Hydrogen becomes reality

Transport over long distances generally takes place via underground pipelines. Primarily, existing pipelines that are currently part of the natural gas transmission network are used. These pipelines can be converted for the transport of hydrogen.

In the GET H2 Nukleus project, for example, mostly existing pipelines are being used. Of the approximately 130-kilometre route, 115 kilometres are existing pipelines currently transporting natural gas, which will be converted for hydrogen transport. A further 15 kilometres of pipeline will be newly constructed by Evonik between Marl and Gelsenkirchen-Scholven.

The hydrogen core network, which will be gradually developed in Germany by 2032, will comprise around 9,000 kilometres of pipelines. About 60% of these will be existing lines, with the remainder being newly built.

Up to now, hydrogen has been used almost exclusively as a raw material in industry. In the chemical and petrochemical sectors, it plays a key role in numerous production processes. It is also used in the food industry, for example in fat hardening. In such applications, hydrogen cannot be replaced by electricity. As an energy carrier, hydrogen is currently used only to a limited extent in Germany. Overall, around 55–60 TWh per year are consumed (German Bundestag, as of 2020).

According to the Federal Government, demand is expected to rise to 90–110 TWh per year by 2030. In addition to existing uses, green hydrogen is primarily expected to reduce CO₂ emissions in steel production and in the manufacture of climate-neutral synthetic fuels for air, maritime and heavy goods transport. Its use in heating and as a backup for electricity generation using hydrogen is also under discussion.

Many countries and regions have substantial potential to produce and export green hydrogen. According to the National Hydrogen Strategy, about 70% of the hydrogen to be used in Germany is expected to be imported — mainly from Norway, Spain, North and South African countries as well as South American countries.

Hydrogen from European or neighbouring regions, such as North Africa or Scandinavia, can be transported via pipeline systems, in a similar manner to existing natural gas imports.

Hydrogen from more distant countries such as Australia or Chile will be shipped to European ports — in liquefied form, as derivatives like ammonia, or bound to a liquid carrier known as a Liquid Organic Hydrogen Carrier (LOHC). At the ports, it will be converted back into gas and fed into the hydrogen network.

More information on this topic can be found in the GET H2 factsheet H2 import.

No. Transporting hydrogen via pipelines is a proven technology. In Germany and many other countries, privately operated hydrogen networks—such as those run by Air Liquide in the Rhineland and Ruhr areas, BASF in Ludwigshafen, or Linde in Leuna—have been safely managed for decades. The systems are professionally monitored and maintained to minimise all potential risks continuously.

The additional electricity consumption from electrolysers must be met by substantially expanding renewable energy generation and through renewable energy import strategies. In 2025, nearly 56% of the electricity used in Germany came from renewable sources. This share must continue to increase nationwide.

However, it does not make sense to wait until all electricity demand is met by renewables before starting hydrogen production. Both renewable electricity generation and demand naturally fluctuate. To cover demand at all times, an excessive number of wind and solar installations would have to be built — many of which already have to be curtailed in very windy or sunny periods. Hydrogen makes it possible to store surplus electricity from wind and solar to balance these fluctuations.

Regardless of the hydrogen infrastructure, achieving climate targets will require a sharp rise in electricity demand and a corresponding expansion of generation capacity.

Hydrogen is mainly stored in so-called cavern storages—underground salt caverns that have safely stored natural gas for decades and can be converted for hydrogen use. New salt caverns can also be developed for hydrogen storage. Most existing gas and planned hydrogen storage facilities are located in north-western Germany. Nearly 90% of all potential cavern storages in Europe are found in East Frisia, Oldenburg, and Münsterland. The first hydrogen storage facility to be connected to the GET H2 Nukleus project in 2026 is located in Gronau-Epe. On a smaller scale, tube trailers or gas tanks can also be used. Only proven and safe technologies are employed. The GET H2 partner Linde already operates hydrogen cavern storage facilities and has summarised its experience in a case study available for download.