland (Uusimaa & Kymenlaakso areas) with significant existing and expected hydrogen demand and the Southwest Finland & Satakunta areas with potential hydrogen demand and significant renewable energy resources.

The development of these hydrogen valleys could emerge due to identified significant use of hydrogen in industry (low-carbon fuel production, chemicals, steel, mining) and possibility to utilise clean energy resources for hydrogen production as well as for supporting also Finland in achieving its 2035 carbon neutrality targets.

As a large part of the supply and demand is expected to develop in regions where there is no (or only limited) existing gas transmission infrastructure, the hydrogen infrastructure is envisioned to be based on new built pipelines.

Therefore, Gasgrid Finland and Nordion Energi (Swedish gas TSO) have started to jointly develop a large scale greenfield cross-border hydrogen infrastructure – Nordic Hydrogen Route https://nordichydrogenroute.com/ - in the region of Bothnian Bay with the target of having the network operational by 2030. The Bothniab Bay onshore interconnection to Sweden could create a Finnish-Swedish hydrogen market at the Bothnia Bay area. Also, another interconnector to Sweden could be developed with direct subsea route crossing the Gulf of Bothnia with potential offshore connection also to Germany.

In addition, the Finnish hydrogen network could develop around hydrogen valleys in the south, southeast and southwest of Finland already during this decade. To support the development of the energy system and creation of hydrogen market, the hydrogen valleys could also be connected. A connection along the west coast of Finland enables more extensive utilization of wind for hydrogen production and aids the energy transfer from north to south. A possible subsea interconnector to Estonia connects Finland to the Baltics and to potential demand markets in central, northern and eastern Europe.

By 2040, national hydrogen valleys are envisioned to be connected, and a national hydrogen network developed. Up north, the hydrogen grid could extend further north, and potentially also additional north-south pipelines could be developed. Even further expansion of the Finnish hydrogen network could facilitate accelerated deployment of wind power to fully utilise the potential enabled by great land availability in the northern and eastern parts of Finland.

By 2030, regional dedicated hydrogen networks will emerge around industrial clusters, with existing fossil hydrogen production or consumption, in Dunkerque, in the Seine Valley from Le Havre to the vicinity of Paris, and around Lyon, Lacq and Marseille. The hydrogen cluster around Dunkerque will be supplied with decarbonised hydrogen from offshore wind, as well as low-carbon hydrogen. This cluster will also co-benefit from the hydrogen valleys in Belgium and the Netherlands. In the east of France, a regional cluster will also develop at the border between France, Germany, and Luxemburg with the commissioning of the mosaHYc project. Another Hub will also emerge in the south of Alsace were clean hydrogen is needed in the fertilizer and chemical industry, paving the way for an interconnexion with Switzerland and Germany in the longer term

The southern clusters in Marseille-Fos and Lacq are also expected to have access to green hydrogen from solar PV and Mediterranean offshore wind. Lastly, dynamic development of green hydrogen for fuel cell projects and industrial uses is expected to continue and to lead to a need for a dedicated hydrogen pipeline in the region surrounding Lyon. As of 2030, a third interconnection between the Iberian peninsula and France will be operating, concretising the Backbone.

By 2035, additional hubs emerge near Saint Nazaire/Nantes, Bordeaux and along the Mediterranean coast, powered by offshore wind or low-carbon electricity and combined with the evolution of Seaports activities. Those hubs will connect to Region of Paris, and to Lyon along the Rhone Valley, thus enabling the decarbonisation of existing grey hydrogen consumptions and the development of new hydrogen uses in mobility (road, inland navigation, rail, airports). The North-West of France will also be connected to the East of France and to the Region of Paris via the retrofitting of existing gas pipelines. This will enable interregional transit and an easier integration of renewable electricity in the energy system, and it will bring flexibility to the system.

