Publications

With the increasing severity of global environmental issues and the pressure from the strict pollutant emission regulations proposed by the International Maritime Or‑ ganization (IMO) the shipping industry is seeking new types of marine power systems that can replace traditional propulsion systems. Marine fuel cells as an emerging energy technology only emit water vapor or a small amount of carbon dioxide during operation and have received widespread attention in recent years. However research on their appli‑ cation in the shipping industry is relatively limited. Therefore this paper collects relevant reports and literature on the use of fuel cells on ships over the past few decades and con‑ ducts a thorough study of typical fuel cell‑powered vessels. It summarizes and proposes current design schemes and optimization measures for marine fuel cell power systems pro‑ viding directions for further improving battery performance reducing carbon emissions and minimizing environmental pollution. Additionally this paper compares and analyzes marine fuel cells with those used in automotive aviation and locomotive applications of‑ fering insights and guidance for the development of marine fuel cells. Although hydrogen fuel cell technology has made significant progress in recent years issues still exist regard‑ ing hydrogen production storage and related safety and standardization concerns. In terms of comprehensive performance and economics it still cannot effectively compete with traditional internal combustion engines. However with the continued rapid devel‑ opment of fuel cell technology marine fuel cells are expected to become a key driver for promoting green shipping and achieving carbon neutrality goals.

In recent years numerous hydrogen-powered rail vehicles have been developed and their deployment within public transport is steadily increasing. To avoid disadvantages compared to diesel vehicles refueling times of 15 min are stated in the industry as target independent of climate zones or vehicle configurations. As refueling time varies with these parameters this work presents the corresponding refueling times and defines optimization potentials. A simulation model was set up and parametrized with a reference vehicle and hydrogen refueling station from the FCH2RAIL project. Measurement data from this station and vehicle were analyzed and compared to simulation results for model validation. The results show that at high ambient temperature pre-cooling reduces refueling time by 71 % and type 4 tanks increase refueling time by 20 % compared to type 3. Overall optimized tank design and thermal management reduce the refueling time for rail vehicles from over 2 h to 15 min.

Ternary I-III-VI quantum dots (QDs) have recently received wide attention in solar energy conversion technologies because of their non-toxicity tunable band gap and composition-dependant optical properties. However their complex non-stoichiometry induces high density of surface traps/defects which significantly affects solar energy conversion efficiencies and long-term stability. This work presents an in-situ growth passivation approach to encapsulate ternary Cu:ZnInSe with ZnSeS alloyed shell (CZISe/ZSeS QDs) as light harvesters for solar-driven photoelectrochemical (PEC) hydrogen (H2) production. The engineered CZISe/ZSeS QDs coupled with TiO2- MWCNTs hybrid photoanode exhibit a high photocurrent density of 13.15 mA/cm2 at 0.8 V vs RHE under 1 sun illumination which is 20.5 % higher than bare CZISe QDs/TiO2 photoanode based device. In addition we observed a 48 % enhancement in the long-term stability with ~88 % current retained after 6000 s. These results indicate that the effective shell passivation has mitigated the surface traps/defects leading to suppressed charge recombination and improved charge transfer efficiency as confirmed by optoelectronic carrier dynamics measurements and theoretical simulations. The findings hold great promise on improving the performance of ternary/multinary eco-friendly colloidal QDs by surface engineering for effective utilization in solar energy conversion technologies.

The paper investigates the potential of co-electrolysis as a viable pathway for hydrogen production and industrial decarbonization expanding on previous studies on water electrolysis. The analysis adopts a general and critical perspective aiming to assess the realistic scope of this technology with regard to current energy and environmental needs. Although co-electrolysis theoretically offers improved efficiency by simultaneously converting H2O and CO2 into syngas the practical advantages are difficult to consolidate. The study highlights that the energetic margins of the process remain relatively narrow and that several key aspects including system irreversibility and the limited availability of CO2 in many contexts significantly constrain its applicability. Despite the growing interest and promising technological developments co-electrolysis still faces substantial challenges before it can be implemented on a larger scale. The findings suggest that its success will depend on targeted integration strategies advanced thermal management and favorable boundary conditions rather than on the intrinsic efficiency of the process alone. However there are specific sectors where assessing the implementation potential of co-electrolysis could be of interest a perspective this paper aims to explore.

