Unlike limited pilot trials in controlled settings, the first hydrogen truck is operating in standard day-to-day freight routes. This approach allows the team to measure real-life handling, costs, and operational impact. “The hydrogen truck will provide us with important insights for decarbonizing our fleet. With rising diesel and electricity prices, this technology could become an attractive operating solution,” said Ann Schildermans, TBO Manager DHL Freight, who, together with colleague Cencio Vlijt, helped drive the project from concept to launch. The truck is leased via hylane, a start-up founded in 2021 in Cologne, Germany, offering a Transport-as-a-Service model that charges only for kilometers driven. Schuurman Logistics, the long-standing carrier partner for the Eindhoven terminal, manages daily operations and provides the driver, while Teal Mobility — a joint venture of Air Liquide and TotalEnergies — supplies the hydrogen refueling infrastructure.

The pilot is planned to observe the first hydrogen truck cover approximately 300 km per day across Overijssel and Gelderland, and collect data on:

• real-life range and refueling patterns,
• energy usage under operational load,
• required driver experience and training,
• customer feedback,
• cost comparison with diesel and electric alternatives,
• and feasibility for scaling toward the 2026 diesel-free goal.

The results will help DHL Freight make decisions about its fleet in the Netherlands and upscale the company’s hydrogen-powered truck deployment. The Eindhoven project supports DHL Freight’s dedication to the Science Based Targets initiative (SBTi) and DHL Group’s goal of achieving net-zero emissions by 2050, as hydrogen continues to emerge as a viable option for medium- and long-haul transport.

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The company says that the commissioning of the first phase is still underway, with commercial operations targeted for 2026. Once completely built out, the Lingen project will deploy 200 MW of PEM electrolyzers from ITM Power in addition to 100 MW of alkaline electrolyzers that are supplied by Sunfire, thereby bringing total capacity to 300 MW by 2027. When functional, the plant will be almost twice the size of the present largest electrolyzer in Europe, which is the 54 MW PEM facility brought online by BASF located in Ludwigshafen earlier in 2025.

It is worth noting that this upcoming largest green hydrogen plant in Europe has already secured a long-term demand. In March 2025, the utility signed a 15-year offtake agreement with TotalEnergies of France to supply 30,000 tonnes per year of green hydrogen to the Leuna refinery of the company starting in 2030. The hydrogen is going to be transported through a 600 km pipeline, forming part of the emerging hydrogen core network in Germany, where it is going to displace fossil-derived hydrogen, which is used in fuel production processes.

In order to manage the intermittency from renewable power, RWE looks forward to relying on booked capacity at its Gronau-Epe hydrogen storage cavern, which is all set to enter into operations in 2027. The maturity when it comes to both the GET H2 nucleus in Lingen as well as the hydrogen storage in Epe helped them to negotiate a 15-year offtake agreement along with TotalEnergies, remarked Sopna Sury, the chief operating officer for hydrogen at RWE Generation. RWE also moved early by ordering long-lead equipment and, at the same time, also starting preparatory works much ahead of the final government funding commitments.

But the timeline goes on to expose a familiar execution barrier. While the commissioning is still underway now and a complete production is anticipated in 2027, the Leuna offtake contract does not start until 2030, hence leaving a three-year gap wherein the hydrogen output is going to need to find alternative outlets. RWE has not disclosed how the volumes are going to be managed during that period or if interim offtake, storage, or curtailed operation is going to be used.

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Satu Sipola, Fortum’s VP of P2X and Project Execution, says that this first hydrogen from Kalla is just a tangible step from vision to reality and also a prominent milestone for Fortum as well as its ambition to go ahead and explore the potential of hydrogen when it comes to decarbonizing the Nordic industries. Sipola adds that they are gaining the technical and commercial experience and expertise that’s required to go ahead and scale renewable hydrogen and also drive Nordic decarbonization. Notably, the approach by Fortum focuses majorly on building technical readiness and also commercial viability, and that too one step at a time, and Kalla is indeed that technical pilot that allows them to proceed with possible larger projects that support the industrial customers’ needs.