The French network will also allow a transnational transit from Spain to Belgium, Germany or Luxembourg. By 2040, a mature network has emerged of mostly repurposed pipelines which has 3 interconnectors with Spain, while also connecting to Belgium, Germany, and Switzerland. The three interconnectors to Spain enable security of supply and flexibility in the large, expected flows of hydrogen from Spain and possibly North Africa into the rest of Europe. On the west side another stretch also provides a different route within France to transport hydrogen, while also serving local customers and industry on the way. In the South, Teréga’s storage locations would build on synergies with renewable hydrogen from Spain and Portugal, enabling a stable and secure hydrogen supply further up North.

As part of the network development plan (NDP) 2020-2030, the German transmission system operators (TSOs) have published first plans for an initial national hydrogen network 2030 based on a market survey in 2019. Further elaborations by the TSOs regarding projections about future production and demand of hydrogen have resulted in the national hydrogen network maps for 2030 and 2050 published by FNB Gas in November 2021.

These maps feature more extended hydrogen networks than those displayed in the network development plan (NDP) 2020-2030, as a higher hydrogen demand and subsequently larger transport volumes are taken into account. The work is based on a scenario for the production and use of hydrogen in Germany developed together with the consulting company 4Management on the basis of the recognised DENA pilot study I (TM95).

The NDP 2022-2032 is currently being prepared and its publication with updated hydrogen networks will take place later this year.

The German hydrogen network 2030 connects different demand clusters like Ruhr Area, Rhine-Main Area, Eastern Germany, Central German chemical triangle and Bavaria with hydrogen sources in Germany, especially in the North, and with important import routes. As such, pipeline connections to the Netherlands, the North Sea and to Denmark and to Poland and the Baltic Sea for integrating offshore pipelines and possible imports are foreseen. While in the Southeast import connections to Austria and the Czech Republic emerge. In the West, connections to Belgium and France occur, while a new connection to Poland in the East will be available for imports to meet growing national demand in different regions.

The compiled German H2 network has a total length of about 5,200 km by 2030, with some 3,700 km of repurposed natural gas pipelines, and would be able to meet a hydrogen demand of around 70 TWh.

By 2040, a new interconnection emerges to Switzerland and an additional connection with Poland and Czech Republic, thereby further enhancing security of supply.

The German H2 network for 2040 is derived from the FNB Gas network publications for 2030 and 2050.

(The published FNBGas H2 network for 2050 has a total length of about 13,300 km with about 11,000 km of repurposed natural gas pipelines and can provide an energy quantity of 504 TWh (net calorific value) at a peak demand of around 110 GWh/h.)

By 2030, up to four of the five industrial clusters could be connected and will form the basis of a GB hydrogen transmission backbone. Due to the sensitivities around industrial cluster developments, National Grid Gas does not hold any views on the phased sequencing of which industrial clusters are likely to connect first as it relates to this study. Additionally, there may be connections to St Fergus in north Scotland and Bacton on the east coast, providing additional hydrogen supplies which could help integrate the large amounts of renewable energy from offshore wind.

By 2035, it is possible that all clusters could be connected. A converted pipeline to Bacton, located on the east coast, could enable future hydrogen flows across the interconnectors between GB and Belgium and GB and the Netherlands once ready. Further repurposed pipelines may start to emerge between 2035 and 2040, including a connection to Moffat, enabling hydrogen to flow across the interconnector between GB and Ireland alongside natural gas flows.

As hydrogen production scales, further expansion of this hydrogen network will occur throughout the 2040s enabling a greater reach across industrial, power, transport and domestic heating sectors. The maps represent the selection of pipelines that could have started the hydrogen repurposing process but may not have completed full conversion by the date on the map. Sequencing and formally defined routes have not been determined, therefore some of these pipelines could be converted in the following 5 to 10-year period.

By 2035, Greece’s main industrial clusters in Athens, Corinth and Thessaloniki would be connected, with new dedicated hydrogen pipelines following the existing natural gas route. The potential hydrogen cluster in West Macedonia will also be connected to Thessaloniki, near the existing connection to TAP, through the new, hydrogen-ready pipeline in the region, which is currently under development.