This report includes information on European training programmes educational materials and the trends and patterns of research and innovation activity in the hydrogen sector with data of patent registrations and publications. It is based on the information available at the European Hydrogen Observatory (EHO) website (https://observatory.cleanhydrogen.europa.eu/) the leading source of hydrogen data in Europe. The data presented in this report is based on research conducted until the end of August 2025. The training programmes section provides insights into major European training initiatives categorized by location. It allows filtering by type of training focus area and language. It covers a wide range of opportunities such as vocational and professional trainings summer schools and Bachelor's or Master's programmes. The education materials chapter summarizes the publicly accessible educational materials available online. Documents can be searched by educational level by course subject by language or by the year of release. The section referring to research and innovation activity analyses trends and patterns in the hydrogen sector using aggregated datasets of patent registrations and publications by country.

Under the background of “dual-carbon” the development of energy internet is an inevitable trend for China’s low-carbon energy transition. This paper proposes a hydrogen-coupled electrothermal integrated energy system (HCEH-IES) operation mode and optimizes the source-side structure of the system from the level of carbon trading policy combined with low-carbon technology taps the carbon reduction potential and improves the renewable energy consumption rate and system decarbonization level; in addition for the operation optimization problem of this electric–gas–heat integrated energy system a flexible energy system based on electric–gas–heat is proposed. Furthermore to address the operation optimization problem of the HCEH-IES a deep reinforcement learning method based on Soft Actor–Critic (SAC) is proposed. This method can adaptively learn control strategies through interactions between the intelligent agent and the energy system enabling continuous action control of the multi-energy flow system while solving the uncertainties associated with source-load fluctuations from wind power photovoltaics and multi-energy loads. Finally historical data are used to train the intelligent body and compare the scheduling strategies obtained by SAC and DDPG algorithms. The results show that the SAC-based algorithm has better economics is close to the CPLEX day-ahead optimal scheduling method and is more suitable for solving the dynamic optimal scheduling problem of integrated energy systems in real scenarios.

This study investigates the effects of secondary jet-guided combustion on the combustion and emissions of a hydrogen direct-injection engine through numerical simulations. The results show that secondary jet-guided combustion which involves injecting and igniting the hydrogen jet at the end of the compression stroke significantly shortens the delay period improves combustion stability and brings the combustion center closer to the top dead center (TDC) achieving a maximum indicative thermal efficiency (ITE) of 46.55% (λ = 2.4). However this strategy results in higher NOx emissions due to high-temperature combustion. In contrast single and double injections lead to worsened combustion and reduced thermal efficiency under lean-burn conditions but with relatively lower NOx emissions. This study demonstrates that secondary jet-guided combustion can effectively enhance hydrogen engine performance by optimizing mixture stratification and flame propagation providing theoretical support for clean and efficient combustion.

Low carbon hydrogen has a fundamental role to play in not one but two of the UK Government’s core missions. First it can help grow the economy - with thousands of new jobs and opportunities breathing new life into our industrial heartlands. Second it can help the UK become a clean energy superpower by using clean secure energy that we control. Third it can future-proof the UK’s foundational industries delivering decarbonisation and energy security to the hard-to-abate sectors which underpin the UK economy. Hydrogen developers across our membership report growing interest from customers in a wide range of sectors. Whilst current government policy has helped start the hydrogen economy industry wants this to accelerate and become more holistic so that interest is translated into demand allowing the sector to fully develop and the UK to meet its decarbonisation targets. With growing international competition the UK Government should prioritise the growth of hydrogen technology implementation leveraging the nation’s natural geological and geographical advantages. Although £20 billion in private capital investment is estimated to be ready to support the UK Government’s hydrogen ambitions persistent delays and market uncertainty risk this funding being lost to other markets. This report outlines the importance of Driving Demand for offtakers complementing the strong market foundation built from Government’s early hydrogen production focus. For effective policy implementation industry stakeholders have highlighted the importance of finding balance: retaining low-carbon technology optionality alongside certainty and support for investment with the adoption of a clear ‘vision’ and ‘market creation’ supported by a tailored mix of ‘carrots and sticks’ to support the market. From the research conducted by HUK it is clear that the choice of decarbonisation options is not done on a sector-by-sector basis that even within companies the decision-making process is site-by-site. This reflects the sensitivity of numerous factors that will ultimately determine the best solution for their site and re-enforces the view that customers must be allowed the choice of decarbonisation options. Hydrogen will play a significant role in decarbonising some of the hardest to abate sectors of the UK economy complimenting the role of electrification CCUS and other decarbonisation technologies. These sectors represent the hardest and therefore most expensive to decarbonise. However hydrogen also provides an opportunity to deliver significant economic growth through a thriving domestic supply chain and so a holistic approach should be applied.

