Policy & Socio-Economics

Green hydrogen has the potential to contribute to the decarbonization of the fossil fuel industry and its development is expected to increase in the coming years. The social dynamics among the various actors in the green hydrogen sector are studied to understand their public perception. Using the technological innovation system research approach for the stakeholder analysis and the qualitative thematic analysis method for the interviews with experts this study presents an overview of the actors in the green hydrogen sector and their relations in Luxembourg. As a central European country with strategic political and geographic relevance Luxembourg offers a timely case for analyzing public perception before the large-scale implementation of green hydrogen. Observing this early stage allows for future comparative insights as the national hydrogen strategy progresses. Results show high expectations for green hydrogen in mobility and industry but concerns persist over infrastructure costs safety and public awareness. Regional stakeholders demonstrate a strong willingness to collaborate recognizing that local public acceptance still requires effort particularly in areas such as clear and inclusive communication sharing knowledge and fostering trust. These findings provide practical insights for stakeholder engagement strategies and theoretical contributions to the study of social dynamics in sustainability transitions.

The ongoing digitalization of energy infrastructure is a crucial enabler for improving efficiency reliability and sustainability in gas distribution networks especially in the context of decarbonization and the integration of alternative energy carriers (e.g. renewable gases including biogas green hydrogen). This study presents the development and application of a Digital Twin framework for a real-world gas distribution network developed using open-source tools. The proposed methodology covers the entire digital lifecycle: from data acquisition through smart meters and GIS mapping to 3D modelling and simulation using tools such as QGIS FreeCAD and GasNetSim. Consumption data are collected processed and harmonized via Python-based workflows hourly simulations of network operation including pressure flow rate and gas quality indicators like the Wobbe Index. Results demonstrate the effectiveness of the Digital Twin in accurately replicating real network behavior and supporting scenario analyses for the introduction of greener energy vectors such as hydrogen or biomethane. The case study highlights the flexibility and transparency of the workflow as well as the critical importance of data quality and availability. The framework provides a robust basis for advanced network management optimization and planning offering practical tools to support the energy transition in the gas sector.

This study assesses the feasibility and profitability of marine hybrid clusters combining wave energy converters (WECs) and offshore wind turbines (OWTs) to power households and marine aquaculture. Researchers analyzed two coastal sites: La Serena Chile with high and consistent wave energy resources and Ensenada Mexico with moderate and more variable wave power. Two WEC technologies Wave Dragon (WD) and Pelamis (PEL) were evaluated alongside lithium-ion battery storage and green hydrogen production for surplus energy storage. Results show that La Serena’s high wave power (26.05 kW/m) requires less hybridization than Ensenada’s (13.88 kW/m). The WD device in La Serena achieved the highest energy production while PEL arrays in Ensenada were more effective. The PEL-OWT cluster proved the most cost-effective in Ensenada whereas the WD-OWT performed better in La Serena. Supplying electricity for seaweed aquaculture particularly in La Serena proves more profitable than for households. Ensenada’s clusters generate more surplus electricity suitable for the electricity market or hydrogen conversion. This study emphasizes the importance of tailoring emerging WEC systems to local conditions optimizing hybridization strategies and integrating consolidated industries such as aquaculture to enhance both economic and environmental benefits.

Addressing GHG emissions in industrial sectors is crucial for developed nations’ energy and environmental policies. European countries use diverse strategies to mitigate industrial GHG impacts with energy models evaluating national objectives and supporting policy implementation. A new hybrid bottom-up technology-oriented simulation model has been developed for Slovenia’s industrial sector focusing on energy-intensive industries like paper metal chemical and cement production. This model linked with the macroeconomic GEM model assesses the impacts of GHG reduction measures on the national economy. This paper introduces the Reference Energy System model for the industrial sector REES SLO aiding Slovenia’s NECP update. It details input parameters model structure proposed measures peculiarities of energy-intensive industries and calculation results. The findings indicate that decarbonizing Slovenia’s industrial sector is feasible but demands immediate policy intervention substantial investments and a collaborative approach among stakeholders. Advanced technologies such as carbon capture utilization and storage (CCUS) hydrogen-based solutions and enhanced energy efficiency measures are essential components of this transition. The integration of renewable energy sources (RES) and circular economy principles further strengthens pathways toward sustainability. The REES IND model underscores the importance of aligning industrial decarbonization strategies with broader economic and environmental objectives. It provides a comprehensive framework for policymakers to evaluate the effectiveness of proposed measures and their long-term impacts. Achieving these goals requires a phased approach beginning with energy efficiency improvements and progressing to structural changes and advanced technologies. The model’s insights pave the way for sustainable industrial transformation aligning Slovenia’s industrial sector with national and European Union climate objectives.

In response to the growing global interest in hydrogen as an energy carrier this study provides the first attempt to develop a baseline inventory of U.S. hydrogen emissions from production distribution and storage. The scope of this study was limited to pure hydrogen emissions and excludes emissions from low purity hydrogen streams and carriers. A detailed literature search was conducted utilizing various greenhouse gas emissions inventory protocol principles and guidelines to consolidate a list of activity data and emission factors. The best available activity data and emission factors were then selected via a Multi-Criteria-Based Decision Making Method named Technique for Order Preference by Similarity to Ideal Solution or modelled using best-engineering estimates. The study estimated total U.S. hydrogen emissions of 0.063 MMTA with emission bounds ranging from 0.02 to 0.11 MMTA. Given the total estimated H2 production capacity of 7.97 MMTA the study estimates a total U.S. hydrogen emission rate for production distribution and storage of 0.79% (0.26%–1.32%). To reduce the uncertainty in the estimated total hydrogen emissions future work should be conducted to measure facility-level hydrogen emission factors across multiple sectors. The inventory framework developed in this study can serve as a living document that can be updated and enhanced as more empirical data is obtained. This study also provides detailed insights regarding key emission or leakage sources and causes from each supply chain stage. The insights and conclusions from this study can provide direction for hydrogen production companies and safety professionals as they develop hydrogen emission mitigation measures and controls.

