European
Hydrogen Backbone
IMPLEMENTATION ROADMAP —CROSS BORDER PROJECTS AND COSTS UPDATENOVEMBER 2023
Amber Grid, Bulgartransgaz, Conexus, CREOS, DESFA, Elering,
Enagás, Energinet, Eustream, FGSZ, FluxSwiss, Fluxys Belgium,
Gas Connect Austria, Gasgrid Finland, Gassco, Gasunie, GASCADE,
Gas Networks Ireland, GRTgaz, National Gas Transmission,
NET4GAS, Nordion Energi, OGE, ONTRAS, Plinacro, Plinovodi, REN,
Snam, TAG, Teréga, Transgaz, Transitgas AG and the TSO of UA

Tableof contents

Executive summary

4

1. The role of EHB within the European energy transition

7

1.1 Hydrogen’s key role for European climate policy

7

1.2 The EHB initiative: a collaborative effort to build out the clean hydrogen infrastructure network8

1.3 The clear benefits of an integrated pan-European hydrogen network

9

2. Current EHB progress to date11

2.1 Typical hydrogen infrastructure project timelines

11

2.2 Overall network development and project timelines

12

2.3 Corridor-specific development

14

3.3.1 Corridor A — North Africa and Southern Europe

14

3.3.2 Corridor B — Southwest Europe and North Africa

15

3.3.3 Corridor C — North Sea

16

3.3.4 Corridor D — Nordic and Baltic Regions

17

3.3.5 Corridor E — East and Southeastern Europe

18

3.3.6 Transmission Network in Germany

19

3. Update of pipeline infrastructure costs20

3.1 Cost inputs and results

20

3.2 The impact of inflation

23

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Table of contents(continued)

4. Conceptual framing of the financial challenge

24

4.1 IRC — conceptual framework25

4.2 UFG — conceptual framework27

5. What to expect from the EHB in 2024

28

6. Appendix

29

6.1 Appendix A: selected projects to create EHB by early 2030s

296.1.1 Corridor A — North Africa and Southern Europe

29

6.1.2 Corridor B — Southwest Europe and North Africa

32

6.1.3 Corridor C — North Sea

34

6.1.4 Corridor D — Nordic and Baltic regions36

6.1.5 Corridor E — East and Southeast Europe

37

6.1.6 Transmission Network in Germany

39

Imprint
Supported by:
Guidehouse

Authors:
Robert Slowinski, Yasin Sagdur, Rik van Rossum, Alex Kozub,
Martijn Overgaag, Ana Amazo Blanco, Alizé Michelet,
Geoffrey Ho, Stephanie Kandathiparambil, Poppy London
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Date:
November 2023
Contact:
Guidehouse
Stadsplateau 15, 3521 AZ Utrecht
The Netherlands+31 30 662 3300
guidehouse.com

Picture credits:
Title motif based on a map of ENTSOG(see https://transparency.entsog.eu/)
Design:Leah Di Meglio, Carolyn Gray, Elizabeth Bell

Motivation

Executive
summary

Building out an integrated pan-European hydrogen network before 2030 is of
critical importance to Europe’s goals for the energy transition, including energy
affordability, security, and independence. Early hydrogen infrastructure enables
a competitive European energy transition on multiple fronts, facilitating largescale deployment of renewable energy and hydrogen production, allowing forhydrogen production in regions where costs are low, and enabling imports fromthird-party countries. Cross-border infrastructure has been and remains a crucialcomponent of the energy value chain—connecting supply with demand andstorage and sending important signals to mitigate perceived financial risk formarket participants, project developers, and downstream end users. To fulfill
Europe’s hydrogen objectives, hydrogen infrastructure will be paramount.
Existing progress and momentum
The buildout of the European Hydrogen Backbone (EHB) network is wellunderway. Transmission System Operators (TSOs) are planning to make substantial
investments and can point to tangible progress on corridor projects. All fiveenvisioned corridors1 have projects currently in progress, with a clear majority
of EHB member TSOs working on implementation and producing real progressin their countries.
This report highlights a set of 40 concrete projects managed by the EHB’s TSO
members, representing 31.500 kilometres of hydrogen pipelines with expectedcommissioning prior to 2030. TSOs are actively seeking sufficient contractual
commitments from future network users to underpin their investment decisions
in hydrogen networks. With the EHB moving from a vision towards reality, thefirst financial investment decision (FID) in a project which is part of the backbone
has already been taken. Furthermore, together, the TSOs are using their existing
expertise with gas networks and working to ensure that the EHB is not just a
vision but a tangible reality that will support and accelerate the European energy
transition.
Updating costs from EHB’s flagship 2020 publication
The world has undergone substantial changes since the initial publication of
EHB cost estimates in 2020. Globally impactful factors like COVID, the Russian
invasion of Ukraine, rising inflation, and policy responses to climate change haveall influenced implementation costs. This report presents an updated, bottom-up
accounting of unitary costs for capital expenditures (CAPEX) and developmental
expenditures (DEVEX) of pipelines and compressors, based on new primary datacollected from the TSOs’ real-world projects.

1

EHB (2022). Five hydrogen supply
corridors for Europe in 2030. Source:
EHB-Supply-corridors-presentationExecSum.pdf

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Costs are nominally higher as compared with the 2020 update but are shown to
be largely in line with economy-wide inflation (of course, the broader impacts ofinflation are felt across nearly all sectors, including other energy vectors). The
cost data in this report reflects Europe-wide average numbers. However, it isimportant to consider that energy infrastructure costs tend to be highly projectspecific, with geographic, demographic, and other factors playing an importantrole in project economics.

Framing the financial challenge
Conceptually and once operational, the EHB network is likely to encounter two
distinct financial phases that are linked to the development of the European
hydrogen economy. The first of these phases represents the market ramp-up,
involving limited hydrogen demand and low booking of capacity on the hydrogen
network. However, as the hydrogen economy develops and demand rises, themarket will transition to the later, mature market phase.
Defined here, the investment recovery challenge (IRC) arises from the potential
financial disparity between the regulated revenue cap and the revenue that canbe earned from network users on account of real network capacity bookings
during the initial market ramp-up phase. A simplified way to interpret the origin
and timing of this challenge is presented conceptually in Figure 1. Please notethat some pipelines will be financially feasible from the start of operation andnot only during the mature market phase, in particular in case of high share of
repurposing. Therefore, this graph is not a reflection of the real dynamics ofthe entire EHB network but rather a simplification of a single pipeline, used toillustrate the structure of the IRC framing.
Underpinning this potential challenge is the possibility that demand might take time
to develop, as market design enablers will take some time to be fully developedand implemented. (These include, for example, RED III obligations, European
Union [EU] and national policy enablers, and subsidies for renewable and low
carbon hydrogen production to enable hydrogen to become increasingly costcompetitive with fossil fuels.) The impact of demand development over time canbe observed via the teal line in Figure 1. The hydrogen demand, and equally theuse of the booked capacity, increases until a steady booked capacity is observedin the mature market phase. This increase in booked capacity allows TSOs tolower tariffs until the market transition to the mature phase.
Figure 1
The IRC and level of tariff required
to realise regulated return.

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The extent of the potential financial challenge of course depends on the amountof public financial support for infrastructure, the share of existing infrastructurethat can be repurposed, as well as the location of supply and demand centers(which are very much country specific).

The upfront financing gap (UFG) is a consequence of the IRC and represents thedifference between the total required upfront investment prior to project operation2
and the ability of a TSO to finance the project. Policymakers could mitigate
the challenges associated with a potential UFG by developing mechanisms to
manage market risk while in parallel allocating public funding or guarantees tomitigate the IRC where relevant. These mechanisms should be designed in a waythat network development is sufficiently derisked and able to attract market-rate
investment to finance its buildout.
Conclusions and looking forward
EHB member TSOs are moving ahead with real, tangible progress on buildingout a Europe-wide hydrogen network. Investment in the EHB is a necessary step
forward for achieving lowest-cost societal decarbonisation in Europe. Hydrogenmakes use of plentiful European and neighboring resources, serves a multitudeof sectors—including those typically viewed as hard to decarbonize—andprovides connectivity and resilience across the continent. Furthermore, building
out infrastructure enables the creation of a liquid, pan-European, hydrogenmarket. Simply put, the hydrogen infrastructure network is of critical importancefor achieving energy transition goals.
Here, we the research team have provided important cost updates to help inform
policymakers on the competitive advantages offered by the EHB and maintain the
progress that is already underway. Additionally, we have laid out a conceptual
framework for the potential financial challenges that could become most prominent
for network development. Future EHB efforts will quantify the potential amountof required EU-wide support, present recommended solutions to mitigate thedefined financial challenges, and provide additional suggestions for addressing
other aspects of the hydrogen value chain. Regardless of the specific pathforward, we expect that the road ahead is likely to require collaboration amongst
energy network operators, end-user industries, governments, and regulators.
The EHB—and the energy transition as a whole—requires proactive planning,collective action, and a dedication to the overarching goal.

2

Investment required prior to operation iscomposed of CAPEX and DEVEX.