The paper can be found on their website.

Hydrogen fuel presents a promising pathway for achieving long-term decarbonization in the maritime sector. However its use in diesel engines introduces challenges due to high reactivity leading to increased NOx emissions and combustion instability. The aim of this study is to identify settings so that the investigated engine operates with 60% hydrogen energy fraction at high load through CFD modelling. The model is utilized to simulate a four-stroke 10.5 MW marine engine at 90% load incorporating 60% hydrogen injection by energy at the engine intake port. The CFD model is verified using experimental data from diesel operation of the marine engine and hydrogen operation of a light-duty engine. The engine performance was determined and detailed emissions analysis was conducted including NO NO2 HO2 and OH. The findings indicate a substantial rise in NOx emissions as opposed to diesel operation due to elevated combustion temperatures and increased residence time at elevated temperature of the mixture in-cylinder. The presence of HO2 and OH highlights critical zones of combustion which contribute to operational stability. The novelty of this study is supported by the examination of the high hydrogen energy fraction the advanced emissions analysis and the insights into the emissions–performance trade-offs in hydrogen-fueled dual-fuel marine engines. The results offer guidance for the development of sustainable hydrogen-based marine propulsion systems.

This report identifies the critical research and innovation (R&I) priorities for decarbonising Europe's heavy-duty vehicles based on direct feedback from industry stakeholders. The findings reveal a consensus: battery electric technology is the primary pathway forward with significant stakeholder support for R&I focused on its improvement. While battery electric technology is perceived as more mature hydrogen is considered a complementary solution for the most demanding long-haul routes. Large-scale demonstrations are suggested for de-risking operations and evaluating integration with the transport and energy system. The analysis confirms that achieving TCO parity or better compared to diesel is the most important factor for market uptake. This study provides direct evidence-based guidance for EU transport R&I policy helping to chart the road ahead and orient R&I call programming to meet the ambitious CO₂ emission standards for heavy-duty vehicles.

The decarbonization of energy systems poses significant challenges to energy networks due to the introduction of new energy vectors and changes in the pattern of energy demand. However this is currently an under-researched area. This paper addresses a gap in the literature by drawing on the socio-technological transitions and multi-system interactions literature to explore the views of experts from industry academia and other sectors about the challenges facing UK energy networks and the possible solutions including taking a more wholistic approach to the planning and operation of dierent networks. Using these frameworks we have demonstrated that systems can be deliberately integrated to interact and solve particular system challenges and have identified the nature of these interactions. The empirical results identify areas of consensus and disagreement about the future development of network infrastructure and regulation. They also highlight how government policy responds to the challenges and opportunities presented by the UK climate targets. The findings show widespread agreement that the UK energy system will become more electrified and decentralized as it incorporates more renewable energy. However the role of gaseous fuels in the energy system is more uncertain with some experts seeing a move from natural gas to hydrogen as being key to maintaining the security of supply while others see little or no role for hydrogen. There is also widespread agreement that the regulatory structure should change to address the challenges facing energy networks with much less agreement on whether this could happen quickly enough. Recent developments indicate the UK Government recognizes the need for regulatory change but it is premature to foresee their success in helping networks be a driver of rather than a barrier to a net-zero energy system.