Storage could be available in the form of an aquifer near the Island of Thasos. This dedicated hydrogen pipeline will offer the opportunity to potential large hydrogen consumers across the country (e.g., refineries, chemical industries, etc.) to have access in their required volumes of green hydrogen. Apart from industry, the biggest hydrogen potential, in terms of end-user perspective, is expected to be the transportation sector, and more specifically heavy-duty vehicles and trains.

By 2040, the dedicated hydrogen pipeline could be interconnected with adjacent systems, so that hydrogen can flow from Greece towards South-East, South-West and Central Europe. As TAP will be directly connected with our system, there will be interconnectivity with the Italian transmission system and subsequently with Central Europe, where significant pure hydrogen demand is foreseen.

At the same time, the interconnection Greece to North Macedonia, and from there to Kosovo, will be hydrogen ready for future use. Finally, ports in the vicinity of the pipeline, with future import infrastructure for hydrogen (or any forms of it), could also be connected.

By 2030, changing gas flows open up part of the network to be repurposed for hydrogen transport. This could already mean the repurposing of the interconnector with Ukraine which would connect the Hungarian market to the large hydrogen potential supply from Ukraine. The rest of the network connects several industrial customers in the chemical and fertiliser sector.

If there will be enough hydrogen production by 2035, Hungary could already have a mature - mostly repurposed - hydrogen network with now in total 7 interconnections to Ukraine, Austria, Slovakia, Serbia, Romania , Croatia and a new one with Slovenia. This would connect all Hungary’s neighbouring countries and the mostly coal based nations in south-eastern Europe to Ukrainian hydrogen, effectively making Hungary a green hydrogen transit country enabling the decarbonization of heavy industry in south-eastern Europe and the transition away from coal. Interconnections to Slovenia and Austria would already by 2035 connect the energy systems of south-eastern Europe and North-western Europe.

By 2040, the interconnection to Slovenia could increase the market liquidity and security of supply of hydrogen from the direction of the Northern Africa - Italy route.

By 2035, a hydrogen “valley” network could emerge around the city of Cork, on Irelands’ south coast. Supply resilience for this mainly green hydrogen cluster would be assured with supplementary imported hydrogen which could be either tanker or interconnector sourced (via a hydrogen pipeline direct to the continent).

By 2040, one of the 2 Moffat interconnectors from the UK could be converted for 100% hydrogen transport and some relatively small-scale reconfiguration of the Dublin gas transmission network could enable local, scale, hydrogen – fired power generation. The other Moffat interconnector could sustain resilient supply to the remaining unconverted network, it no longer having to serve the Cork cluster and Dublin power generation loads.

Development of these dedicated hydrogen networks provide for accommodation of and ready market access for scale green hydrogen and could create the potential for future (through the 2040’s) extended gas network conversion to hydrogen, hydrogen consumption for residential heating and industry and ultimately green hydrogen export to Great Britain or beyond.

By 2030, The Italian backbone may stretch from Sicily till the hydrogen valley of Emilia Romagna supporting an accelerated development of hydrogen in the country as indicated by the Guidelines on the Italian National Hydrogen Strategy. These developments will be coupled with the potential to import hydrogen from Tunisia, fully exploiting the cost advantage of solar production and land availability in Northern Africa. Most of these developments will consist of repurposed natural gas pipelines as a result of the availability of parallel routes.

Hydrogen could potentially be transported both from North Africa and from injection points in Southern Italy to industrial clusters in the South and potentially integrating the blue production in the North that could serve industrial uses in the area. The connection to Austria could allow hydrogen from North Africa to be used in Northern Europe, provided that gas consumption would be gradually replaced by hydrogen and gas security of supply and balancing needs were guaranteed.

On the Eastern side, the interconnection to Slovenia connects two large potential supply regions - Ukraine and North Africa. By 2040, an interconnection to Switzerland could be added to provide another connection to North-Western Europe.

Current gas system is underutilised. There are some possibilities to potentially repurpose existing gas transmission and storage infrastructure, but also new pipelines will need to be built, to adjust the gas system to higher hydrogen blend or pure hydrogen.

