Publications

Under the UK’s carbon neutrality goals for 2050 the Liverpool City Region’s (LCR) strategic positioning with its rich industrial heritage and infrastructure assets such as extensive port facilities and proximity to vast renewable energy resources positions it as a potential leader in the UK’s shift towards a hydrogen economy. Given this the regional hydrogen industry and stakeholders in decarbonisation initiatives intend to undertake a critical review of the opportunities challenges and uncertainties to local hydrogen supply and demand systems to assist in their decision-making. To achieve this goal this study reviews the readiness of the hydrogen supply chain infrastructure within the LCR which highlights four sectors in the hydrogen economy i.e. production storage transportation and utilisation. Subsequently to offer the first-hand data in practice a multi-faceted approach that incorporates a broad array of stakeholders through the Triple Helix (TH) model is adopted. Special attention is given to hydrogen’s role in transforming heavy industry transportation and heating sectors supported by significant local projects like HyNet North West. During a roundtable discussion industry-academia-government stakeholders identify challenges in scaling up infrastructure and assess the economic and technological landscape for hydrogen adoption. To the best of our knowledge this will be the first regional academic endeavour to comprehensively examine the alignment between hydrogen supply and demand theory and practice. Based on a detailed SWOT analysis this study outlines the region’s strengths including established industrial clusters and technological capabilities in manufacturing. It also highlights weaknesses such as the high costs associated with emerging hydrogen technologies technological immaturity and gaps in necessary infrastructure. The opportunities presented by national policy incentives and growing global demand for sustainable energy solutions are considered alongside threats including regulatory complexities and the slow pace of public acceptance. This comprehensive examination not only maps the current landscape but also sets the stage for strategic interventions needed to realise hydrogen’s full potential within the LCR aiming to guide policymakers industry leaders and researchers in their efforts to foster a viable hydrogen economy. Moreover the findings offer valuable insights that can inform the development of hydrogen strategies in other regions and cities.

The paper approaches a computational evaluation of the 100% hydrogen fueled DLR micro-Gas Turbine (mGT) burner F400S.3 through high-fidelity Large Eddy Simulations (LES). Sensitivity analyses on the thermal boundary conditions of the burner walls and the turbulent combustion model were conducted. The experimental OH*-Chemiluminescence distribution was compared with numerical results obtained using the Partially Stirred Reactor (PaSR) and the Extended Flamelet Generated Manifold (ExtFGM) combustion models. The results showed good agreement regarding the flame shape and reactivity prediction when non-adiabatic thermal boundary conditions were applied at the burner walls and the PaSR model was implemented. On the contrary the ExtFGM model exhibited underprediction in flame length and flame lift-off overestimating flame reactivity. Finally after selecting the combustion model that best retrieved the experimental data a pressurized LES was performed on the combustor domain to evaluate its performance under real operating conditions for mGT.

Blue hydrogen production typically achieved by combining steam methane reforming with amine-based CO2 capture is widely considered an economical route towards clean hydrogen. However it suffers from high energy demands associated with solvent regeneration. To overcome this limitation we propose a novel hybrid approach integrating steam methane reforming with membrane-based CO2 capture and O2-enriched combustion. Using process simulations we conducted comprehensive techno-economic and environmental analyses to assess critical parameters affecting the levelised cost of hydrogen (LCOH) and CO2 emissions. Optimal results were obtained at an enriched oxygen level of 30% using vacuum pumping and CO2 capture via feed compression at 11 bar. This configuration achieved an LCOH of ~$1.8/kg H2 and total specific CO2 emissions of ~4.9 kg CO2/kg H2. This aligns closely with conventional blue hydrogen benchmarks with direct emissions significantly reduced to around 1 kg CO2/kg H2. Additionally sensitivity analysis showed robust economic performance despite variations in energy prices. Anticipated advancements in membrane technology could reduce the LCOH further to approximately $1.5/kg H2. Thus this hybrid membrane-based process presents a competitive and sustainable strategy supporting the achievement of the 2050 net-zero emissions goals in hydrogen production.