Hydrogen transportation through a new pipeline poses significant economic barriers and blending hydrogen into existing natural gas pipelines offers promising alternative. However hydrogen’s low energy density and potential material compatibility challenges necessitate modifications to existing infrastructure. This study conducts a comprehensive thermo-economic analysis of natural gas and hydrogen mixtures with and without gaseous inhibitors evaluating the impact on thermophysical properties (Wobbe index density viscosity energy density higher and lower heating values) compression power economic feasibility and storage volume requirement. A pipeline transmission model was developed in Aspen HYSYS to assess these properties considering major and minor infrastructure modifications. The findings suggest that the addition of 5% carbon monoxide and 2% ethylene as gaseous inhibitors in maintaining desired properties ensuring compatibility with existing infrastructure and operational processes. The findings also indicate that blending 30% hydrogen increases storage volume by 30–55% while reducing higher and lower heating values by 20–25%. However the addition of 5% carbon monoxide and 2% ethylene improves the pipeline performance and reduces the carbon emissions by 23–26% supporting the transition to low-carbon energy systems. The results suggest that hydrogen blending is viable under specific infrastructure modifications providing critical insights for optimizing pipeline repurposing for sustainable hydrogen transportation.

The UK is set to build on its world leading position of renewables deployment targeting as much as 50GW of offshore wind 27GW of onshore wind and 47GW of solar by 2030 as part of the Clean Power 2030 mission. As we move towards a net zero power system driven by renewables and away from unabated gas the UK will need greater capability to manage periods of low and excess renewable generation. Electrolytic hydrogen is a critical solution to this challenge as the Clean Power Plan and the advice from NESO make clear. Firstly because hydrogen can be stored for long periods of time and in large volumes and because curtailed power can be very low cost. Therefore electrolytic hydrogen can provide cost-effective long duration energy storage which can then be used as a low carbon alternative to natural gas for dispatchable power generation and for a wide variety of uses essential to the full decarbonisation of other sectors including industry and heavy transport. Secondly electrolytic hydrogen can be produced using the renewable power in places such as Scotland that would otherwise go to waste due to the lack of network capacity or demand. Building electrolytic hydrogen production capacity in areas with high renewables and behind grid constraints has a wide range of benefits. Providing electricity demand for the increasing levels of onshore and offshore wind that is in the pipeline in Scotland is going to be critical for renewable deployment while reducing constraint costs paid by consumers. Thus by providing a source of firm power and demand for excess renewable generation electrolytic hydrogen is fundamental to ensuring security of supply in a low carbon power system.

This paper can be found on their website.

Solid oxide fuel cells (SOFCs) have garnered significant attention as a promising technology for clean and efficient power generation due to their ability to utilise renewable fuels such as hydrogen and ammonia. As carbon-free energy carriers hydrogen and ammonia are expected to play a pivotal role in achieving net-zero emissions. However a critical research question remains: how does the electrochemical performance of SOFCs compare when fuelled by hydrogen vs. ammonia and what are the implications for their practical application in power generation? This mini-review paper is premised on the hypothesis that while hydrogen-fuelled SOFCs currently demonstrate superior stability and performance at low and high temperatures ammonia-fuelled SOFCs offer unique advantages such as higher electrical efficiencies and improved fuel utilisation. These benefits make ammonia a viable alternative fuel source for SOFCs particularly at elevated temperatures. To address this the mini-review paper provides a comprehensive comparative analysis of the electrochemical performance of SOFCs under direct hydrogen and ammonia fuels focusing on key parameters such as open-circuit voltage (OCV) power density electrochemical impedance spectroscopy fuel utilisation stability and electrical efficiency. Recent advances in electrode materials electrolytes fabrication techniques and cell structures are also highlighted. Through an extensive literature survey it is found that hydrogen-fuelled SOFCs exhibit higher stability and are less affected by temperature cycling. In contrast ammonia-fuelled SOFCs achieve higher OCVs (by 7%) and power densities (1880 mW/cm2 vs. 1330 mW/cm2 for hydrogen) at 650 °C along with 6% higher electrical efficiency. Despite these advantages ammonia-fuelled SOFCs face challenges such as NOx emissions nitride formation environmental impact and OCV stabilisation which are discussed alongside potential solutions. This mini review aims to provide insights into the future direction of SOFC research emphasising the need for further exploration of ammonia as a sustainable fuel alternative.