It is well to be noted that the hydrogen at Kalla is produced by way of electrolysis, which splits water into hydrogen as well as oxygen using fossil-free electricity. Hydrogen goes on to act as an energy carrier, which can store and also transport energy without producing CO₂ when being used, hence making it valuable where direct electrification is not possible.  Apparently, there are two electrolyzer technologies that are integrated into one plant and are being commissioned in phases—a 1 MW alkaline electrolyzer from Stargate Hydrogen as well as a 0.75 MW PEM electrolyzer from Hystar. Interestingly, operating both systems under real-time conditions goes on to offer certain valuable insights when it comes to efficiency, agility, safety, and scalability.

The Kalla Test Center is going to function as a learning and development platform till 2028. The findings are going to help shape possible commercial-scale hydrogen projects for Fortum and its future customer solutions. Hydrogen from Kalla is going to be delivered to P2X Solutions Oy by way of an existing agreement. Part of the hydrogen is also going to be used in terms of research and development, as well as at the Loviisa nuclear power plant in Fortum.

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This marks the second PCI/PMI list released since the TEN-E reform in 2022, and it points to the European Commission’s ongoing effort to develop cleaner energy corridors and expand digital-ready networks. The 100 hydrogen and electrolyzer initiatives are positioned to contribute to decarbonizing the region’s energy mix while supporting industrial capability within the bloc. As the Commission noted, “These cross-projects will strengthen energy connectivity across the continent, bringing nearer the completion of the Energy Union.” Collectively, the approved schemes form part of an estimated €1.5 trillion investment outlook for European energy infrastructure between 2024 and 2040, demonstrating the scale of the ongoing transition.

EU hydrogen projects included on the PCI/PMI list will receive coordinated political support through the Energy Union Task Force and regional decision-making groups. Their rollout aligns with forthcoming measures such as the European Grids Package and the Energy Highways initiative, both highlighted by President von der Leyen, which aim to relieve structural bottlenecks across the continent’s energy networks. The list now proceeds to a two-month examination period by the European Parliament and Council. Once endorsed, the Commission intends to work directly with member states and project developers to advance construction. Since 2014, the CEF-Energy programme has committed €8 billion to interconnection efforts, and the Commission has proposed expanding its 2028–2034 budget to €29.91 billion to maintain momentum behind these priorities.

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The INPEX hydrogen park also reflects the company’s long-running commitment to Niigata Prefecture through a “local production for local consumption” model. Natural gas from the Minami-Nagaoka Gas Field serves as the main feedstock, and CO₂ created during hydrogen and ammonia production will be directed into the reservoir beneath the Hirai area of the Higashi-Kashiwazaki Gas Field, where gas extraction has already ended. The hydrogen produced through this project will supply electricity generation at the Kashiwazaki Hydrogen Power Plant and be delivered through the grid to users in Niigata Prefecture. A portion of that hydrogen will be synthesized into ammonia for customers located in the same region.

INPEX said the purpose of the INPEX hydrogen park is to strengthen its experience across the full hydrogen and ammonia value chain and build a record of operational know-how that can support its role in these sectors both domestically and internationally. Parts of the hydrogen and ammonia production system, including CO₂ capture, are backed by the New Energy and Industrial Technology Development Organization under its “Fuel Ammonia Utilization and Production Technology’’ program. Work on subsurface CO₂ storage is being advanced with the Japan Organization for Metals and Energy Security through joint research on depleted oil and gas fields in Japan.

The initiative forms a core component of INPEX Vision 2035, released in February 2025, which sets out the company’s plans for a responsible energy transition and names CCS and hydrogen as key growth areas. INPEX noted that commissioning and the introduction of natural gas represent a major step in the project’s rollout. Running from the second half of fiscal 2022 through the end of fiscal 2025, with room for extension, the project includes blue hydrogen and clean electricity production, low-temperature and low-pressure ammonia synthesis, studies on CO₂ storage potential, enhanced gas recovery assessments, and monitoring designed to verify safe CO₂ injection.