Methane pyrolysis offers a compelling pathway for low-carbon hydrogen production by avoiding CO2 emissions and enabling distributed deployment in locations with natural gas supply thereby eliminating the need for costly hydrogen transport. While promising the commercial deployment is constrained by the lack of detailed reactor modeling and technoeconomic assessment at small production scales. This study addresses these gaps by designing and modeling a small-scale (1–10 t-H2/day) bubble column reactor employing molten Ni–Bi alloy catalyst for methane pyrolysis. A coupled kinetic–hydrodynamic model was developed to simulate gas holdup bubble behavior and conversion under different operating conditions. The reactor design was integrated into an Aspen Plus simulation of the full process including heat recovery and hydrogen purification. Optimization of pressure temperature and single-pass conversion revealed that operation at 1100 ◦C 15 bar and 70–75 % conversion minimized reactor volume and cost. The lowest levelized cost of hydrogen (LCOH) achieved was $3.06/kg-H2 without sale of carbon significantly lower than green H2 produced from water electrolysis and competitive with blue H2 produced via centralized reforming when transportation costs are included. Sensitivity analysis reveals that carbon byproduct is a key economic lever; carbon sale at $250/t-C reduces LCOH by 25 % while a price of $700/t-C would meet U.S. DOE $1/kg-H₂ target. These results demonstrate the technoeconomic viability of molten metal methane pyrolysis and highlight future opportunities.

The transition to hydrogen as an aviation fuel as outlined in current decarbonization roadmaps is expected to result in the entry into service of hydrogen-powered aircraft in 2035. To achieve this evolution certification regulations are key enablers. Due to the disruptive nature of hydrogen aircraft technologies and their associated hazards it is essential to assess the maturity of the existing regulatory framework for certification to ensure its availability when manufacturers apply for aircraft certification. This paper presents the work conducted under the Clean Aviation CONCERTO project to advance certification readiness by comprehensively identifying gaps in the current European regulations. Generic methodologies were developed for regulatory gap and risk analyses and applied to a hydrogen turbine aircraft with non-propulsive fuel cells as the APU. The gap analysis conducted on certification specifications for large and normal-category airplanes as well as engines confirmed the overall adequacy of many existing requirements. However important gaps exist to appropriately address hydrogen hazards particularly concerning fire and explosion hydrogen storage and fuel systems crashworthiness and occupant survivability. The paper concludes by identifying critical areas for certification and highlighting the need for complementary hydrogen phenomenology data which are key to guiding future research and regulatory efforts for certification readiness maturation.

Achieving global net-zero emissions by 2050 demands integrated and scalable strategies that unite decarbonization technologies across sectors. This review provides a forwardlooking synthesis of carbon capture and storage and hydrogen systems emphasizing their integration through artificial intelligence to enhance operational efficiency reduce system costs and accelerate large-scale deployment. While CCS can mitigate up to 95% of industrial CO2 emissions and hydrogen particularly blue hydrogen offers a versatile low-carbon energy carrier their co-deployment unlocks synergies in infrastructure storage and operational management. Artificial intelligence plays a transformative role in this integration enabling predictive modeling anomaly detection and intelligent control across capture transport and storage networks. Drawing on global case studies (e.g. Petra Nova Northern Lights Fukushima FH2R and H21 North of England) and emerging policy frameworks this study identifies key benefits technical and regulatory challenges and innovation trends. A novel contribution of this review lies in its AI-focused roadmap for integrating CCS and hydrogen systems supported by a detailed analysis of implementation barriers and policy-enabling strategies. By reimagining energy systems through digital optimization and infrastructure synergy this review outlines a resilient blueprint for the transition to a sustainable low-carbon future.