This study focuses on enhancing the efficiency of alkaline water electrolysis technology a key process in green hydrogen production by leveraging the synergy of magnetic fields and in situ electrode activation. Optimizing AWE efficiency is essential to meet increasing demands for sustainable energy solutions. In this research nickel mesh electrodes were modified through the application of magnetic fields and the addition of hypo-hyper d-metal (cobalt complexes and molybdenum salt) to the electrolyte. These enhancements improve mass transfer facilitate bubble detachment and create a high-surface-area catalytic layer on the electrodes all of which lead to improved hydrogen evolution rates. The integration of magnetic fields and in situ activation achieved over 35% energy savings offering a cost-effective and scalable pathway for industrial green hydrogen production.

To ensure the safe and reliable operation of hydrogen-blended natural gas (HBNG) pipelines in urban utility tunnels this study conducted a comprehensive CFD simulation of the leakage and diffusion characteristics of HBNG in confined underground environments. Utilizing ANSYS CFD software (2024R1) a three-dimensional physical model of a utility tunnel was developed to investigate the influence of key parameters such as leak sizes (4 mm 6 mm and 8 mm)—selected based on common small-orifice defects in utility tunnel pipelines (e.g. corrosion-induced pinholes and minor mechanical damage) and hydrogen blending ratios (HBR) ranging from 0% to 20%—a range aligned with current global HBNG demonstration projects (e.g. China’s “Medium-Term and Long-Term Plan for Hydrogen Energy Industry Development”) and ISO standards prioritizing 20% as a technically feasible upper limit for existing infrastructure on HBNG diffusion behavior. The study also evaluated the adequacy of current accident ventilation standards. The findings show that as leak orifice size increases the diffusion range of HBNG expands significantly with a 31.5% increase in diffusion distance and an 18.5% reduction in alarm time as the orifice diameter grows from 4 mm to 8 mm. Furthermore hydrogen blending accelerates gas diffusion with each 5% increase in HBR shortening the alarm time by approximately 1.6 s and increasing equilibrium concentrations by 0.4% vol. The current ventilation standard (12 h−1 ) was found to be insufficient to suppress concentrations below the 1% safety threshold when the HBR exceeds 5% or the orifice diameter exceeds 4 mm—thresholds derived from simulations showing that under 12 h−1 ventilation equilibrium concentrations exceed the 1% safety threshold under these conditions. To address these gaps this study proposes an adaptive ventilation strategy that uses variable-frequency drives to adjust ventilation rates in real time based on sensor feedback of gas concentrations ensuring alignment with leakage conditions thereby ensuring enhanced safety. These results provide crucial theoretical insights for the safe design of HBNG pipelines and ventilation optimization in utility tunnels.

As the need for sustainable hydrogen storage solutions increases enhancing the bonding interface between polymer liners and carbon fiber-reinforced polymer (CFRP) in Type IV hydrogen tanks is essential to ensure tank integrity and safety. This study investigates the effect of plasma treatment on polyethylene (PE) and PE/graphene nanoplatelets (GNP) composites to optimize bonding with CFRP simulating the liner-CFRP interface in hydrogen tanks. Initially plasma treatment effects on PE surfaces were assessed focusing on plasma energy and exposure time with key surface modifications characterized and bonding performance being evaluated. Plasma treatment on PE/GNP composites with increasing GNP content was then examined comparing the bonding effectiveness of untreated and plasma-treated samples. Wedge peel tests revealed that plasma treatment significantly enhanced PE-CFRP bonding with optimal conditions at 510 W and 180 s resulting in 212 % and 165 % increases in the wedge peel strength and fracture energy respectively. Plasma-treated PE/GNP composites with 0.75 wt.% GNP achieved a notable bonding enhancement with CFRP showing 528 % and 269 % improvements in strength and fracture energy over untreated neat PE-CFRP samples. These findings offer practical implications for improving the mechanical performance of hydrogen storage tanks contributing to safer and more efficient hydrogen storage systems for a sustainable energy future.

Pressure collapse in sloshing cryogenic liquid hydrogen tanks is a challenge for existing models which often diverge from experimental data. This paper presents a novel lumped-parameter model that overcomes these limitations. Based on a control volume analysis our approach simplifies the complex non-equilibrium physics into a single dimensionless ordinary differential equation governing the liquid’s temperature. We demonstrate this evolution is controlled by one key parameter: the interfacial Nusselt number (). A method for estimating directly from pressure data is also provided. Validated against literature data the model predicts final tank temperatures with deviation of 0.88K (<5% relative error) from measurements thereby explaining the associated pressure collapse. Furthermore our analysis reveals that the Nusselt number varies significantly during a single sloshing event—with calculated values ranging from a peak of 5.81 × 105 down to 7.58 × 103—reflecting the transient nature of the phenomenon.