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Air Products is positioned to deliver the overwhelming share of that volume. Its contract allows for as much as 36.5 million pounds of liquid hydrogen to be sent to Kennedy Space Center and Cape Canaveral Space Force Station in Florida, as well as Marshall Space Flight Center in Alabama and Stennis Space Center in Mississippi. Plug Power’s contribution, capped at up to 480,000 pounds, is earmarked for Glenn Research Center and the Neil A. Armstrong Test Facility in Ohio, at a price point of roughly $2.8 million. Together, these allocations represent the backbone of the NASA hydrogen contracts and ensure uninterrupted access to a critical cryogenic propellant.

NASA highlighted the value of the multi-year, fixed-price setup, noting how it stabilizes planning for engine testing and flight development tied to future lunar and Martian missions. The distribution between two suppliers also adds a degree of resilience to the agency’s hydrogen procurement chain. Air Products extends a relationship with NASA that reaches back to the Apollo era, while Plug Power increases its presence in aerospace fueling following its recent activity in green hydrogen production.

Liquid hydrogen has supported NASA missions for more than six decades, and the latest contracts maintain that legacy through 2030. The agency expects the secured volume to keep propulsion tests, launch operations, and aeronautics experimentation on schedule. Maintaining purity standards, managing cryogenic logistics, and scaling production will remain central challenges as NASA advances its next wave of exploration and relies on producers tied to the NASA hydrogen contracts to keep operations moving.

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Project records show that GUOFUHEE advanced the effort through a series of stages. In May 2023, the company completed its core equipment package after working through several challenges specific to liquid hydrogen production. By May 2024, the systems had been delivered and installed at the Qilu Hydrogen Energy base in Zibo, Shandong, where the full operating sequence was commissioned. A panel of domestic liquid hydrogen specialists reviewed the setup and gave it the go-ahead. Once the team wrapped another cycle of optimization and steady-state testing, the project shifted into steady mass production, holding to its early pledge to deliver engineered capability and industrial output on time.

Performance indicators from the Qilu Liquid Hydrogen Project provide a snapshot of how the facility is performing at scale. The comprehensive energy consumption for liquefaction is reported at under 12 kW•h/kg-LH₂. Para-hydrogen content in the product exceeds 98.5%, and the purity reaches above 7N—figures that meet or surpass recognized international thresholds. These results support lower production costs and match the needs of downstream users, including fuel cell vehicle suppliers and semiconductor-grade gas applications. The plant’s operation is built around GUOFUHEE’s multi-stage pre-cooling hydrogen expansion refrigeration technology, and both the 20K hydrogen liquefaction cold box and the hydrogen expander carry independent intellectual property rights.

GUOFUHEE notes that the equipment design, with its compact form, stable operation, and heat-exchange performance, suits larger deployment scenarios. The mass production level reached at the Qilu Liquid Hydrogen Project is seen as an early marker for the hundred-ton-class liquid hydrogen projects expected to follow. It also aligns with China’s “West Hydrogen East Transmission” strategy, supporting long-distance movement of hydrogen and offering a model for peak-shaving and storage within pipeline networks. As liquid hydrogen moves deeper into applications tied to new energy, aerospace, advanced materials, and the low-altitude economy, the project is positioned to feed into wider industrial development and a new wave of emerging growth areas.

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Chinese regulators have formally designated the project as a National Hydrogen Demonstration Project, underscoring its strategic importance. CCTV said the site “provides a replicable model for the green transformation of the coal-to-chemicals industry,” reflecting the government’s expectation that this large-scale trial can guide similar upgrades across the sector. The broader coal chemical industry remains central to China’s domestic supply of chemicals, oil, and gas, helping reduce import dependence. But its rapid expansion has also been identified as a major obstacle to achieving the country’s 2025 carbon intensity reduction targets, making this early coal-to-hydrogen shift a critical testing ground for emissions mitigation.

The project is operated by state-owned Datang Group. Station manager Cao Guoan told CCTV that the plant is forecast to produce 70.59 million cubic meters of hydrogen annually, although current output levels were not disclosed. The facility continues to rely on coal gasification to produce syngas, a mix of carbon monoxide and hydrogen used to make ammonia, methanol, and olefins, but the new element is the integration of green hydrogen to reduce the carbon footprint of these outputs.