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1. The role of EHB within theEuropean energy transition

1.1 Hydrogen’s key role for European climate policy
In 2020, the EU envisioned a hydrogen strategy to create a continent-widehydrogen ecosystem in line with the European Green Deal. In July 2021, theEuropean Commission set out a target of 5.6 million tonnes (Mt) of renewablehydrogen in Europe by 2030 in its Fit For 55 legislative package3. Russia’s
invasion of Ukraine in February 2022 strengthened the already clear need for a
rapid energy transition. In the face of these events, the European Commission
published REPowerEU4, setting a target of 20 Mt of renewable hydrogen (10 Mt
domestically produced and 10 Mt imported).
Before the European Commission released the REPowerEU plan, the EHB
initiative conducted a bottom-up assessment of demand by sector and country.
In this analysis, the EHB identified 14.7 MT of demand5, representing tangible
and achievable projections based on national targets, market developments, andannounced projects (prior to the release of REPowerEU).

3

4

5

European Commission (2022).
Commission launches consultations on
the regulatory framework for renewablehydrogen. Source: https://commission.
europa.eu/news/commission-launchesconsultations-regulatory-frameworkrenewable-hydrogen-2022-05-23_en
European Commission (2022).
REPowerEU: Joint European Action for
more affordable, secure, and sustainableenergy. Source: https://ec.europa.eu/
commission/presscorner/detail/en/
ip_22_1511.
EHB (2022). Five hydrogen supply
corridors for Europe in 2030. Source:
https://ehb.eu/files/downloads/
EHBSupply-corridor-presentation-Fullversion.pdf

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The sizeable hydrogen demand in 2030 laid out in both the REPowerEU plan andthe EHB’s bottom-up analysis underscores the key role hydrogen is envisioned
to play in the future European energy system, both as an energy carrier andas an energy feedstock in industrial and other processes. Hydrogen is likely
to be a crucial component of the energy transition across end-use sectors, as
an important tool for hard-to decarbonise sectors such as heavy industry (e.g.,iron and steel manufacturing), freight and transportation sectors that historicallydepended upon fossil fuels, and as a means of storing renewable energy for use
on a dispatchable basis.

1.2 The EHB initiative: a collaborative effort to build
out the clean hydrogen infrastructure network
The EHB initiative is a group of TSOs spanning the European continent andcollaborating to lead hydrogen infrastructure development. The original group of
11 EHB partners published their first paper in July 2020, outlining a vision for
dedicated hydrogen pipeline infrastructure—to a large extent based on
repurposed existing natural gas pipelines—including maps showing hydrogen
infrastructure covering their home regions. Since then, the EHB initiative hasgrown to 33 European network operators with infrastructure covering 24 EU
member states plus Norway, the United Kingdom, Switzerland, and Ukraine(Figure 2).

Figure 2
The 33 members of the
EHB, as of 2023.

Since the EHB’s initial report in 2020, subsequent publications served to enhancethe vision as more partners entered the initiative, adding detail to recommended
actions and building additional momentum for the deployment of large-scalehydrogen infrastructure. In view of national and European climate ambitions, firstmover market actors have called for accelerated hydrogen infrastructure planningand development to support lower-cost implementation of their energy transition
strategies. In addition to contributing to REPowerEU climate targets, the ability tostrengthen European resilience and energy security in response to global energy
market disruptions, while preserving the overall EU competitiveness, underscores
the urgency of large-scale hydrogen infrastructure planning.

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From the EHB’s formation in 2020 through today, EHB partners have collaborated
to develop a common hydrogen infrastructure strategy. By combining andvalidating the viewpoints and ambitions of a growing number of members, thisstrategy continues to evolve. Since the beginning, we have periodically updated
our expectations of infrastructure size and cost to reflect the dynamic external
environment of recent years.
Since our previous publication describing hydrogen corridors in June 2022,
many ambitions have turned into reality as all members have been engaged inreal project development, allowing first-hand access to key financial indicatorsthat allow us to report more accurately on the investment needs of the EHB.

1.3 The clear benefits of an integrated pan-European
hydrogen network
While both electricity transmission and hydrogen transmission will be required
in a mature energy system, a previous EHB report6 demonstrated that a pipelinetransmission system offers a more cost-effective energy transfer solution to servehydrogen demand as compared with high voltage direct current or high voltage
alternating current options, with a particularly strong competitive advantage athigh volumes. Therefore, the rollout of hydrogen infrastructure is key to scale
up Europe’s renewable energy supply efficiently and fully—including domestic
renewable hydrogen production—and enable a significant increase in the amountof low-carbon energy transferred between countries and imports from outside
EU.

6

7

8

Note that this comparison is madeagainst transmitting renewable energy
as electric current to the place of local
hydrogen demand and then converting
into hydrogen (locally). EHB (2021).
Analysing future demand, supply, andtransport of hydrogen.p.81. Source:
https://ehb.eu/files/downloads/EHBAnalysing-the-future-demand-supply-andtransport-of-hydrogen-June-2021-v3.pdf
EHB (2022). Five hydrogen supply
corridors for Europe in 2030. Source:
https://ehb.eu/files/downloads/EHBSupply-corridor-presentation-Full-version.
pdf
Projects of Common Interest (PCIs)
are intended to help the EU achieve its
energy policy and climate objectives:
affordable, secure, and sustainableenergy for all citizens and long-term
decarbonization. Source: https://energy.
ec.europa.eu/topics/infrastructure/projects-common-interest/key-crossborder-infrastructure-projects_en

9 / EUROPEAN HYDROGEN BACKBONEThe EHB has long advocated for European hydrogen corridors and their rolein contributing to an affordable and secure energy supply in Europe. The
corridor concept provides an economical means to bridge the substantial
variation of hydrogen producers and end users throughout regions of Europe,
owing to demographic, geographical, economic, and climatic factors.7 Some
European regions—the Nordics, Baltics, North Sea, and southern Europe—
are characterised by a net oversupply of low-cost hydrogen resources. These
regions benefit from vast renewable energy potential, high-capacity factors, andsubstantial land availability. Other regions—such as central Europe—will requirehydrogen imports from neighbouring European or other countries to meet theirhydrogen demand.
Offering an economical connection between regions of hydrogen supply andthe hydrogen consumers in central Europe via cross-border pipeline corridors
will become increasingly important as adoption of hydrogen increases in thetransport, industry, and power sectors. Such a scenario could lead to demand
outpacing supply in regions with lower renewable energy potential. Importantly,
this mirrors the EU sentiment, aligning with goals of the Projects of Common
Interest (PCIs).8

Figure 3
A comparison of the clusteredvs. interconnected hydrogen
network approach in the S1
scenario.11

9

Gas For Climate (2023). Assessing thebenefits of a pan-European hydrogentransmission network. Source: https://
gasforclimate2050.eu/wp-content/
uploads/2023/03/2023_Assessing_the_benefits_of_a_pan-European_hydrogen_transmission_network.pdf
10 Based on supply and demand data fromthe 2022 Ten Year Network Development
Plan (TYNDP), factoring an adjustment
for the phase-out of Russian supply andconsideration of REPowerEU targets,the study shows that total cost savings
could reach €330 billion. These costsavings are mainly attributed to theability to source hydrogen from the mosteconomical regions, while additionalsavings can be attributed to lower
investment requirements for electricity
generation, storage, and transmission
capacities.
11 The S1 scenario is the TYNDP Global
Ambition scenario.

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A recent study by the Gas for Climate consortium—using a methodology basedon optimising a single European energy system—estimated the cost savings
resulting from a pan-European hydrogen network over the 2030 to 20509
timeframe to be as high as €330 billion as compared with a more isolated cluster
approach (see Figure 3).10 Here, it becomes clear that an integrated pan-European
hydrogen network contributes to an affordable energy supply, supporting themost competitive integration of large-scale variable renewable energies andstrengthening Europe’s security of supply.9

2. Current EHB progress to date
EHB members are central actors enabling hydrogen’s role in decarbonising theEuropean energy system. Amidst large-scale economic, geopolitical, and regulatorychanges, these TSOs are moving forward with project development and working toturn the EHB vision12 into a tangible reality.

2.1 Typical hydrogen infrastructure project timelines
Figure 4 shows a representative implementation timeline for the types oftransmission projects comprising the EHB. This timeline shows that urgency andspeed is essential for realising Europe’s decarbonisation goals for 2030. Projectspecific timelines likely vary depending on the jurisdiction, size, and complexityof a project, as well as established corporate and national procedures. On
average, implementing a hydrogen transmission project implementation takes 7
years from initiation to commissioning.
Figure 4
A representative timeline
for transmission project
implementation.

12 Note, on a national level, continual
discussions are being held on thedevelopment of national grids. These
discussions could lead to a deviationfrom the current EHB vision.

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The most important milestone of any project is the Final Investment Decision(FID). The building blocks of the timeline prior to FID are intended to address thetechnical and financial complexities of a project. In addition to technical studies
and permitting, market and financial analyses are important. The main objective isto ensure that the project will generate a sufficient return to cover the investment.
The costs incurred before FID are referred to as DEVEX and are assumed to bea couple percentage of the total CAPEX of a project. The EHB’s members are
currently working proactively with policymakers and industry to ensure FIDs canbe taken at a speed in line with Europe’s decarbonisation ambitions.

2.2 Overall network development and project timelines
Projects initiated by the EHB members have been planned in close cooperation
with industry stakeholders and regulators and are anticipated to receive strong
support at the national and international level. Most of these projects are alreadyin the early phase of development and are expected to be operational between
2029 and 2031 (see Figure 5).
The projects currently in the front-end engineering design (FEED) phase are
expected to be operational within a couple of years. If FID is taken, these projects
will establish the first 4.000 km of the European hydrogen transmission network.
In total, 40 projects are expected to be commissioned in by the start of the next
decade.
Figure 5
Anticipated kilometers ofcommissioned hydrogenpipelines, per year.