This review investigates hydrogen production via photocatalysis using ammonia a carbon-free source potentially present in wastewater. Photocatalysis offers low energy requirements and high conversion efficiency compared to electrocatalysis thermocatalysis and plasma catalysis. However challenges such as complex material synthesis low stability spectral inefficiency high costs and integration barriers hinder industrial scalability. The review addresses thermodynamic requirements reaction mechanisms and the role of pH in optimizing photocatalysis. By leveraging ammonia’s potential and advancing photocatalyst development this study provides a framework for scalable sustainable hydrogen production and simultaneous ammonia decomposition paving the way for innovative energy solutions and wastewater management.

Zero-export photovoltaic systems are an option to transition to Smart Grids. They decarbonize the sector without affecting third parties. This paper proposes the analysis of a zero-export PVS with a green hydrogen generation and storage system. This configuration is feasible to apply by any selfgeneration entity; it allows the user to increase their resilience and independence from the electrical network. The technical issue is simplified because the grid supplies no power. The main challenge is finding an economic balance between the savings in electricity billing proportional to the local electricity rate and the complete system’s investment operation and maintenance expenses. This manuscript presents the effects of the power sizing on the efficacy of economic savings in billing (ηSaving ) and the effects of the cost reduction on the levelized cost of energy (LCOE) and a discounted payback period (DPP) based on net present value. In addition this study established an analytical relationship between LCOE and DPP. The designed methodology pro poses to size and selects systems to use and store green hydrogen from the zero-export photo voltaic system. The input data in the case study are obtained experimentally from the Autonomous University of the State of Quintana Roo located on Mexico’s southern border. The maximum power of the load is LPmax = 500 kW and the average power is LPmean = 250 kW; the tariff of the electricity network operator has hourly conditions for a medium voltage demand. A suggested semi-empirical equation allows for determining the efficiency of the fuel cell and electrolyzer as a function of the local operating conditions and the nominal power of the com ponents. The analytical strategy the energy balance equations and the identity functions that delimit the operating conditions are detailed to be generalized to other case studies. The results are obtained by a computer code programmed in C++ language. According to our boundary conditions results show no significant savings generated by the installation of the hydrogen system when the zero-export photovoltaic system Power ≤ LPmax and DPP ≤ 20 years is possible only with LCOE ≤ 0.1 $/kWh. Specifically for the Mexico University case study zero-export photovoltaic system cost must be less than 310 $/kW fuel cell cost less than 395 $/kW and electrolyzer cost less than 460 $/kW.

This study offers a novel techno-economic evaluation of a small hydrogen generation system included into a residential villa in Sharjah. The system is designed to utilize solar energy for hydrogen production using an electrolyzer. The study assesses two scenarios: one lacking a fuel cell and the other incorporating a fuel cell stack for backup power. The initial scenario employs a solar-powered electrolyzer for hydrogen production attaining a competitive levelized cost of energy (LCOE) of $0.1846 per kWh and a hydrogen cost of $4.65 per kg. These data underscore the economic viability of utilizing electrolyzers for hydrogen generation. The system produces around 1230 kg of hydrogen per annum rendering it appropriate for many uses. Nevertheless the original investment expenditure of $73980 necessitates more optimization. The second scenario includes a 10 kW fuel cell for energy autonomy. This scenario has a marginally reduced LCOE of 0.1811 $/kWh and a cumulative net present cost of $72600. The fuel cell runs largely at night proving the efficiency of the downsizing option in decreasing capital expense. The system generates electricity from solar panels (66.1 MWh/year) and the fuel cell (16.9 MWh/year) exhibiting a multi-source power generating technique. The results indicate that scaled-down hydrogen generation systems both with and without fuel cells may offer sustainable and possibly lucrative renewable energy options for household use especially in areas with ample solar resources such as Sharjah.

