Forschungsstelle für Energienetze und Energiespeicher (FENES) / Forschungsgruppe Energiespeicher
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This paper investigates the implications of green hydrogen production on Algeria’s future electricity system using the open-source PyPSA-Earth modeling framework. Three decarbonization scenarios are analyzed for 2050: (i) electricity-only, (ii) moderate hydrogen production for domestic industry, and (iii) large-scale hydrogen production for export. Results show that all pathways require a significant scale-up of solar PV capacity, with hydrogen ambitions driving further increases in generation, storage, and transmission infrastructure. The spatial mismatch between renewable resources in the south and demand centers along the coast leads to substantial north–south grid expansion needs, particularly for domestic hydrogen use. In contrast, hydrogen exports can leverage existing inland gas pipelines, offering co-benefits through infrastructure repurposing. The study highlights how hydrogen strategies shape power system design and emphasizes the need for integrated planning of electricity and gas networks to support a cost-effective, renewables-based energy transition in Algeria.
Der Hochlauf der Wasserstoffwirtschaft ist ein zentraler Baustein der Energiewende und essenziell für die Dekarbonisierung der Industrie sowie die Erreichung der Klimaziele. Die bestehende Förderlandschaft in Deutschland und Europa umfasst eine Vielzahl an Instrumenten, darunter direkte Projektsubventionen wie die Important Projects of Common European Interest Wasserstoff, auktionsbasierte Fördermechanismen wie die European Hydrogen Bank und H2Global, Carbon Contracts for Difference wie die Klimaschutzverträge, indirekte Förderinstrumente wie das europäische und nationale Emissionshandelssystem, sowie regulatorische Maßnahmen wie sektorale Nutzungsquoten und Nachhaltigkeitszertifizierungsverpflichtungen. Diese Instrumente sollen Investitionsanreize schaffen und die Marktintegration erneuerbarer und kohlenstoffarmer Wasserstofftechnologien unterstützen.
Allerdings zeigt die Analyse erhebliche Herausforderungen auf. Die Vielzahl an Instrumenten und bürokratischen Prozessen führt zu einer hohen Komplexität, was insbesondere für kleine und mittelständische Unternehmen eine Teilnahme erschweren kann. Zudem bestehen Zielkonflikte zwischen dem politisch angestrebten schnellen Markthochlauf und den strengen Nachhaltigkeitsanforderungen für erneuerbaren Wasserstoff und dessen Derivate. Die mangelnde Investitionssicherheit, bedingt durch fehlende langfristige Verträge, unsichere politische und schwer einhaltbare regulatorische Rahmenbedingungen, hemmt den Kapitalfluss und bremst die Entwicklung eines stabilen Wasserstoffmarktes.
Zur Beschleunigung des Hochlaufs sind eine Vereinfachung und bessere Abstimmung bestehender Fördermechanismen erforderlich. Die Unterstützung langfristiger Abnahmeverträge sowie eine gezielte und effektive Nutzung der finanziellen und personellen Kapazitäten können dazu beitragen, Investitionen zu erleichtern und eine nachhaltige Wasserstoffwirtschaft in Deutschland und Europa zu etablieren.
Achieving climate neutrality requires large-scale production of green hydrogen and its derivatives. A persistent cost gap between producers and offtakers, however, impedes market growth. Our study couples European-African energy markets to analyse the role of the H2Global mechanism in bridging this gap, employing sector-coupled energy models. We find that no analysed pathway is cost-competitive in 2030, with African export costs (140-229 €/MWh) exceeding European willingness to pay (40-100 €/MWh) for hydrogen, ammonia, and methanol. The required annual funding ranges between 0.6 and 11.4 billion €. By 2050, early-stage support enables a market entry and the ramp-up of a hydrogen and Power-to-X economy: trade volumes of up to 236 TWh become cost-competitive, potentially reaching 450 TWh through reinvested savings. We conclude that, although ambitious European climate targets are the main reason for market ramp-up, the H2Global mechanism is a key and cost-effective instrument for overcoming the initial 'chicken-and-egg' problem, enabling market creation and ramp-up.
Michael Sterner zeigt in "So retten wir das Klima", dass Klimaschutz machbar ist und lange geglaubte Mythen zur Energiewende längst hinfällig sind. Er erklärt anschaulich, warum wir dringend ohne fossile Rohstoffe auskommen müssen, sich unsere Energiegewinnung wieder oberirdisch abspielen muss und die Sonne im Zentrum unserer zukünftigen Energie-versorgung steht. Dabei geht er auf die einzelnen Bereiche Strom, Wärme, Mobilität und Industrie ein und macht mehr als deutlich: Es ist alles da, was wir für eine nachhaltige Energiewende brauchen - wir müssen nur wollen!
PV and wind systems with PEM electrolysis offer great potential for producing hydrogen with low emissions. Our research has identified the ecologically optimal size of PEM in relation to fixed PV/wind capacities. We calculate efficiencies and production volumes for PEM with 240 capacity and site variations. We analyse the global warming potential of all systems and draw conclusions about the optimal system design. The lowest GWP is achieved at the site with the highest full load hours with 1.32 kg CO2-eq/kg H2 (Wind, 28 MW electrolysis) and 4.24 kg CO2-eq/kg H2 (PV, 23 MW electrolysis). We have identified a clear trend: increasing PV/wind full load hours leads to higher ideal PEM capacities. However, there is a significant discrepancy between the ideal economic and ecological capacity. Furthermore, higher electrolysis capacities can achieve lower emissions as they increasingly operate at a more efficient partial load.