As global efforts to decarbonize intensify hydrogen produced via renewable electricity has emerged as a pivotal energy vector for a sustainable industrial future. This commentary provides a critical analysis of the current state of the hydrogen economy in Europe detailing the core principles operational mechanisms and industrial status of four primary water electrolysis technologies: alkaline (ALK) proton exchange membrane (PEM) solid oxide (SOEC) and anion exchange membrane (AEM). Furthermore it explores the significant socio-political challenges inherent in producing green hydrogen in non-EU nations for subsequent import into the European market.

With the growing significance of hydrogen in the global energy transition research on its pricing mechanisms has become increasingly crucial. Focusing on hydrogen markets predominantly supplied by electrolytic production this study proposes a nodal marginal hydrogen price decomposition algorithm that explicitly incorporates the time-delay dynamics inherent in hydrogen transmission. A four-dimensional price formation framework is established comprising the energy component network loss component congestion component and time-delay component. To address the nonconvex optimization challenges arising in the market-clearing model an improved second-order cone programming method is introduced. This method effectively reduces computational complexity through the reconstruction of time-coupled constraints and reformulation of the Weymouth equation. On this basis the analytical expression of the nodal marginal hydrogen price is rigorously derived elucidating how transmission dynamics influence each price component. Empirical studies using a modified Belgian 20-node system demonstrate that the proposed pricing mechanism dynamically adapts to load variations with hydrogen prices exhibiting a strong correlation with electricity cost fluctuations. The results validate the efficacy and superiority of the proposed approach in hydrogen energy market applications. This study provides a theoretical foundation for designing efficient and transparent pricing mechanisms in emerging hydrogen markets.

Hybrid renewable energy systems (HRESs) are an effective tool for addressing the challenges of rural electrification in sub-Saharan Africa (SSA). However their viability is limited by the lifespan environmental impacts high costs and inefficiency of conventional energy storage technologies (battery and pumped-hydro). This study examines a hydrogen-based energy storage system combined with photovoltaic (PV) and wind energy for the electrification of Dargalla a village in northern Cameroon. The goal is to meet community and agricultural electricity needs while optimizing the system. The analysis utilized HOMER software to simulate model and optimize the system. The optimal architecture consisted of a 50-kW photovoltaic (PV) array a 10-kW wind turbine a 10-kW fuel cell a 30-kW electrolyser a 25-kg hydrogen tank and a 10-kW converter. The optimised system’s net present cost and cost of energy were assessed at USD 138202 and USD 0.443/kWh respectively. Sensitivity analysis results showed that areas with high wind speeds would be mainly suitable for the proposed system. Moreover with the upcoming decrease in the costs of fuel cells and PV components such systems are expected to become more economically viable in the future leading to the conclusion that integration of hydrogen-based energy storage technology in HRESs in SSA can effectively address the United Nations Sustainable Development Goals (UNSDG) and the historic Paris Climate Agreement (HCA).

The conventional electrolysis is recognized as a mature and promising hydrogen (H2) production technology but there is still a strong need for further performance improvement. In this regard achieving an effective H2 evolution reaction at the cathode requires costly catalysts such as platinum and various catalyst-modified electrode materials. Nevertheless these materials are expensive and involve complex production procedures. Due to an increasing interest in deploying biomaterial-based cathodes as potential alternatives to conventional cathode materials we make the focus of this study on such materials and a graphite-loaded bioelectrode is in this regard synthesized for electrolysis application for effective H2 production. The surface morphology and electrochemical activity of the produced biocathode are characterized. Our results show that the H2 production performance of the system improves with the increasing graphite dosage on the biocathode and with the applied voltage ranging from 2 to 6 V. At improved operating conditions the highest H2 production rate of 1000 ppm (8.18 mg/m3 min) is obtained using a 1.5 g graphite-loaded biocathode at an applied voltage of 6 V. Consequently the produced graphite-loaded biocathode can be a promising option for sustainable and effective H2 production with waste minimization owing to its high conductivity low-cost and good stability.

China is developing renewable energy bases (REBs) in the desert and Gobi regions. However the intermittency of renewable energy and the temporal mismatch between peak renewable generation and peak load demand severely disrupt the power supply reliability of these REBs. Hydrogen storage technology characterized by high energy density and long-term storage capability is an effective method for enhancing the power supply reliability. Therefore this paper proposes a REB planning model in the desert and Gobi regions considering seasonal hydrogen storage introduction as well as electricity-carbon-hydrogen markets trading. Furthermore a combination scenario generation method considering extreme scenario optimization is proposed. Among which the extreme scenarios selected through an iterative selection method based on maximizing scenario divergence contain more incremental information providing data support for the proposed model. Finally the simulation was conducted in the desert and Gobi regions of Yinchuan Ningxia Province China primarily verifying that (1) the REB incorporating hydrogen storage can fully leverage hydrogen storage to achieve seasonal and long-term electricity transfer and utilization. The project has a payback period of 10 years with an internal rate of return of 13.30% and a return on investment of 16.34% thus showing significant development potential. (2) Compared to the typical battery-involved REB the hydrogen-involved energy storage facility achieved a 59.39% annual profit a 10.98% internal rate of return a 14.93% return on investment and a 1.51% improvement in power supply reliability by sacrificing a 52.49% increase in construction cost. (3) Compared to REB planning based only on typical scenarios the power supply reliability of REBs based on the proposed combination scenario generation method improved by 8.58%.