A dedicated 150-megawatt wind and solar farm powers the hydrogen system and sends surplus electricity to the national grid. This renewable energy supply enables the facility to produce green hydrogen instead of fossil-based hydrogen, marking the operational core of the coal-to-hydrogen shift now underway. As the plant moves into full commercial service, industry observers will be watching closely to see whether it can establish a workable blueprint for the next phase of China’s chemical-sector decarbonization.

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The Delegated Act builds on the wider policy framework that includes the Renewable Energy Directive 2018/2001 (RED III), which already defines strict rules for renewable fuels of non-biological origin (RFNBOs). It also ties in with the June 2024 rollout of the Hydrogen and Gas Market Package, which aims to help bring both renewable and low-carbon gases and hydrogen into the European energy system.  While renewable hydrogen remains the EU’s preferred option for meeting climate goals, its production is still far from matching expected demand, making low-carbon alternatives an important short- and medium-term part of the energy transition. The new rules confirm that both renewable and low-carbon hydrogen must reach a 70% emissions-reduction threshold compared with fossil fuels, even though the renewability requirement only applies to the electricity used to produce renewable hydrogen.

The methodology in the Delegated Act mirrors the life-cycle approach used in Delegated Acts 1184/2023 and 1185/2023 for RFNBOs. It includes standard greenhouse gas emission intensity tables for material and energy inputs, and it allows hydrogen to be produced through different pathways, including electrolysis or steam methane reforming with carbon capture. For electrolysis-based hydrogen, the emission intensity of electricity is calculated at the level of countries or bidding zones. The Delegated Act also notes that emissions from renewable electricity, such as wind, solar, geothermal, or hydropower, are treated as zero. One example in the annex shows Finland with an electricity-emission intensity of 12.5 gCO₂eq/MJ in 2023, the second lowest in the EU. This gives an advantage to hydrogen projects operating in Finland, as they can more easily meet the required greenhouse gas savings.

The act leaves unresolved whether nuclear electricity can be used for low-carbon fuels, noting that the Commission will review alternative pathways, including nuclear, by 1 July 2028. It also notes that carbon captured during low-carbon hydrogen production can either be stored in geological formations or fixed into long-lasting products listed in Delegated Act 2024/2620, such as carbonated cement and concrete. Certification of low-carbon hydrogen is set out in Directive 2024/1788 and follows the same structure used for renewable fuels, with voluntary schemes permitted to carry out verification.

Member States have to bring the Delegated Act into national law by August 2026, and Finland plans to do so through its Sustainability Act, with a government proposal expected in spring 2026. As the rules take shape, the framework should give developers and investors more certainty, especially in places where grid-emission levels are low and biogenic CO₂ is readily available.  These conditions place Finnish producers in a strong position to benefit from the evolving regulatory landscape for both low-carbon and renewable hydrogen across Europe.

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The report concludes the BarMar route is technically feasible because every identified challenge can be managed through established engineering practices. This clarity lets the partners continue making progress on the overall schedule, which is part of the future European hydrogen network planning. The schedule now sets the Commercial Operation Date (COD) for BarMar in 2032. This is the same date targeted for the CelZa project.

This update reflects the project’s technical demands and the work of the countries involved, which are all developing their own national hydrogen networks. Securing permits and synchronizing the authorization schedule is essential, as H2med is designed to be the backbone connecting all these systems. During the joint Council of Ministers on August 29th 2025, France and Germany reaffirmed their common approach to supporting the corridor’s timely implementation. Also, the progress being achieved now in cross-border governance and regulatory harmonization is truly pioneering. This diligent, laborious effort will not only ensure the success of H2med; it will help establish an essential blueprint for subsequent transnational energy projects.

The year 2025 marked a clear acceleration for H2med, which followed its designation as a Project of Common Interest by the European Commission in 2024. Key steps included the signing of Grant Agreements with the European Climate, Infrastructure and Environment Executive Agency (CINEA) for both BarMar and CelZa. The BarMar company was also created last July to advance the Barcelona–Marseille interconnection. Political backing remains strong across all involved member states, supported by the European Commission, which has called the corridor a priority “energy highway.” Industry support has also widened through the H2med Alliance, now made up of 49 organizations across the hydrogen value chain. For background on the corridor, see our previous coverage of the BarMar hydrogen pipeline and the H2med hydrogen project.

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