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Figure 6
A selection of EHB-affiliatedhydrogen transmission projects(see Appendix A for details).

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2.3 Corridor-specific development
The next sections provide in-depth information about projects planned forcommissioning by EHB partners in the coming years.13 The projects are arranged
and color-coded by corridor. The transmission network in Germany is included
separately because that would otherwise have been discussed in multiple
corridors. For more detail about the projects included in the sections below see
the Appendix A: Selected Projects to Create EHB by Early 2030s.
3.3.1 Corridor A — North Africa and Southern Europe
Figure 7
Corridor A development(selected projects).

Corridor A is intended to deliver low-carbon hydrogen from North Africa
and Southern Italy towards Central Europe. Overarching initiatives such as theSunsHyne Corridor and the SoutH2 Corridor combine multiple national projects
into bigger alliances that enhance political support and enable them to benefit
from a streamlined permitting process as well as pursue a value-for-money
framework through mechanisms such as the Projects of Common European
Interest (PCI). The very broad support and exchange of stakeholders along theentire value chain—from production to consumers—is a success factor for thedevelopment of the favourable production areas in North Africa. Focusing on thedevelopment within specific countries, green hydrogen from North Africa will firstbe injected to the Italian Hydrogen Backbone, consisting of approximately 2.300
km of pipeline (of which 75% is repurposed). After serving domestic demand in
Italy, hydrogen will be moved into additional central European countries. Within
Austria—in addition to serving domestic demand—hydrogen will be transported

13 These maps do not provide a complete
overview of projects in each region.
There are additional projects indevelopment that are not shown.

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via one repurposed TAG pipeline, WAG, and Penta West pipeline towards
Germany and connected to storage facilities along the route. HyPipe Bavariain Germany finally forms the link between Austria and the German Hydrogen
Backbone. The route from Austria via Slovakia and Czech Republic to Germany
is fully made up by repurposed pipelines and will serve demand centres along
the corridor. Additionally, a connection to the Slovenian Hydrogen Backbone will
not only supply national demand but also enable further connection to Croatia.
Furthermore, the SunsHyne corridor will be used to serve hydrogen demand in
Slovakia and Czechia. When needed, the connection to Hungary can also serve
demand in southern Europe.
3.3.2 Corridor B — Southwest Europe and North Africa
Figure 8
Corridor B development(selected projects).

The Southwest Europe & North Africa Corridor aims to transport hydrogen to
demand centres in Germany and beyond, through the H2ercules project. Within
Corridor B, H2Med is the overarching project connecting hydrogen networks
in Portugal, Spain, France, and Germany. It consists of the CelZa project inPortugal that connects hydrogen producers such as the Green H2 Valley to
the Spanish Hydrogen Backbone. The Spanish Hydrogen Backbone collects
multiple supply sources from around Spain and allows connection to North
African project developments, making it one of the most promising hydrogenproduction locations in Europe. To transport planned supply volumes to the main
demand centres of Europe, the connection into France is essential. The BarMar
project circumvents geographic challenges of the Pyrenees by traversing theMediterranean Sea as an offshore pipeline from Barcelona to Marseille. From
Marseille onwards, the hydrogen network branches into two directions, throughFrance with HySoW towards the Atlantic coast and as connection to Western
European countries via HyFen.

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3.3.3 Corridor C — North Sea
Figure 9
Corridor C development(selected projects).

The North Sea Corridor aims to expedite the delivery of hydrogen to demand
centres in the western part of Germany. A primary energy feedstock for hydrogenin this corridor is provided by the vast offshore wind potential in the region. With
this aim, H2T envisions to develop a pipeline from Norway in close collaboration
with the German and Norwegian government. Nearby, the Danish-German
Hydrogen Network intends to transport hydrogen via a 561 km onshore pipeline
through Denmark into the north of Germany. Additional offshore wind energy
from the North Sea is brought to the German coastline with hydrogen initiatives
such as HyOne and AquaDuctus in which hydrogen will be produced offshore
and will be transported via pipelines to the mainland. Entities in Corridor C also
envision supplying hydrogen in this corridor by importing hydrogen derivatives
via ports such as Rotterdam and Antwerp. Additionally, to transport hydrogenacross the mainland and into Europe, projects such as the Belgium Hydrogen
Backbone and the Hydrogen Network Netherlands are progressing rapidly—the
Belgium Hydrogen Backbone is in the FEED phase, while the Hydrogen Network
Netherlands has already taken FID. The construction of the Hydrogen Network
Netherlands has started on 27th of October.

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3.3.4 Corridor D — Nordic and Baltic Regions

Figure 10
Corridor D development(selected projects).

The Nordic and Baltic regions have significant renewable energy resources basedon low-cost renewable energy. The availability of land and water for hydrogenproduction makes the region lucrative for hydrogen projects and new P2X (Powerto-X, the process of turning hydrogen into something else) industries. Therefore,
three major projects are planned to connect with demand regions. The Nordic
Hydrogen Route-Bothnian Bay connects the northern parts of Finland and Sweden
with their abundant renewable energy resources (onshore and offshore wind) to
demand centers in these regions. It is also connected to the onshore Nordic-Baltic
Hydrogen Corridor project, which connects the future Baltic hydrogen market
with Germany. The offshore Baltic Sea Hydrogen Collector offshore project,which connects Finland, Sweden, and Germany, as well as the energy islandsin the region, will link the vast offshore wind resources to be used for hydrogenproduction with demand in Western and Central Europe. The offshore projectmight also be connected to the Bornholm-Lubmin interconnector in Denmark.

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3.3.5 Corridor E — East and Southeastern Europe
Figure 11
Corridor E development(selected projects).

Corridor E—the East and Southeastern corridor—enables the transport ofhydrogen from Greece or from Ukraine through Bulgaria, Romania, Hungary,
Slovakia, and Austria to Central Europe. Projects already under development
include the RO/HU H2 corridor, the HU/SK H2 corridor, and the Central European
Hydrogen Corridor (CEHC) or the H2EU +Store initiative. Each of these projects iscurrently in the pre-feasibility phase and are all aiming to be operational in 2030.
A significant part of these projects also directly interfaces with other neighboring
initiatives, such as the SunShyne Corridor and the SoutH2 Corridor, where they
enable transport of hydrogen from East and Southeastern Europe as well as from
Northern Africa through Corridor A. To enable flows in all these directions, there
is a need for technical flexibility of the transmission system, especially in Slovakia
and Austria.

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3.3.6 Transmission Network in Germany
Figure 12
Development of the network inGermany (selected projects).

Germany is part of all EHB corridors and is therefore discussed separately
here. Germany is expected to import large amounts of hydrogen to meet thelargest national hydrogen demand. Development of the network in Germany(selected projects). shows the key projects of some German TSOs as part of theplanned Hydrogen Core Network,14 which will enable the connection of domestichydrogen production and neighboring countries for hydrogen imports to thedemand centers. The German TSOs are closely cooperating on several projects
in Germany, the Netherlands, Belgium, France, Norway, Austria, Denmark, andthe Czech Republic.

14 FNB Gas (2023). Hydrogen core
network. Source: https://fnb-gas.de/en/hydrogen-core-network/
15 The association of the supra-regional gas
transmission companies.
16 Hydrogen Insights (2023). How should
Germany fund its 11,200km nationalhydrogen network? This is Berlin‘slatest thinking. Source: https://www.
hydrogeninsight.com/policy/how-shouldgermany-fund-its-11-200km-nationalhydrogen-network-this-is-berlins-latestthinking/2-1-1497289
17 https://fnb-gas.de/en/

19 / EUROPEAN HYDROGEN BACKBONEThe German TSOs work closely with FNB Gas e.V.15 and the Federal Ministryof Economics and Climate Action (BMWK) to coordinate the development of
the Hydrogen Core Network. As of July 2023, the total length of the network
is expected to be about 11.200 km. The goal of the planning is to connect the
key supply and demand facilities to enable an open and competitive hydrogenmarket. Joint planning will also enable the development of comprehensive support
mechanisms to minimise and derisk investments.16 Note that the final network is
still under discussion and therefore might be updated after the publication ofthis report. The latest version can be found on the website of FNB Gas e.V.17.
Development of the network in Germany (selected projects). shows only selected
projects and therefore does not fully correspond to the network developed under
the FNB Gas e.V. initiative.

3. Update of pipeline
infrastructure costs

In 2020, the EHB published first-of-its-kind cost data for hydrogen pipeline
infrastructure, outlining the costs associated with pipelines of different sizes,
onshore versus offshore, and new versus repurposed. This data has been
circulated around the world, being utilised by commercial actors, research
institutions, planners, policymakers, and others. Given recent developments to
the global economic picture—whether COVID, geopolitical, or climate-related—the EHB has undertaken an effort to provide updated cost information to keep
project development, planning, and policy efforts as current and accurate as
possible. In this section, we provide a discussion of CAPEX relating to pipeline
and compressor costs.

3.1 Cost inputs and results

Figure 13
Components included in thecalculation of CAPEX and DEVEX.

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The 2023 cost update included a survey of TSOs to estimate the costs associatedwith each of the components necessary to build out pipeline infrastructure.
Broadly speaking, these components include material costs, labour costs,
costs to acquire rights-of-way, and miscellaneous additional costs. DEVEX were
calculated as a percentage of the total CAPEX costs. A simple schematic of the
CAPEX calculation methodology can be seen in Components included in thecalculation of CAPEX and DEVEX..