Latvia has an underground natural gas storage (an aquifer), the only gas storage in Baltic States with active gas capacity 2.3 bcm, that could potentially be used in the future for hydrogen storage, after appropriate research and technical adjustments. The gas TSOs of Estonia, Finland, Latvia, and Lithuania in 2021 has already started preparation of research and development study of technical capabilities for injection and transportation of hydrogen in gas grid, study is expected to be finished in 2024 and the results will be used to decide on further hydrogen infrastructure development.

Potentially in the upcoming decade, energy transition projects, such as Power-to-Gas (hydrogen or synthetic methane) could be developed in Latvia, based on hydrogen related national policy framework development. Hydrogen production and infrastructure development could potentially help develop new industries in the future.

Lithuania together with the Baltic Region is named as a potential region for the development of surplus wind energy. That creates preconditions for the development of the market of green hydrogen. Adaptation of existing infrastructure and creation of new energy transmission corridors are becoming particularly important. It is expected that the Lithuanian pure hydrogen network, will mostly consist of natural gas pipelines adapted for the transportation of hydrogen. This infrastructure will stimulate the development of RES hydrogen production capacity.

According to the forecasts of the Ministry of Energy, Lithuania’s renewable electricity generation capacity will significantly increase in 2025, exceeding the peak demand of the country (2500 MW). The capacity of onshore wind farms will reach 1800 MW, solar power will reach 1000 MW and offshore wind power will reach 700 MW in 2028. These renewable electricity capacities will even be doubled by 2030. Part of the surplus renewable electricity will be used for production of pure hydrogen and will enable development of the pure hydrogen grid.

As of 2030 a demand for hydrogen is expected in the Lithuanian fertilizer production sector. Main consumption will take place in the central part of the country, where the hydrogen grid will be built (or adapted) first. Later, it is planned to connect the oil refinery in the north-west of Lithuania. Also, it is planned to connect the western and central hydrogen corridors of the country, as well as to connect the hydrogen networks with Latvian and Polish hydrogen networks, creating a regional hydrogen corridor connecting Finnish, Estonian, Latvian, Lithuanian and Polish grids.

In the medium term, priority is put on the potential hydrogen supply of industrial clusters connected to a cross-border hydrogen infrastructure.

By 2040 a full connection to the European hydrogen backbone via Belgium and Germany can be envisaged, requiring a new pipeline between the Belgian and German hydrogen networks at Bras respectively to the MosaHyc project near Remich. Another option might be the repurposing of an existing pipeline if the operation of an existing gas interconnection would no longer be justified for the supply of existing gas customers. The Luxembourgish hydrogen network could potentially be used for transit flows.

By making maximum use of the existing natural gas transport infrastructure, the national hydrogen backbone can have a capacity of approximately 10-15GW by 2030. The national hydrogen transport network will be developed in phases, following and facilitating the hydrogen market development. The aim is to connect the Rotterdam-Rijnmond region with the area ‘Noordzeekanaalgebied’ (steel-production) and the Northern Netherlands first. With this first step, these regions will also gain access to underground hydrogen storage at Zuidwending and to Germany.

The Schelde-Delta region, including a connection with Belgium, will also be developed at an early stage, but might be able to function as a stand-alone cluster in the first year after development. The connection of the Schelde-Delta region to the other aforementioned clusters will follow next, after which the network-connection towards and in the province of Limburg will be developed.

The “ring” will be completed by 2030, but Gasunie emphasises that connections to storage and neighbouring countries for all clusters are possible at an earlier stage (2027). Moreover, Gasunie is investigating the connection of industries that are not situated in one of the major industrial clusters.

Gasunie and partners will also be working together to develop the ACE ammonia import terminal. The terminal will operate on the Maasvlakte near Rotterdam and will include an installation for converting ammonia into hydrogen to supply future Northwestern European hydrogen demand. It will also supply ammonia directly to amongst others the fertiliser industry. Work on the basic design of the import terminal will start in Q2 2022, and it will be operational from 2026, connecting to the ‘Dutch hydrogen backbone’ that can serve the future hydrogen market in Northwestern Europe. Furthermore, by mutually aligning plans for hydrogen transport and storage, joint Dutch and northern German hydrogen infrastructure is very much a possibility, for example the Hyperlink project in Germany.