The transition towards a low-carbon energy system remains a critical challenge for regions heavily dependent on fossil fuels such as Andalusia. This study proposes an energy planning framework based on the Low Emissions Analysis Platform (LEAP) to model alternative scenarios and assess the feasibility of meeting the 2030 and 2050 decarbonisation targets. Three scenarios are evaluated the Tendential Scenario (TS01) the Efficient Scenario (ES01) and the Efficient UJA (EEUJA) Scenario with this last being specifically designed to ensure full compliance with regional energy goals. The results indicate that while the Tendential Scenario falls short in reducing primary energy consumption and greenhouse gas (GHG) emissions the Efficient Scenario achieves significant progress though it is still insufficient to meet renewable energy integration targets. The proposed EEUJA Scenario introduces more ambitious measures including large-scale electrification smart grids energy storage and green hydrogen deployment resulting in a 39.5% reduction in primary energy demand by 2030 and 97% renewable energy penetration by 2050. Furthermore by implementing sector-specific decarbonisation strategies for the industry transport residential and services sectors Andalusia could position itself as a frontrunner in the energy transition while minimising economic and environmental risks. These findings underscore the importance of policy enforcement technological innovation and financial incentives in securing a sustainable energy future. The methodology developed in this study is replicable for other regions aiming for carbon neutrality and energy resilience through strategic planning and scenario analysis.

This study explores the feasibility parameters of a potential investment plan for injecting “green” hydrogen into the existing natural gas supply network in Greece. To this end a preliminary profitability optimization analysis was conducted through key performance indicators such as the cost of hydrogen and the socio-environmental benefit of carbon savings followed by break-even and sensitivity analyses. The identification of the major impact drivers of the assessment was based on the examination of a set of operational scenarios of varying hydrogen and natural gas flow rates. The results show that high natural gas capacities with a 5% hydrogen content by volume are the optimal case in terms of socio-economic viability but the overall profitability is too sensitive to hydrogen pricing rendering it unfeasible without additional motives measures and pricing strategies. The results feed into the main challenge of implementing commercial “green” hydrogen infrastructures in the market in a sustainable and feasible manner.

The transition to sustainable energy is crucial for mitigating climate change impacts. This study addresses this imperative by simulating a green hydrogen supply chain tailored for residential cooking in Oman. The supply chain encompasses solar energy production underground storage pipeline transportation and residential application aiming to curtail greenhouse gas emissions and reduce the levelized cost of hydrogen (LCOH). The simulation results suggest leveraging a robust 7 GW solar plant. Oman achieves an impressive annual production of 9.78 TWh of green hydrogen equivalent to 147808 tonnes of H2 perfectly aligning with the ambitious goals of Oman Vision 2040. The overall LCOH for the green hydrogen supply chain is estimated at a highly competitive 6.826 USD/kg demonstrating cost competitiveness when benchmarked against analogous studies. A sensitivity analysis highlights Oman’s potential for cost-efective investments in green hydrogen infrastructure propelling the nation towards a sustainable energy future. This study not only addresses the pressing issue of reducing carbon emissions in the residential sector but also serves as a model for other regions pursuing sustainable energy transitions. The developed simulation models are publicly accessible at https://hychain.co.uk providing a valuable resource for further research and development in the feld of green hydrogen supply chains.

The increasing demand for carbon-free energy in recent years has positioned hydrogen as a viable option. However its current production remains largely dependent on carbon-emitting sources. In this context natural hydrogen generated through geological processes in the Earth’s subsurface has emerged as a promising alternative. The present study provides the first national-scale assessment of natural dihydrogen (H2) potential in Uruguay by developing a catalog of potential H2-generating rocks identifying prospective exploration areas and proposing H2 systems there. The analysis includes a review of geological and geophysical data from basement rocks and onshore sedimentary basins. Uruguay stands out as a promising region for natural H2 exploration due to the significant presence of potential H2-generating rocks in its basement such as large iron formations (BIFs) radioactive rocks and basic and ultrabasic rocks. Additionally the Norte Basin exhibits potential efficient cap rocks including basalts and dolerites with geological analogies to the Mali field. Indirect evidence of H2 in a free gas phase has been observed in the western Norte Basin. This suggests the presence of a potential H2 system in this area linked to the Arapey Formation basalts (seal) and Mesozoic sandstones (reservoir). Furthermore the proposed H2 system could expand exploration opportunities in northeastern Argentina and southern Brazil given the potential presence of similar play/tramp.