EHB member TSOs—the stakeholders most familiar with real-world hydrogen
infrastructure implementation—provided primary data to inform this cost update.
The collected data originates from a variety of sources, including vendor quotes,
pre-feasibility studies, real project data, and internal budgeting departments.
Additionally, we used an external model,18 historical project database,19 andcommercial studies20,21 to corroborate and validate TSO data. To account forvarying data quality and specificity, we categorised collected data by level ofrigor—assigning different weights to the various source types and creating
weighted average cost values for pipelines of different sizes. In this process,
TSO primary data was given a stronger weighting than external models andstudies. Within collected TSO data, real project cost data was valued with ahigher weighting than costs from pre-feasibility studies and the assumptions frominternal budgeting departments.
Figure 14 provides comparison of the new and previous EHB cost assumptions
for new-build onshore pipelines and compressors. The graph above the tabledisplays how the costs of a pipeline can be influenced by external factors (e.g.
population density and elevation). The EHB 2023 values in the table are reflectedof Europe-wide estimates. Although the data distribution has been anonymisedfor confidentiality purposes, the visualisation does reflect the true nature of thecollected data. The yellow line represents the current assumption of EHB network
costs.
Figure 14
Visualisation of data received
from EHB members for new
pipeline and new compressors
costs.

18 Khan, M.A., Young, C. and Layzell,
D.B. (2021). The Techno-Economics
of Hydrogen Pipelines. Transition
Accelerator Technical Briefs Vol. 1, Issue
2, Pg. 1-40. ISSN 2564-1379.
19 Energy Information Administration(2023). U.S. natural gas pipeline
projects. Source: https://view.
officeapps.live.com/op/view.
aspx?src=https%3A%2F%2Fwww.
eia.gov%2Fnaturalgas%2Fpipelines%2FEIA-NaturalGasPipelineProjects.
xlsx&wdOrigin=BROWSELINK
20 DNV (2023). Specification of aEuropean Offshore Hydrogen Backbone.
Source: https://www.gascade.de/fileadmin/downloads/DNVStudy_
Specification_of_a_European_Offshore_
Hydrogen_Backbone.
21 Strategy& (2021). HyWay 27: hydrogentransmission using the existing naturalgas grid?

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Not visualized in Visualisation of data received from EHB members for new
pipeline and new compressors costs. (but compiled using the same method),
TSO data shows that repurposed 20” pipelines represent 30% of the cost of new
pipeline deployment. For all other sizes, repurposing costs are approximately
20% of the cost of new pipeline construction. (Note that this 20% repurposing
cost assumption is in line with previous EHB values). For offshore pipelines, we
retain the previous EHB assumption, indicating that these kinds of pipelines cost
approximately 1.7x more than similarly sized onshore pipes. Detailed cost resultsby size and type of pipeline can be seen in EHB CAPEX Assumptions.
Table 1EHB CAPEX Assumptions

Parameter
20” onshore pipes
36” onshore pipes
New48” onshore pipes
pipelines
36” offshore pipes
48” offshore pipe20” onshore pipes
36” onshore pipes
Repurposed48” onshore pipes
pipelines
36” offshore pipes
48” offshore pipe
Compressor station

CAPEX costs(M€/km for pipelines andM€/MWe for compressors)
1.80
3.20
4.40
5.44
7.48
0.54
0.64
0.88
1.09
1.50
4.0

It is important to note that although this report presents the latest cost estimatesfor hydrogen infrastructure within Europe, the numbers are based on three broad
financial assumptions:
1. EHB cost data reflects a Europe-wide estimate. Europe-wide estimates
are reasonable to use in EHB calculations due to the diversity of pipelines
in the pan-European grid. However, these assumptions might not apply toindividual projects, given the diverse terrain or required infrastructure indifferently populated regions. Regions with greater population density or
mountainous geography might encounter costs toward the higher end ofthese ranges, while more sparsely populated or with flatter or less complex
terrain will likely be able to take advantage of lower values.
2. Limited empirical data exists regarding large-scale hydrogentransmission pipelines in Europe. While gas transmission pipeline data
can be extrapolated, uncertainties regarding operating pressure, pipelinematerials, etc., contribute to uncertainty for hydrogen-specific costs. As
described previously, TSO data is consolidated across all responses andcompared with existing studies to reduce any potential bias. However, thedata still relies on estimates underlied by a limited amount of empirical data.
3. Material and labour costs account for 70%-80% of transmission pipeline
and compressor expenses. Consequently, future cost developments arestrongly tied to the development of steel prices, energy prices, inflation, andworkforce dynamics. Overall, it is the EHB’s aim to estimate and monitor thetrue cost of a pan-European hydrogen network, enabling this research toprovide value for real pipeline network planners and implementers.

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3.2 The impact of inflation
While prices in this update are nominally higher than the costs cited in 2020,
Figure 15 shows that the bulk of the cost increase—as compared with previous
EHB publications—can be attributed to inflation. To corroborate this assertion,
the figure portrays the previous EHB assumptions adjusted for sector-specificinflation,23 leading to CAPEX numbers that are approximately equal to the new
EHB values.
Figure 15
Comparison of 2019 EHB
assumptions (adjusted for
inflation compared) to EHB 2023
assumptions (based on new data
reflective of project experienceof TSOs) show costs increase arelargely due to inflation

23 Inflation numbers are based on producer
prices in industry – specifically for
manufactures of tubes, pipes, hollow
profiles and related fittings, of steel.
Eurostat (2023). Producer prices inindustry. Source: ttps://ec.europa.
eu/eurostat/databrowser/view/STS_
INPP_A__custom_6529451/default/
table?lang=en
24 All producer price indices are based onEurostat data, indicating—since 2019—a
47% increase in prices for manufactureof tube pipes, hollow profiles andrelated fittings of steel; a 48% increase
for copper production; a 52% increase
for aluminium production; and a 125%
increase in electric power generation,transmission and distribution: ec.europa.
eu/eurostat/databrowser/view/STS_
INPP_A__custom_8023762/default/
table?lang=en
25 International Energy Agency (2023).
Energy Technology Perspective 2023.
Page 320. Source: https://iea.blob.
core.windows.net/assets/a86b480e2b03-4e25-bae1-da1395e0b620/
EnergyTechnologyPerspectives2023.pdf.
26 Gas For Climate (2023).
Assessing the benefits of a panEuropean hydrogen transmission
network. Page 6. Source: https://
gasforclimate2050.eu/wp-content/
uploads/2023/03/2023_Assessing_the_benefits_of_a_pan-European_hydrogen_transmission_network.pdf.
27 EHB (2021). Analysing future demand,
supply, and transport of hydrogen.
Page 81. Source: https://ehb.eu/
files/downloads/EHB-Analysing-thefuture-demand-supply-and-transport-ofhydrogen-June-2021-v3.pdf

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A comparison of Eurostat data24 on producer price indices by sector shows thatthe gas pipeline and electricity transmission sectors (and their associated raw
materials) have seen an equivalent rise in prices on account of recent inflation.
Considering this cost increase, the primary aim of policy makers should beto enable sufficient investment in infrastructure across all energy carries.
Both electricity and hydrogen infrastructure have an important role to play indecarbonising the European energy system. However, with regard to hydrogen,several studies conclude that it is more cost-efficient to install electrolysers close
to renewable power generation and then use pipelines to transport hydrogento the point of consumption than it is to install electrolysers close to hydrogen
demand and consequently power electrolysers through the electricity grid.25,26,27
Given our observation that the inflation has impacted both hydrogen pipelines
and electricity transmission infrastructure, we believe this conclusion still holdstrue.

4. Conceptual framing of
the financial challenge

Upfront CAPEX and DEVEX costs are just a part of the broader financial pictureof hydrogen network development. Conceptually, the EHB network is likely to
encounter two distinct financial phases during its operation that are strongly linked
to the development of the European hydrogen economy (Figure 16). The first ofthese phases represents the market ramp-up, involving limited hydrogen demandand low hydrogen capacity booking on the network. The capacity booking of the
network could consist of both long-term and short-term bookings. However, as
the hydrogen economy develops and demand rises, the market will transition to
the later mature market phase.
The EHB network is projected to be financially viable in the long term, given
the updated unit costs explained in section 4.1 of this report and bottomup demand development as laid out by the EHB in previous publications.28
Given the signals of wider institutional support towards hydrogen in Europe,
the financial challenges during operation discussed in the upcoming section
relate primarily to the first, developmental phase of network operation. The maincause of this potential financial challenge is that demand might take time todevelop, as market design enablers will take some time to be fully developedand implemented.
During the ramp-up phase, the EHB might therefore encounter an investment
recovery challenge (IRC), meaning that the network might not generate the fullrevenue allowed by regulators under a largely similar application of existing—natural gas infrastructure-based—regulations. Operational revenue streams arenecessary to refinance the costs associated with building and operating the
network; therefore, the challenge is caused by low earned tariff revenue resulting
from a low level of capacity bookings or uncertain network user willingnessto-pay in the initial phase. Additionally, the duration of market ramp-up might
exceed the timeframe for network operators to recoup missed revenue under
existing cost recovery rules.