The ramp-up of the hydrogen and Power-to-X economy in the EU and Germany is supported by a diverse mix of instruments. Existing research primarily examines individual support mechanisms or their interactions with energy markets and does not provide a comprehensive comparison of the wide range of EU and national instruments shaping the hydrogen and Power-to-X landscape. The objective of this study is to address these gaps by conducting a comprehensive, system-level analysis of how EU and national instruments collectively shape the ramp up of H2 and Power-to-X markets within the evolving legal framework of the Renewable Energy Directive III. To this end, this paper systematically analyses and compares key instruments - including the EU Emissions Trading System, Important Projects of Common European Interest, Carbon Contracts for Difference, H2Global and the European Hydrogen Bank - and evaluates their structure and impact across the hydrogen and Power-to-X value chain, encompassing production, transport and consumption. The analysis is based on a systematic literature review, through which relevant information is collected, structured, and organised into datasets using clearly defined criteria. This approach enables a transparent comparison and further analysis of the instruments while also providing the quantitative basis for the calculation of CO2 mitigation costs of expenditure-based instruments. Positive synergies can be obtained when they complement one another, such as when market mechanisms like H2Global are combined with investment subsidies like the Important Projects of Common European Interest. However, significant structural challenges remain. There are high bureaucratic hurdles for funding instruments like the Important Projects of Common European Interest and Carbon Contracts for Difference. The EU regulatory framework, particularly strict Renewable Fuels of Non-Biological Origin criteria, provides clear sustainability goals but can be a curse, limiting funding eligibility for viable, emission-free projects while other technologies like electromobility face no such restrictions. Furthermore, Renewable Fuels of Non-Biological Origin criteria on CO2 origin hinder the import of carbon-based Power-to-X products, putting the EU at a disadvantage. Our calculations on CO2 mitigation costs show that the European Hydrogen Bank and H2Global have lower greenhouse gas mitigation costs than Carbon Contracts for Difference by making use of existing infrastructure and green drop-in fuels. In conclusion, while the current instrument architecture offers a foundation, its potential is limited by incoherence, bureaucratic complexity, and regulatory contradictions. To fully unlock the new hydrogen and Power-to-X economy, greater coordination among instruments, more pragmatic Renewable Fuels of Non-Biological Origin criteria, and a reevaluation of rules on CO2 origin are needed. Ultimately, the most effective approach combines fraud-free, strictly enforced quotas with efficient instruments like the European Hydrogen Bank and H2Global.
The increasing demand for hydrogen in Europe and the development of cross-border infrastructure, such as the SoutH2 Corridorconnecting Tunisia, Italy, Austria, and Germany, underscore the importance for hydrogen storage solutions to ensure supplysecurity and competitive pricing. Without storage, producers face increased market dependency, as electrolyzers require con-tinuous operation to remain economically viable. At the same time, storage offers opportunities to strengthen domestic valuechains by securing hydrogen supply for local industries. To assess the system-level impact of underground hydrogen storageand its implications for hydrogen partnerships, we integrate GIS-based salt cavern potentials into PyPSA-Earth and apply theframework to Tunisia. Salt caverns are currently largely considered the most economical option for large-scale hydrogen storage,offering operational flexibility. Underground storage is represented as an endogenously optimised, regionally constrained option,enabling a direct comparison between scenarios with and without geological storage under identical demand, technology, andpolicy assumptions.Our results show that underground hydrogen storage enables seasonal balancing at multi-terawatt-hour scale, reshaping hydro-gen system design. Storage availability substitutes most aboveground hydrogen tank capacity, improves electrolyser utilisation,and reduces levelised hydrogen production costs by approximately 0.10 € kg−1. Moreover, it decouples hydrogen production fromshort-term electricity variability and export demand, enhancing supply stability and export competitiveness.Beyond the Tunisian case, the findings underscore the strategic role of geological storage in international hydrogen trade. Byincreasing resilience and reducing cost volatility, underground hydrogen storage strengthens the position of exporting regionsand supports more balanced and sustainable hydrogen partnerships.
This thesis identifes Power-to-Gas in general and biological CO2-methanation in trickle-bed reactors in particular as promising energy storage and sector coupling technology ready for application but with further optimization potential.
It reviews the global status and development of Power-to-Gas technology as to be of exponentially growing importance in energy systems changing towards renewable power supply and analyzes optimization and standardization potential for biological CO2-methanation in tricklebed reactors deriving an improved methanation process.
Process development and experiments on hydrodynamical and biological improvement of such a setup were performed, leading to an optimized combination of a packing and microorganisms in pure culture embedded in the new ORBIT-process. First experimental results give evidence of successful application of different optimization approaches implemented in a technical center scale setup.
The determination of the optimal location, types and size of additional required reactive power sources is a main interest of Reactive Power Planning (RPP) investigations and of this paper. The planning problem addresses the maintenance of voltage stability, which is an ancillary service in Germany, and can be formulated as a mixed-integer optimization prob-lem. The aim of this work is a techno-economically efficient coverage of the deficient steady state voltage deviation demands (VDD) by placing new reactive power sources with adequate size or extending the reactive power potential of existing sources. An optimization model is set up to solve the planning problem by using load flow voltage sensitivities, which quantify and evaluate the technical efficiency of new reactive power sources in relation to the present voltage deviation demands. Operating and investment costs are used as economic decision parameters. Within an application example, which is carried out with an exemplary transmission system, the solution of the planning problem is discussed.