Gasunie is also involved in the German offshore hydrogen infrastructure initiative AquaVentus, which aims to construct Germany’s first offshore hydrogen backbone in the North Sea, with possibilities to connect to Dutch, Danish and Norwegian hydrogen infrastructure.

Additionally, renewable hydrogen will be used to integrate large amounts of offshore wind energy, particularly in the north of the Netherlands and Germany. More than 180 GWs of offshore wind will be built by 2050 in the North Sea, which will create challenges to integrate this into the energy system. This integration can be economically done by an internationally coordinated development plan of energy hubs, including off- and onshore ‘power to hydrogen’, as well as system integration between the power- and hydrogen network.

A vital role is foreseen for hydrogen to integrate the large amounts of energy into the system and provide seasonal storage. This hydrogen network is also expected to become crucial to stabilise the power grid with new hydrogen fired power plants.

The pipeline system operated by Gassco transports natural gas from NCS through three large processing plants on the west coast of Norway to Germany, Belgium, France and UK. The potential for hydrogen production from natural gas and from renewable power sources is being studied for all three Norwegian processing plants.

By 2030, Norwegian hydrogen production could be in the order of 2-3 GW, further ramping up to 10-15 GW by 2040. Gassco is investigating export solutions for these production volumes and is assessing development of new dedicated hydrogen pipelines, conversion of existing natural gas pipelines, as well as a combination of new and existing pipelines. Blending of hydrogen into the natural gas export stream is also part of the study work.

In 2030, based on available system capacity, one of the export pipelines downstream the riser platforms Draupner or Sleipner could be repurposed to hydrogen transport. This could for instance be the Europipe pipeline from Draupner to Germany, but the other export pipelines, Zeepipe, Franpipe and Langeled South are also relevant depending on the market for hydrogen. Pipelines upstream Sleipner and Draupner will not be available for dedicated hydrogen transport until after 2035. Transport of pure hydrogen in 2030 would require a combination of existing and new pipelines to establish an export route from Norway to Europe.

A new pipeline, for instance from Norway to the Netherlands, is also an option, however this would have to be sized for volumes expected in 2040. Blending of hydrogen into the natural gas export stream could also be another option to allow usage of the existing natural gas pipelines from 2030.

Green hydrogen from offshore wind energy hubs can complement blue hydrogen supply in 2035, and depleted hydrocarbon reservoirs could become available for hydrogen storage between 2030 and 2040. In 2040, based on current gas market forecasts, another export route from Norway, for instance to Great Britain, could be envisaged by repurposing the Langeled South natural gas pipeline.

A possible scenario assumes that the initial hydrogen network in Poland will be formed around 2035mainly around offshore wind energy potential in the North and industrial clusters in its vicinity (Pomorskie voivodship), as well as the centre (Kujawsko-Pomorskie and Mazowieckie voivodship). In addition, the potential of an underground storage facility - the Damasławek Project - is expected to be significantly exploited at this time. This storage facility is based on a system of salt caverns and makes it possible to store energy from wind at sea and use it later during periods of low wind speed. This makes it an important alternative to gas or even coal peaker power plants. The Damasławek project will play an important role in linking industrial clusters and planned hydrogen valleys.

In this perspective also a transit connection between Finland and the Baltic States via Poland to Germany may be implemented. This is strictly connected with a pace of H2 production potential in these countries and the demand level in Germany, as well as ability to create a feasible financing structure (relevant tariff scheme, long term commitments, etc.) for such size infrastructure project. Implementation of this transit connection would allow to integrate the emerging Polish hydrogen network, in particular UGS Damasławek, with the rest of Europe. In case that the very promising forecasts of hydrogen supply from the direction of Finland via the Baltic States would materialize, the construction of a dedicated hydrogen transit link to Germany in parallel to the gas interconnection GIPL (currently under construction) might be justified.