28 EHB (2022). Five hydrogen supply
corridors for Europe in 2030. Source:
https://ehb.eu/files/downloads/EHBSupply-corridor-presentation-Full-version.
pdf

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Figure 16
Structure of the EHB’s main
financial challenges

Fundamentally, the IRC can be perceived as a source of investment risk for TSOs
and other EHB investors during network buildout. This perceived risk leads to a
upfront financing gap (UFG), which emerges if network operators are not able tomobilise sufficient market capital to develop the EHB. This section explains thefundamentals of the IRC and UFG, the impact these challenges might have on
EHB buildout, and potential measures to mitigate their risks.

4.1 Investment recovery challenge —conceptual framework
As introduced earlier, the first potential financial challenge—occurring during
the market ramp-up phase—is the IRC. For simplicity, we assume that the EHB
network will be regulated under a typical Regulated Asset Base (RAB) model,
mirroring to a large extent the current gas infrastructure regulatory framework.
The RAB represents the total value of owned infrastructure and is used (alongsideconsiderations of operating expenses and allowed maximum return on capital) byregulators to set a revenue cap each year, defining the TSOs’ regulated returns
based on depreciated asset value over time.
Additionally, we can estimate the revenue generated by a pipeline as the amountof booked capacity times a tariff equal to the assumed network user willingnessto-pay for hydrogen conveyance. The IRC arises from the financial disparity
between the regulated revenue cap and the real revenue that can be earned
from network users on account of actual network usage.

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A simple way to interpret the IRC is presented conceptually in Figure 17. Notethat this graph is not a reflection of the real dynamics of the entire EHB network
but rather a simplification of a single pipeline, used to illustrate the structure of
the IRC framing.

Figure 17
Level of tariff required to realise
regulated return across different
financial phases (utilising a single
simplified pipeline model).

Represented by the yellow area on the left side of the graphic, the challengearises during the early years of operation. Even considering the optimistic longterm financial picture, it is important to mitigate the potential effects of high earlytariffs hindering hydrogen market development. Building a smaller pipeline tomatch the initial low hydrogen capacity booking level—while initially requiring
less investment—is neither an efficient nor a competitive solution: it would fail toaccommodate the expected future hydrogen flows, leading either to additionalcosts required to build new lines outside of the initial large-scale buildout or
insufficient transport capacity and a bottleneck for Europe’s decarbonisation
efforts.

Conceptual IRC Example: In this simple illustrative example, assume that the regulator has set the RAB revenue cap
at 100€, that the expected booked capacity is 4 MWh/y in the first year, and that the pipe can transport 20 MWh/y at
maximum capacity.
The TSO is allowed to set the tariff at 25€/MWh = 100€ (RAB) / 4 MWh/y (booked capacity). This tariff is visualised by
the yellow line at the start of market ramp-up phase. If network users are willing to pay a tariff of 25€/MWh, no IRC exists.
However, due to low initial capacity booking level (and subsequently low denominator in the IRC equation), the TSOs
need to ask for the calculated 25€/MWh tariff to earn back their network costs. However, such a tariff (in this example) islikely to be unacceptably high for first movers. Consequently, if network users are only willing to pay 10€/MWh (visualisedby the blue line in Figure 17), there is a 15€/MWh = 25€/MWh – 10€/MWh difference between the tariffs required torealise the regulated return and the willingness-to-pay of (initial) network users. This scenario results in an IRC of 60€ =15€/MWh x 4 MWh.
By contrast, in a mature market where hydrogen capacity booking level matches the maximum capacity of the pipes, therequired tariff would be: 5€/MWh = 100€ (RAB) / 20 MWh/y (capacity booking level). This 5€/MWh is likely lower
than the maximum early market end-user willingness-to-pay. After the market has matured, this would mean that tariffs are
acceptable to network users while also allowing TSOs to recover their investments.

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4.2 Upfront financing gap — conceptual framework
One consequence of an IRC—should one arise—is investor concern about thebankability of the EHB, which manifests as investment risk, preventing them fromproviding the necessary capital available to TSOs. While some TSOs will be able
to fully fund the buildout of their portions of the EHB network, many TSOs must
attract additional external capital to do so. In this report, we refer to the capacity
to do so as the financing ability per TSO.
Therefore, in many cases, the UFG arises as a consequence of the projected IRC
and represents the difference between the total required upfront investment prior
to project operation29 and the ability of a TSO to finance the project (Figure 18).
There are cases where TSOs have sufficient capital available but are not able toinvest this capital, as the IRC poses too big of a risk.
Figure 18
Definition of the UFG.

The UFG poses a particular problem for the upfront capital that is reservedfor DEVEX. If TSOs do not have sufficient capital to conduct developmental
activities, the timeline to build a project is directly delayed (this is the first stepin realising a project, as section 3.1 shows). Therefore, the UFG—which impacts
the DEVEX—should be a primary concern of European policymakers aiming toachieve ambitious decarbonisation goals.
Policymakers could mitigate the challenges associated with the UFG by facilitating
funding or guarantees in an amount appropriate to counter the IRC. In this way,
network development could be sufficiently derisked and able to attract marketrate investment to finance its buildout.

29 Investment required prior to operation iscomposed of CAPEX and DEVEX.

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5. What toexpect fromthe EHB in
2024

We view investment in the EHB as a necessary step forward for achieving
lowest-cost societal decarbonisation in Europe. For a new venture—especiallyat this scale—the path forward is likely to at times be complicated, uncertain,
and involve numerous different stakeholders. Despite these challenges, theEHB effort remains a vital and strategic investment in the future of the European
energy system. Hydrogen makes use of plentiful European and neighbouringresources, serves a multitude of sectors—including those typically viewed as hardto decarbonise—and provides connectivity and resilience across the continent.
Simply put, the hydrogen infrastructure network is of critical importance forachieving energy transition goals while preserving the competitiveness of the EU.
In this paper, we have conceptually framed certain financial challenges that could
potentially arise in the emerging hydrogen market. Future EHB efforts will explore
the size of the financial commitment required for the EHB network development
and compare it with the existing funding mechanisms already available forhydrogen infrastructure development. In conjunction, we aim to examine thecurrent and future role of the EU and member states in funding the EHB.
Beyond the financial challenges, there are a variety of considerations related to thehydrogen value chain and project delivery process that could help to enable thetimely and efficient implementation of the EHB. Each of these ecosystem factors
contributes to the success of the emerging hydrogen market, and in turn provides
some measure of risk mitigation for financiers by streamlining the process andencouraging hydrogen market development. Future EHB efforts will also recap
the current understanding of these supplemental and ecosystem considerations,with recommendations for an efficient path forward to implementation.

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6.1 Appendix A: selected projects to create EHB byearly 2030s

6. Appendix

Overview of selected projects planned for commissioning by early 2030s.
6.1.1 Corridor A — North Africa and Southern Europe
Italian Hydrogen Backbone (part of SoutH2 and SunsHyne Corridors)
Project partners: SnamDevelopment phase: Pre-feasibility phase / feasibility phase
The project includes the development of a hydrogen backbone from Sicily to theexport points with Austria and Switzerland, enabling the transport of hydrogenproduced in Northern Africa and Southern Italy to the main national and European
consumption areas. The project supports creation of an interconnected EU
hydrogen market, ensuring diversification and security of supply and positioning
Italy as a hydrogen hub.
The Italian Hydrogen Backbone will be approximately 2,300 km long witharound 75% share of repurposed pipelines and up to 500 MW of compressor
stations. The project would be a major European renewable hydrogen importartery, serving Italian demand clusters and enabling exports towards Central
and Western European countries via Austria and Switzerland. Snam is currently
analysing the possibility of converting depleted gas storage fields into hydrogenstorage sites that could complement the backbone to mitigate the volatility of theincreasing RES production and provide flexibility to the power system.
SoutH2 Corridor
Project partners: Snam, TAG, Gas Connect Austria and bayernets
Development phase: Pre-feasibility phase / feasibility phase
Website: https://www.south2corridor.net/
The SoutH2 Corridor project is a 3300 km hydrogen pipeline connecting North
Africa, Italy, Austria, and Germany. Led by TSOs that each submitted Project ofCommon Interest submissions to the European Commission, it aims to supply
competitive renewable hydrogen to European demand clusters. It utilises >70%
repurposed infrastructure, with new pipeline segments where necessary. The
corridor has trilateral political endorsement, as well as strong support fromcompanies involved in production (ca. 2.5 Mt/y) and offtake of hydrogen
along the whole corridor. The SoutH2 Corridor plays a vital role in enabling thetransportation of both imported and domestically produced hydrogen.

