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3The European Commission has selected the Northern Netherlands to become the leading European hydrogen region and supports establishment of a complete local (green) hydrogen ecosystem covering production, storage, distribution, refueling and final use of hydrogen (Cordis, H2Valley, 2019). In line with the European recognition, the Dutch government has set the goal to establish a hydrogen ecosystem by 2025 that would further expand to Western Europe by 2030.
Yet before the European Union nominated the Northern Netherlands as European Hydrogen Valley, the key stakeholders in the Northern Netherlands – industry, SMEs, knowledge institutions and government – committed to the long-term cooperation in development of the green hydrogen market. Subsequently, the three regional governments of the Northern Netherlands, - Groningen, Friesland and Drenthe, - prepared the common Hydrogen Investment Agenda (2019), which was further elaborated in the common Hydrogen Investment Plan (2020). The latter includes investments amounting to over 9 billion euro, which is believed will secure some 66.000 existing jobs and help create between 25 thousands (in 2030) and 41 thousands (in 2050) new jobs.
However, implementation of these ambitious plans to establish a hydrogen ecosystem of this scale will require not only investments into development of a new infrastructure or technological adaptation of present energy systems, e.g., pipelines, but also facilitation of economic transformation and securing the social support and acceptance. What are the prospects for the social support for the developing European Hydrogen Valley in the Northern Netherlands and its acceptance by inhabitants?
The paper discusses the social support and acceptance aspects for a hydrogen ecosystem in the context of regional experiences of energy transition, including the concerns of energy justice, safety, and public trust that were raised in the recent past.
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This report analyzes the different legal aspects when establishing a hydrogen hub in the region of Delfzijl. It focuses on hydrogen networks, transport, production, renewable targets, mass balancing and hydrogen distribution, from an European level as well as a Dutch level.
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While prominently highlighted in the National Plan Energy of the Netherlands government (2022), green hydrogen has been facing obstacles in terms of scaling up in energy markets and thus fulfilling expectations. An important reason is that production of green hydrogen has remained relatively costly, partly due to the lack of economies of scale as of yet in combination with investment dilemmas caused by market uncertainties.
The project H2opper aims at addressing this dilemma by designing a local hydrogen hub with a governance structure, standardised contracts and a virtual trading platform. This paper explores the economic benefits for suppliers of green hydrogen when modifying their production profiles according to electricity market profiles. Assuming that a producer continues to trade the majority of its produced green hydrogen via long-term hydrogen purchase contracts, as is the default trading option for securing finance investment decisions, and supplies the remainder via short term (‘spot’) market trading, additional financial benefits can be realised. The paper analyses examples of green hydrogen production profiles and impacts of each profile on the levelized costs of green hydrogen.
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Green hydrogen is increasingly positioned as an important element of Europe's energy transition, particularly for decarbonising sectors that are difficult to electrify directly and for integrating growing shares of renewable electricity. Yet regional hydrogen ecosystems often remain fragmented and immature. This paper uses evidence from Green Hydra regional market system mapping exercises to analyse green hydrogen market development across partner regions, with particular attention to recurring barriers, enabling conditions, and patterns of market-system fragmentation. Based on stakeholder input generated through the Green Hydra market system mapping exercise and subsequent comparative analysis, the paper distinguishes barriers in the hydrogen value chain, the enabling business environment, and supporting services. The findings show that renewable potential and early pilot activity are widespread, but integrated value chains, demand formation, infrastructure, regulatory clarity, and supporting services remain underdeveloped. The paper argues that regional green hydrogen development should be understood as a market-system formation challenge, in which technology, infrastructure, demand, regulation, finance, and supporting services must develop together.
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Biogas production involves the complex process of anaerobic digestion in bioreactors. This paper presents numerical modeling results and analysis of bioreactors. We discuss research methodology, model geometry, internal bioreactor processes, and possible modifications. Two mathematical models and their results are detailed, including PDE models and discussions on their outcomes. Additionally, qualitative and quantitative biogas parameters were experimentally studied using chicken manure biomass and a bioreactor prototype, with and without biomass mixing. Mixing increased CH4 concentration, with maximum levels of 77.5 % and 63.2 % for mixed and unmixed biomass, respectively. Biogas yield increased by up to 36.0 % with biomass mixing, demonstrating its impact on production efficiency. Furthermore, this research identifies opportunities for integrating hydrogen energy within biogas systems. By capturing and utilizing CO2 during biogas upgrading processes, such as biogas-to-hydrogen conversion, environmental benefits and carbon capture are realized. Utilizing captured CO2 for carbon capture and storage (CCS) or synthesizing synthetic methane underscores the renewable energy potential of biogas systems. In summary, this study provides insights into biogas production dynamics and highlights potential synergies between biogas production and hydrogen energy. These findings contribute to advancing understanding of renewable energy systems and their role in sustainable energy futures.
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With space constraints onshore, strong renewable resources available far offshore and growing green hydrogen demand, far offshore green hydrogen production may be an attractive option. To assess this potential, a mixed integer quadratically constraint programming (MIQCP) optimization model was developed to find the cost per kilogram of far offshore green hydrogen in specific scenarios. The design of the far offshore green hydrogen supply chain was optimized with this model for six high potential scenarios in varying locations and the results were analyzed. It was found that far offshore green hydrogen costs are in the same order of magnitude as the costs of its alternatives. Far offshore green hydrogen may be considered marginally competitive with these alternatives from 2035 onwards in the analyzed scenarios when taking into account the considerable advantages of far offshore production, such as avoidance of scarce land usage in crowded areas and certain geopolitical considerations.
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Excess of renewable electricity from wind turbines or solar panels is used for electrolysis of water. To store this renewable energy as methane, the hydrogen is fed to an anaerobic digester to stimulate biological methanation by hydrogenotrophic methanogens. These work packages focus on the best ways for hydrogen delivery and the community changes in a biomethanation reactor as a result of hydrogen supply.
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