Since the Polish Hydrogen Strategy provides for verification of its assumptions in 2025, it will then be possible to make preliminary verification of the dedicated hydrogen interconnection plan with Lithuania assuming a transit connection with Germany in order to enable a transfer of hydrogen from Finland to Germany about 2035.

After 2040, all planned Polish industrial clusters (Hydrogen Valleys) are to be connected, and a north-south connection would complete the integration of large amounts of renewable energy in the north from offshore wind, as well as potential imports from Scandinavia (via Baltic Pipe) and the Baltic States via GIPL that would be repurposed. Additionally, around 2040 there may be a possibility of repurposing a section of the gas pipeline connecting the FSRU in the Gulf of Gdansk with the rest of the planned infrastructure (North-South corridor). This gives flexibility in the form of using hydrogen supplies delivered by sea (with favourable market conditions possible replacement of the Floating Storage Regasification Unit).

The development of the internal H2 transmission system after 2040 (as well as interconnections), is associated with the forecasted increase of hydrogen consumption in Poland that may lead to becoming a H2 net consumer. Such market circumstances would create the potential need for repurposing of the interconnections (GIPL, Baltic Pipe) and creating new ones, i.e., Poland – Czechia interconnections.

Moreover, the increasing demand for hydrogen in Western Europe, in particular in Germany is expected to be a reason for implementing the second transit infrastructure corridor via Poland, i.e., from Ukraine to Germany.

Finally, in the perspective of 2040+, it is possible to create a mature H2 infrastructure giving the possibility of connecting Poland, additionally, with the Czech Republic, Ukraine and Denmark / Sweden These infrastructure developments would contribute very much to the role of Poland as a real integrator of the regional hydrogen market.

Since repurposing of existing network is not always an option due to increasing demand for natural gas in Poland, technical constraints and the age of existing pipelines, the development of the H2 transmission system in Poland will consists also of the newly built infrastructure.

It should be noticed that an important factor to consider for a hydrogen network in Poland is the currently growing consumption of natural gas, which will still require a significant portion of the Polish transmission system by 2040.

Any repurposing/reconstruction solution will be carefully evaluated on a case-by-case basis due to the technical limitations and heterogeneity of the existing network. The analysis of such potential in the material area has already been started by GAZ-SYSTEM - mapping of the potential, analysis of the transmission system itself and its possible cooperation with hydrogen is underway.

By 2030, at least up to two dedicated industrial clusters (at North and South of the country) could be supplied by dedicated 100% Hydrogen closed loop integrated network systems with a length of around 20 km.

At this stage, REN expects further developments in blending demand to foster the Hydrogen accommodation in gas grid and to promote the decarbonisation of gas system (up to 15% of blended Hydrogen, in 2030 horizon).

From there the next step is to gradually switch the existing network to a fully 100% hydrogen network, coping with the Hydrogen and gas demand in Portugal. Hydrogen and natural gas demand evolution will be critical for this process, as the fully switch from natural gas to Hydrogen, would require adaptation and investments on the utilization side.

From 2035 onwards, it is expected Portugal could receive and share hydrogen, through the northern IP connection to the Spanish Grid, by repurposing the actual gas transmission grid, depending on the development of the Spanish Hydrogen network .

From 2040 onwards, hydrogen import/export would also be possible through the east-west gas repurposed gas pipeline, considering the region existing good renewable hydrogen production potential.

By 2040, it is expected that approximately 40-50% of the grid could be repurposed and operated with 100% Hydrogen.

Underlining the importance of establishing a national strategy on hydrogen, a strategy for the implementation of the European Green Deal, in the current European and national context, at SNTGN Transgaz SA level, the sustainable development strategy of the NTS for the coming years requires a resetting of objectives, a reshaping of the development model so that it allows the implementation of the provisions of the Green Deal. Thus, in order to create the "backbone" of the hydrogen transmission system in Romania, the need to repurpose several strategic transmission corridors as shown on the map has been identified.

In this respect, in 2030 Romania can be interconnected with Hungary, Bulgaria via the current BRUA corridor whereas another connection is envisaged with Republic of Moldova in north-eastern Romania.