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SunsHyne Corridor
Project partners: Snam, TAG, Eustream, NET4GAS, OGE
Development phase: Pre-feasibility phase
Website: https://www.sunshynecorridor.eu/
The SunsHyne Corridor is a strategic infrastructure initiative promoted by agroup of five leading TSOs – Snam, TAG, Eustream, NET4GAS, OGE – whose
ambition is to enable hydrogen flows from North Africa to Germany supplying
and crossing Italy, Austria, Slovakia, and the Czech Republic. The corridor has
a total length of 3.400 km, a share of 85 % repurposed pipelines, and aims tooffer a capacity of minimum 126 GWh/d in 2030. Each TSO has applied for the
status of Project of Common Interest. Due to its strategic location, the SunsHynde
Corridor will not only enable the development of a common hydrogen market in
Italy, Slovakia, the Czech Republic, and Germany but also in wider Central andEastern Europe, supporting competition and security of supply.
H2 Readiness of the TAG Pipeline System (part of SoutH2 andSunsHyne corridors)
Project partners: TAG
Development phase: Feasibility phase
The project connects the hydrogen pipeline at the Italian-Austrian border(Arnoldstein) with those at the Austrian-Slovakian border (Baumgarten). It
consists of repurposing one of the three existing natural gas pipelines of the
TAG system to 100% hydrogen, with all associated facilities between Arnoldsteinand Baumgarten. There, it will be connected to the H2-WAG pipeline within
Austria to supply central Austria and southern Germany and will be connected to
EUSTREAM’s hydrogen pipeline.
The bidirectional design of TAG’s 380 km hydrogen pipeline meets the local
needs of customers in Austria and enables Italy, Germany, Slovakia, Czech
Republic, and all of central and eastern Europe to develop a common hydrogenmarket, promoting competition and security of supply. The system is optimised
to transport hydrogen from the Snam system at 168 GWh/day capacity from lowcost production areas in North Africa.
H2 Backbone WAG + Penta West (part of SoutH2 corridor)
Project partners: Gas Connect Austria
Development phase: Feasibility / Pre-FEED phase
Website: https://h2backbone-wag-pw.at/en/home-english/
With the realisation of the project bidirectional cross-border hydrogen transportpossibilities between Slovakia and Austria as well as between Austria andGermany to the extent of 150 GWh/day (55 TWh/a) are established. The project
connects part for South-North as part of the SoutH2 Corridor initiative and EastWest as part of the H2EU+Store initiative. The project would enable hydrogenfrom the south via the TAG-hydrogen pipeline systems in the Baumgarten node.
This setup allows for obtaining hydrogen from different sources in the future suchas North Africa, Ukraine, Germany, Romania, and Croatia. The development of
this project is a precondition to address the hydrogen import need of Austria anddeliver the hydrogen to the large demand centers along the route, in particular
the wider area around Vienna and Linz. Additionally, the project allows for theconnection to storage facilities in Austria, which helps to create security of supply
with hydrogen.
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Central European Hydrogen Corridor, Czech part
Project promoter: NET4GAS
Development phase: Pre-feasibility phase
Website: https://www.sunshynecorridor.eu/, www.cehc.eu
The Central European Hydrogen Corridor, Czech part (gas pipeline DN 1.400,
403 km), between the Czech/Slovak border and Czech/German border enablestransport of pure hydrogen of 144 GWh/d starting by the end of 2029 andaims to create a part of a hydrogen “highway” in Central Europe for transportinghydrogen from two major hydrogen supply areas outside the EU (mainly Ukraine
and North Africa) as well as the supply areas along the corridor to expected highdemand clusters along the corridor, especially in Germany.
The supply corridor from North Africa will go to Germany through Italy, Austria,
Slovakia, and Czechia and is developed as SunsHyne. The project is promotedby the following gas TSOs: Snam (IT), TAG (AT), EUSTREAM (SK), NET4GAS(CZ), and Open Grid Europe (DE).
The supply corridor from Ukraine will go to Germany through Slovakia andCzechia and is developed as project CEHC. The east-west corridor is promoted
by four gas TSOs: Gas TSO of Ukraine, EUSTREAM (SK), NET4GAS (CZ), andOpen Grid Europe (DE).
H2 Backbone Murfeld
Project partners: Gas Connect Austria
Development phase: Pre-feasibility phase
Website: https://h2backbone-murfeld.at/en/home-english/
With the realisation of the project bidirectional cross-border hydrogen transportpossibilities between Slovenia and Austria to the extent of 33 GWh/day (12TWh/a) are established. The project enables the transportation of hydrogen fromthe South, e.g., from Croatia via Slovenia or Italy to Austria. Hence, it contributes
to the diversification of the future hydrogen supply supporting consumption areasin Austria, such as Styria, the wider area of Vienna and Linz and surrounding
industrial regions in neighbouring countries.
Slovenian Hydrogen Backbone – Central Region
Project partners: Plinovodi d.o.o.
Development phase: Pre-feasibility phase
Project is the first phase of development of the Slovenian Hydrogen Backbone.
The repurposed part of the project will connect the Slovenian capital Ljubljana with
Austria and will lead to the first hydrogen interconnection point in Slovenia with
Austria. The project will also enable the establishment of a new interconnection
point with Croatia. The repurposed part of the project consists of 165 km ofexisting pipelines. Bidirectional capacity of the new hydrogen interconnection
point with Austria is aligned with GCA and is equal to 33 GWh/day (12 TWh/a).
The first phase of the project is expected to be completed by 2029.
In Germany, Corridor A connects to the H2ercules project via the SunsHyne
Corridor and the SoutH2 Corridor.

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6.1.2 Corridor B — Southwest Europe and North Africa
CelZa (part of H2Med corridor)30
Project partners: REN and Enagás
Development phase: Pre-feasibility
The CelZa (Celorico-Zamora) is part of the H2Med corridor and is about 242 kmlong with a bidirectional capacity of 81 GWh/d (HHV), links and supplements thedevelopment of the BarMar interconnection project, enabling the emergence of a
supply corridor. With the CelZa as an enabler, REN considers a first componentof the Portuguese Hydrogen Backbone with new pipelines between Figueirada Foz and Cantanhede and the repurposed portion between Cantanhede –Celorico da Beira – Monforte, allowing the connection of Green H2 Valley at
Figueira da Foz and other producers along the corridor.
Portuguese Hydrogen Backbone
Project promoters: REN
Development phase: Pre-feasibility
The Portuguese Hydrogen Backbone is linked to the CelZa project and includes
a new Figueira da Foz–Cantanhede hydrogen pipeline, about 50 km long, andthree repurposed pipelines: Cantanhede-Mangualde (68 km of a trunkline and
8 km branch line), Mangualde-Celorico da Beira (48 km of a trunkline), andCelorico da Beira-Monforte (213 km of a trunkline plus 4 km branch line).
This project creates a condition for the production and integration of greenhydrogen, both in Portugal’s central inland region and in the Figueira da Foz
region, which benefits from its proximity to industrial infrastructures and offshore
wind production as part of the objectives pursued by the government.
Spanish Hydrogen Backbone
Project partners: Enagás
Development phase: Feasibility / Pre-FEED phase
By 2030, the proposed hydrogen network will connect the industrial clusters
along the Mediterranean coast and in the north of Spain, where two undergroundstorage projects could also link to the network. The network will also comprise
pipeline axis along the Via de la Plata and Ebro Valley to harness the potential forhydrogen production from the rich renewable resources of these areas. Later,
the development of the network will guarantee cohesion between the different
demand regions and integrate the multiple supply points that will be distributed
across the country.
Spain’s long-term ambition is to be one of the main hydrogen suppliers in Europe,building on its significant solar PV, wind, and hybrid potential to produce greenhydrogen. The national backbone will enable this setup by connecting with France
through a new marine pipeline route from Barcelona to Marseille by 2030 andlater by converting the existing connections via Irún and Larrau to hydrogen. A
new connection between Portugal and Zamora (2030) is also planned.

30 H2Med partners: GRTgaz, Teréga, REN
and Enagás

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HySoW (Hydrogen South-West corridor of France)
Project partners: Teréga
Development phase: Pre-feasibility
The project has a capacity of 0.40 Mt/y and consists of 460 km of new and 180
km of repurposed natural gas pipelines for hydrogen transport:− Connection of the saline cavern storage facility near Lacq to the IberianFranco-German H2Med corridor− Connection to the renewable energy and hydrogen production hub in Portla-Nouvelle− Connections to key demand centres and additional production sites in theports of Bordeaux and Bayonne
HySoW has received explicit support from more than 37 national and international
stakeholders, including public authorities (e.g., French Ministry for the Energy
Transition, Région Occitanie, Région Nouvelle Aquitaine), hydrogen producers(e.g., H2V, DH2 Energy), and off-takers (e.g., Lafarge, Aerospace Valley, orBASF). Teréga is also actively cooperating with GRTgaz, Enagas, and REN on
delivering the H2Med corridor.
BarMar (part of H2Med corridor)
Project partners: GRTgaz, Teréga, Enagás, OGE
Development phase: Pre-feasibility / Feasibility
As part of H2Med corridor, the BarMar project will transport up to 2 Mt/y ofgreen hydrogen between the Iberian Peninsula and France (between Barcelona
and Marseille), which is 10% of the hydrogen consumption anticipated by
REPowerEU. The hydrogen will be mainly produced in the Iberian Peninsula (byRES) and then transported through the H2Med corridor to supply the industrial
and mobility sectors. By 2040, some imports from North Africa are expected,
which will increase the flows through this corridor. The project will allow toscale future European hydrogen markets by providing affordable and low-costhydrogen by 2030. It will also allow for development of national backbones andstorage projects along the corridor. This project is politically supported by theannouncement of high officials of the European Commission, Portugal, Spain,
France, and Germany.
HY-FEN
Project partners: GRTgaz
Development phase: Pre-feasibility phase
The HY-FEN project aims to develop a French hydrogen transmission network via
pipeline, connecting the Iberian Peninsula (via H2Med) to Germany (H2ercules)
and national storage sites by 2030. Security of supply and flexibility will beenhanced through access to UGS projects (such as GeoH2 and HySoW) andfuture salt cavern projects in Etrez and Tersanne/Hauterives in the Rhône Valley.
HY-FEN will further enhance the Hynframed, MosaHYc, HySoW, and RHYn projects
by providing access to competitive hydrogen from various sources, particularly
imports. Overall, stakeholders of the mentioned projects will gain access tohydrogen volumes produced/stored outside their immediate periphery, thereby
broadening the market for large hydrogen volumes. In Germany, Corridor B
connects to the H2ercules project to continue supply from HY-FEN (see Section).