By 2035, in south-east Romania the Trans Balkan pipeline will stretch from the Ukrainian border to the Bulgarian border, while in north, a hydrogen pipeline will stretch from the existing UA/RO IP to central Romania, insuring in this way potential hydrogen import/export routes. All these pipelines as well as BRUA corridor are interconnected via the central hydrogen backbone.

In western Romania, the interconnection with Serbia is also envisaged for 100 % hydrogen use.

By 2030 the Slovak connection between Austria and Czech Republic could be repurposed to supply hydrogen from North Africa further towards consumption centers through interconnection points Baumgarten and Lazhot. By 2035, Eustream intends to repurpose one of its large diameter pipelines from Ukraine in the East to the Austrian and Czech networks in the West.

In the beginning with green hydrogen flows still picking up, the lower capacity of hydrogen flowing the repurposed network would also serve the currently coal-based steel industry and chemical industry in Slovakia. Repurposed interconnections to Hungary and Poland would connect another multiple markets and provide higher security of supply as of 2035.

By 2035, a regional backbone could emerge. The current main gas pipeline is doubled and together with the changing gas flows due to changes on energy markets, new interconnection with Hungary, and upgrade of connection with Croatia, it enables the repurposing of parallel natural gas pipelines. Thus, the domestic production and consumption can be connected.

There would be hydrogen interconnections from Slovenia to Hungary and Italy which connects the national hydrogen markets, but also major green hydrogen supply sources (e.g., North Africa). The connection to Austria and Croatia would ensure that the European Hydrogen Backbone becomes an integrated hydrogen network stretching from South-Eastern to North-Eastern Europe.

By 2030, industrial clusters within reach of the proposed parallel network and therefore relevant for initial development of the backbone are along the Mediterranean coast and in the north of Spain. Later, the development of the network will guarantee cohesion between the different demand regions, also integrating the multiple supply points that will be distributed across the geography. Spain’s long-term ambition is to be one of the main hydrogen suppliers in Europe, building on its significant large-scale solar PV and wind and hybrid potential to produce green hydrogen.

The national backbone will enable this by connecting to France through a new route through Catalonia by 2030 and the existing connections by Irún (2030) and Larrau (2035) Connections to North Africa can be made from 2035 to complement supply with imports from the south to cover the demand in Central Europe. With Portugal, it is also planned to build a new connection by Zamora (2030) and to repurpose the current ones of Tuy (2035) and Badajoz (2040).

Nordion Energi has, together with Gasgrid Finland, started to jointly develop a greenfield cross-border hydrogen infrastructure in the region of Bothnian Bay (Nordic Hydrogen Route) with the target of having the network operational by 2030. At about the same time, as a response to REPowerEU, an offshore hydrogen connection from the Bothnian Bay, across the Baltic Sea with potentially multiple interconnections to the onshore hydrogen networks in Sweden and Finland, to Central Europe is envisioned. The latter strategically located to collect and enable export of potential excess of off-shore wind and green hydrogen production in the area.

By 2035, the southern backbone stretches further north not far from the Stockholm region of Sweden, linking industrial demand centres and cities in southern and central Sweden. Around this time, the southern and northern backbones connect, creating a hydrogen corridor across the country, linking the backbones of Denmark, Sweden, and Finland to the European hydrogen backbone. A new energy transmission network from north to south would in this way be a reality.

By 2040, an additional interconnection (offshore) from Denmark could emerge via the Kattegat Sea area, which would then be the fourth possible interconnector for Sweden.

A large-scale hydrogen demand post 2030 is expected if the EU wants to honour the Green Deal & Paris Agreement. The Transitgas pipeline links North West Europe to South East Europe and is the shortest route from Italy to NW Europe. It is therefore an ideal partner to ensure the necessary imports from outside Europe and more specifically from North Africa, can reach its destination without capacity constraints on the way.

North Africa is considered to be one of the most promising regions for the production of renewable hydrogen. The exact timing for the development of H₂ transmission infrastructure in Switzerland will mainly depend on the development of the adjacent H₂markets and the need for import/export between these markets.