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6.1.3 Corridor C — North Sea
Hydrogen Network Netherlands
Project partners: Gasunie
Development phase: FID taken
The objective of the Dutch hydrogen network project is to create an open accessnon-discriminatory national and cross-border network and for connection withlarge-scale hydrogen storage in northeast Netherlands. This network will becomposed of 70%-80% repurposed natural gas pipelines, with the addition of
new pipes in areas where connections are not yet available. Once complete, thehydrogen network will connect onshore and offshore hydrogen sources with
consumers in the Netherlands, Germany, and Belgium. As such, the hydrogen
network will form a vital part of the EHB and help kickstart the shift towards
carbon-neutral energy in Europe.
Capacities of the total hydrogen network and the different cross-borderconnections will be gradually increased. The industrial clusters are planned tobe connected from 2025-2026. The entire backbone will be operational from2030 and will have a capacity between 10 GW and 15 GW.
Danish-German Hydrogen Network (Danish backbone West andHyperlink 3)
Project partners: Gasunie, Energinet
Development phase: Feasibility / Pre-FEED phase
The 561 km project includes construction of a dedicated hydrogen pipeline
between Denmark (Danish backbone West) and Germany (Hyperlink 3 project) totransport up to 10 GW of hydrogen from Denmark to end customers in Germany.
The German part of the project will include repurposing of the existing natural
gas infrastructure to hydrogen transportation (114 km) and construction of newhydrogen pipelines (84 km). The project Hyperlink 3 is an integral part of theHyperlink system, developed by Gasunie as well as the future German National
Hydrogen Network. It will provide a possibility to transport hydrogen from theinterconnection point Ellund, domestic production sides in Schleswig-Holsteinand northern Lower Saxony and hydrogen receiving terminal in Brunsbüttel,
to the German final consumers as well as provide access to the undergroundhydrogen storage in Harsefeld, project SaltHy, developed by Storengy.
HyONE (Hydrogen Offshore Network)
Project partners: Gasunie
Development phase: Feasibility / Pre-FEED phase
HyONE focuses on offshore hydrogen transport to link the European onshorehydrogen network with offshore wind farms in the Dutch and German economic
zones in the North Sea as well as offshore connections to Norway and Denmark.
HyONE enables a large-scale rollout of offshore electrolysis and the ramp-up
of the national and cross-border North-West European hydrogen market. It links
offshore hydrogen production sites connected to Hydrogen Network Netherlands
and demand centres in Western Europe and provides interconnectors toGermany, Belgium, Denmark, and potentially to the UK. HyONE is part of theCH2-4EU project, designed to enable the transport of renewable and low-carbonhydrogen along the HI West hydrogen corridor. Planned capacities are 30 GW
for the network and 6 GW for the interconnector between the Netherlands andGermany.
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H2T (Hydrogen Offshore Transport)
Project partners: Gassco on behalf of the H2T group31
Development phase: Feasibility / Pre-FEED phase
Norway wants to actively contribute to the rapid development of the hydrogenmarket in Germany and the EU. To realise the fastest possible import of about
4 Mt/y of hydrogen and ensure the rapid availability thereof, the country also
jointly plan to use blue hydrogen for a transition period. Germany and Norway
want to work together closely to ensure a reliable energy supply for Europe thatis based on an increasing share of renewable energy. Both countries aim tobe completely climate-neutral by mid-century, Germany by 2045 at the latest,
Norway by 2050.
AquaDuctus
Project partners: GASCADE, Fluxys
Development phase: Feasibility / Pre-FEED phase
AquaDuctus will be an offshore hydrogen pipeline and connect the first largescale offshore hydrogen wind farm site SEN-1 (up to 1 GW generation capacity)
located 150 km northwest of the island of Heligoland. The 48” offshore pipeline
will transport green hydrogen to Wilhelmshaven, Germany. Through an additional
onshore pipeline, a direct link to Hyperlink will secure downstream connection tohydrogen users. AquaDuctus will be capable of picking up additional hydrogen
quantities, e.g., from further hydrogen wind farm sites, re-powering existing windfarms, and providing the interconnection of adjacent offshore hydrogen pipelines(e.g., from DK, NL, UK or NOR) aiming for export of local hydrogen production
to the European market. Hence, AquaDuctus (total length of approximately
250 km) will already be designed to transport up to approximately 20 GW ofhydrogen capacity.
Belgium Hydrogen Backbone
Project partners: Fluxys
Development phase: FEED phase
Fluxys has the ambition to link hydrogen import facilities and local hydrogenproduction in Belgium with industrial clusters through an interconnected hydrogen
backbone. This project aims to kickstart the development of the hydrogen
economy in northwest Europe. The import of hydrogen in maritime ports andinterconnections with adjacent countries such as Germany, the Netherlands, andFrance are foreseen to ensure security of supply and flexibility. Repurposing
existing infrastructure is put forward to reduce the system cost of the hydrogenvalue chain. The first phase of infrastructure is planned for implementation in
2026.
In Germany, Corridor C connects to the H2ercules (see Chapter ) to continue
supply from AquaDuctus, H2T, Hydrogen Network Netherlands, and Belgium
Hydrogen Backbone.

31 The H2T group is a potential hydrogenproducer and infrastructure owner.

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6.1.4 Corridor D — Nordic and Baltic regions
Nordic-Baltic Hydrogen Corridor
Project partners: Amber Grid, Conexus Baltic Grid, Elering, Gasgrid Finland,
Ontras, Gaz System Poland
Development phase: Pre-feasibility phase
The aim of the Nordic Baltic Hydrogen Corridor project is to enable transportof 7-11 Mt of green hydrogen produced in the Nordic and Baltic Sea region
to Central Europe and demand centers along the corridor covering up to
100% of REPowerEU domestic hydrogen supply targets. The corridor project
aims to integrate the Nordic, Baltic, Polish, and German hydrogen markets
with connecting hydrogen infrastructure and to trigger further infrastructuredevelopments to connect additional hydrogen suppliers and consumers in thesecountries. The project is aiming to foster market processes between producers,
consumers, and trading companies that might enter the hydrogen markets in
Finland, Estonia, Latvia, Lithuania, Poland, Germany, and beyond.
The Nordic Hydrogen Route – Bothnian Bay
Project partners: Gasgrid Finland, Nordion Energi
Development phase: Pre-feasibility phase
The Nordic Hydrogen Route is an initiative between Gasgrid Finland andNordion Energi to accelerate the creation of a hydrogen economy by building
up cross-border hydrogen infrastructure in the Bothnian Bay region and an
open hydrogen market by 2030. The aim of the Nordic Hydrogen Route is todrive decarbonization and support regional green industrialisation, economic
development, and European energy independence. The region has abundant
RES energy sources and is one of the key regions of Europe for green hydrogenproduction. In the Nordic Hydrogen Route project, the companies seek todevelop a network of pipelines that would effectively transport energy fromproducers to consumers to ensure they have access to an open, reliable, andsafe hydrogen market.
Baltic Sea Hydrogen Collector
Project partners: Nordion Energi, OX2, Gasgrid Finland and Copenhagen
Infrastructure Partners
Development phase: Pre-feasibility phase
The Baltic Sea Hydrogen Collector will be a newly built, large-scale, crossborder, offshore, bidirectional transmission system of 1,250 km in the Baltic Sea,
promoted by Gasgrid Finland Oy and Nordion Energi AB, and supported byco-investors OX2 AB (OX2) and Copenhagen Infrastructure Partners (CIP).
As one of the core systems envisioned as part of the EHB, the Baltic Sea
Hydrogen Collector is an offshore pipeline project with the potential capacity of
296 TWh/y that will connect mainland Finland and Sweden with Finnish Åland
island and Germany by 2030. The offshore project might also be connected toother energy islands in the region such as Gotland and Bornholm in Sweden
and Denmark. The aim of the Baltic Sea Hydrogen Collector is to unlock thesignificant offshore wind potential in the Bothnia Bay and Baltic Sea region,
creating a booming hydrogen market and connecting both supply and demand.

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Interconnector Bornholm-Lubmin
Project partners: GASCADE, Energinet
Development phase: Pre-feasibility phase
The envisioned 140 km cross-border pipeline from Bornholm to Lubmin, locatedin the priority corridor of BEMIP Hydrogen, will connect the large-scale hydrogenproduction and compressor station on Bornholm with large demand centres inGermany and central Europe through GASCADE’s repurposed onshore hydrogenpipeline network. The project intends to construct the first hydrogen pipelinein the Baltic Sea while supporting the emergence of an EU-wide network forhydrogen transport, giving access to multiple network users on a transparent andnon-discriminatory basis. The pipeline will enable the planning of several projects
developing large-scale hydrogen production on Bornholm from gigawatt-scale
offshore wind in the area already by 2027. The 42” pipeline is expected totransport upwards of 4 GWel by 2028-2030 while enabling additional capacityof up to 10 GW, meaning the pipeline can furthermore enable and enhance anaccelerated development of additional offshore wind in the region.
6.1.5 Corridor E — East and Southeast Europe
Central European Hydrogen Corridor CEHC32
Project partners: TSO of UA, EUSTREAM, NET4GAS, OGE
Development phase: Pre-feasibility
Website: www.cehc.eu
The Central European Hydrogen Corridor (CEHC) enables competitive hydrogentransport from renewable sources in Ukraine through Slovakia and the Czech
Republic to Germany and further in the EU. The project aims to be operationalby 2030, with later target transport capacity of up to 1.5 Mt/y (144 GWh/d).
The overall length of the corridor is about 1,225 km made up of more than 90%
of repurposed pipelines. The project is currently in the pre-feasibility phase,
focusing on assessment of the technical feasibility and the investment required toprepare the existing natural gas infrastructure to transport hydrogen.
HU/SK Hydrogen Corridor Project
Project partners: Eustream, FGSZ
Development phase: Pre-feasibility
The project is critical for the development of EHB Corridor E, connecting
southeastern Europe to the backbone. Initially, by 2030, hydrogen transported
through Corridor A (Italy – Austria – Germany) can be channeled through Slovakia
into Hungary for an early access to the backbone. The project also provides
access for large hydrogen customers in the Transdanubian hydrogen valley to the
backbone, such as refinery and fertilizer industry. The southeastern region will be
a net exporter by 2040, and most of the hydrogen can be transported throughthis corridor to the central parts of Europe.

32 Note that Czech and partially SK parts of
CEHC are also part of SunHyne Corridor,
see Corridor A.

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RO/HU Hydrogen Corridor Project
Project partners: Transgaz, FGSZ
Development phase: Pre-feasibility
The project is critical for the development of EHB Corridor E, connecting
southeastern Europe to the backbone. The southeastern region could be a net
exporter by 2040, and the majority of the hydrogen can be transported throughthis corridor to the central parts of Europe. The area near Algyo has the best
potential for solar PV-based renewable electricity production in Hungary, whichmakes it an ideal development zone for electrolyser projects. The Hungarian
natural gas storage operator considers development of hydrogen storage in thevicinity of the pipeline utilising depleted gas fields and three natural gas storages.
The description of the hydrogen Backbone WAG + Penta West project, whichenables hydrogen transportation from Slovakia – Austria - Germany can be foundin the project description in Corridor A. It is also part of the SoutH2 Corridor.
In Germany, Corridor E connects to the H2ercules via CEHC and CGHI projects
and also to the HyPipe Bavaria project via H2 Backbone WAG + Penta West.
GR/BG H2 Interconnection
Project partners: DESFA, Bulgartransgaz
Development phase: Feasibility
The GR/BG H2 Interconnection corridor aims to connect the future hydrogen
networks between Bulgaria and Greece at the first hydrogen interconnection
point in the Кulata/Sidirokastro region on the Bulgarian-Greek border. The newhydrogen interconnection is indispensable, as it will enable hydrogen transport
from southeastern Europe to the north and continue the efficient interoperability
between the two countries. The project on Bulgarian territory includes potential
exit points for hydrogen deliveries from Bulgaria to Romania through the futurehydrogen network of Bulgartransgaz. The entire corridor is currently being
developed and is expected to be operational in 2030.
Dedicated Hydrogen Pipeline
Project partners: DESFA
Development phase: Pre-feasibility
The Dedicated Hydrogen Pipeline project consists of a new, approximately 540
km long hydrogen pipeline with two compressor stations in Patima and Nea
Messimvria, and a possible branch comprising an additional 250 km. The aimof the project is to transport pure hydrogen mainly from the production regions
in southern and eastern Greece to the interconnector with Bulgaria for further
export and to the Kavala region, where a future storage facility will be located. The
project will enable the transport and supply of hydrogen for local consumption inindustrial areas with hydrogen demand near Athens and Thessaloniki. This new36”pipeline will run in parallel to the existing natural gas pipeline. The project is
expected to be operational in 2029.

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6.1.6 Transmission Network in Germany
Flow - Making Hydrogen Happen
Project partners: Ontras, GASCADE
Development phase: FEED phase
GASCADE, ONTRAS Gastransport GmbH, and terranets bw GmbH havedeveloped the project “Flow – making hydrogen happen” to connect the Baltic
Sea with Czech Republic and Poland and southern Germany. The flow foresees
the repurposing of existing infrastructure to supply clean hydrogen from local
sources in and around the Baltic area. Clean hydrogen produced onshore andoffshore in the Lubmin region and Baltic Sea will be transported south. Hydrogen
will flow to the Czech-German border and further to the Net4Gas network.
This cooperation is formed under the title of the Czech-German Hydrogen
Interconnector (CGHI), which will ensure an integrated cross-border hydrogen
network from the Baltic Region to central European countries.
H2ercules
Project partners: OGE
Development phase: Pre-feasibility and feasibility phases
The H2ercules network aims to create a super-sized hydrogen infrastructure forGermany and is a substantial part of the German Hydrogen Core33 network,
which is planned to be realised by 2032. The H2ercules pipeline network by
OGE consists of about 2,000 km of pipelines. For the most part, this will mean
converting pipelines from the existing natural gas network to hydrogen. On key
routes, where pipelines with sufficient capacity for conversion are not available
in the short term, H2ercules relies on new construction to support the faster
ramp-up of the European hydrogen economy. The H2ercules network will
establish connection to five European countries - Norway, the Netherlands,
Belgium, France, and Czech Republic - via pipeline and a terminal for the importof hydrogen derivatives by ship. The H2ercules pipeline network will also enable
the connection of domestic green hydrogen production and thus connect newsources to the existing pipeline network.

33 FNB Gas (2023). Hydrogen core
network. Source: https://fnb-gas.de/en/hydrogen-core-network/

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Czech-German Hydrogen Interconnector CGHI
Project partners: GASCADE, NET4GAS, OGE
Development phase: Pre-feasibility phase
Website: https://www.cghi.eu/
The Czech-German Hydrogen Interconnector (CGHI) will provide a hydrogentransportation route between potential hydrogen supply areas in the Nordic-Baltic
region, via the 150 km 100% repurposed pipeline over Czech Republic to largehydrogen demand clusters in southern Germany. Additionally, this corridor will
supply hydrogen customers in the Czech Republic along this corridor, mainly tothe expected hydrogen cluster in Northern Bohemia.
With an initial technical capacity of 144 GWh/d, the project aims to transporthydrogen as of 2030. The total length of the corridor is 1,068 km and consistsof 90%-100% repurposed pipelines.
doing Hydrogen
Project partners: ONTRAS Gastransport GmbH
Development phase: feasibility phase/pre-FEED
Website: https://www.doinghydrogen.com/
Doing hydrogen is a 550 km hydrogen transmission system that connects projects
in Mecklenburg-Western Pomerania, Brandenburg, Berlin, Saxony, and SaxonyAnhalt to form a high-performance hub: production, transport, storage, andconsumption all under one roof. The operation of doing hydrogen will start in
2026. In the medium-term Alongside Green Octopus Mitteldeutschland, doinghydrogen is one of the ONTRAS projects that has been selected by the German
Federal Ministry of Economics and Technology as Important Projects of Common
European Interest (IPCEI) in 2021.
Green Octopus Mitteldeutschland
Project partners: ONTRAS Gastransport GmbH
Development phase: feasibility/pre-FEED
Website: https://www.ontras.com/en/go
The Central German Chemical Triangle needs green hydrogen. The same istrue for the industries in Saxony-Anhalt and the steel region in Salzgitter/Lower
Saxony. Green Octopus Mitteldeutschland (GO!) is the future transport route forthis hydrogen: GO! connects the regions and integrates the future hydrogenstorage facility in Bad Lauchstädt. From 2026, GO! will ensure the securetransport of hydrogen with a network of pipelines covering around 305 km. GO!
will also make use of other hydrogen pipelines to integrate these regions into
the growing EHB. A connected cavern storage facility with a working gas volumeof 50 million cubic meters supports the hydrogen infrastructure and ensures abalance between supply and demand. Along with doing hydrogen, GO! is oneof the ONTRAS projects that has been selected by the German Federal Ministryof Economics and Technology as IPCEI in 2021.

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Hyperlink 1 & 2 & 3
Project partners: Gasunie
Development phase: feasibility phase/pre-FEED
Website: https://www.hyperlink-gasunie.de/en
A hydrogen pipeline system of the Hyperlink 1 and 2 projects will connect theDutch and German hydrogen networks. As a central part of the hydrogen network
planned by Gasunie, the pipeline will run from the border at Oude Statenzijl
and Bunder Tief through Germany to the Hamburg region. It also connects
a storage facility near Nüttermoor and the Bremen region with Leversen. The
first consumers and producers within the area covered by Hyperlink 1 will beable to be connected in 2026-2027. The Hyperlink 2 project is expected to becompleted and operational by 2029 to supply a steel plant in Salzgitter. The
project has an IPCEI status. In Heidenau, Hyperlink 3 joins up with the other
Hyperlink sections to enable the transmission of hydrogen to customers in otherparts of Germany too.
Hyperlink 4 & 5
Project partners: Hyperlink 4 – Gasunie; Hyperlink 5 – Gasunie andThyssengas
Development phase: feasibility phase/pre-FEED
Website: https://www.hyperlink-gasunie.de/en
The Hyperlink 4 project will enable the transfer of imported hydrogen from theWilhelmshaven terminal and Norway to northwestern Europe. The Wilhelmshaventerminal will be directly connected to the hydrogen network. The Hyperlink 4
project will enable direct supply to the major industrial clusters and urban centresof Hamburg, Bremen, and Hanover via the Hyperlink 1 and 2 pipelines and to
the Ruhr region via Hyperlink 5. The Hyperlink 4 and 5 projects are candidates
for PCI status and are expected to be in operation by 2030.

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