Towards low-carbon buildings with resilient energy performance renewable energy resources and flexible energy assets play key roles in managing the electrical and heat demands. Hydrogen-based systems represent a promising solution through renewable hydrogen production and long-term storage. This paper systematically reviews 35 peer-reviewed studies (1990–2024) on hydrogen integration in buildings focusing on demand-side management (DSM) optimization methods and system performance. The review covers the environmental impacts feasibility and economic viability of integrating different hydrogen systems for supplying energy. Across critical reviews case studies hydrogen supplementary systems achieved CO2 reductions between 12 % and 87 % operational cost decreases of up to 40 % and efficiency gains exceeding 80 %. Payback periods varied widely between 9 and 20 years demonstrating high investment costs. Key gaps include limited field validation economic feasibility and public acceptance of hydrogen homes. One key area for future investigation is optimizing energy flows across production storage and demand particularly in Vehicle-to-Building (V2B) applications. This review paper highlights opportunities especially the potential of hydrogen system in decarbonization of buildings by long-term energy storage barriers and policy needs for implementing hydrogen technologies in grid-connected and remote areas to enhance sustainable and resilient buildings.

Electrifying heat supply in chemical processes offers a strategic pathway to reduce CO2 emissions associated with fossil fuel combustion. This study investigates the retrofit of an existing terrace-wall Steam Methane Reformer (SMR) in an ammonia plant by replacing fuel-fired burners with electric resistance heaters in the radiant section. The proposed e-REFORMER concept is applied to a real-world case producing hydrogen-rich syngas at 29000 Nm3 /h with simulation and energy analysis performed using Aspen HYSYS®. The results show that electric heating reduces total thermal input by 3.78 % lowers direct flue gas CO2 emissions by 91.56 % and improves furnace thermal efficiency from 85.6 % to 88.9 % (+3.3 %). The existing furnace design and convection heat recovery system are largely preserved maintaining process integration and plant operability. While the case study reflects a medium-scale plant the methodology applies to larger facilities and supports integration with decarbonised power grids and Carbon Capture Utilisation and Storage (CCUS) technologies. This work advances current literature by addressing full-system integration of electrification within hydrogen and ammonia production chains offering a viable pathway to improve energy efficiency and reduce industrial emissions.

Hydrogen as a clean energy source has enormous potential in addressing global climate change and energy security challenges. This paper discusses different hydrogen production methodologies (steam methane reforming and water electrolysis) focusing on the electrolysis process as the most promising method for industrial-scale hydrogen generation. The review delved into three main electrolysis methods including alkaline water electrolysis proton exchange membrane electrolysis and anion exchange membrane electrolysis cells. Also the production of hydrogen as a by-product by means of membrane cells and mercury cells. The process of reforming natural gas (mainly methane) using steam is currently the predominant technique comprising approximately 96% of the world’s hydrogen synthesis. However it is carbon intensive and therefore not sustainable over time. Water as a renewable resource carbon-free and rich in hydrogen (11.11%) offers one of the best solutions to replace hydrogen production from fossil fuels by decomposing water. This article highlights the fundamental principles of electrolysis recent membrane studies and operating parameters for hydrogen production. The study also shows the amount of pollutant emissions (g of CO2/g of H2) associated with a hydrogen color attribute. The integration of water electrolysis with renewable energy sources constitutes an efficient and sustainable strategy in the production of green hydrogen minimizing environmental impact and optimizing the use of clean energy resources.

Hydrogen can play a key role as short- and long-term energy storage solution in an energy grid with fluctuating renewable sources. In technologies using hydrogen there is always the risk of unintended leakages due to the low density of gaseous hydrogen. The risk becomes specifically high in confined areas where leaking hydrogen could easily mix with air and form flammable gas mixtures. In the maritime transportation large and congested geometries can be subject to accumulation of hydrogen. A mitigation measure for areas where venting is insufficient or even impossible is the installation of catalytic recombiners. The operational behavior can be described with numerical models which are required to optimize the location and to assess the efficiency of the mitigation solution. In the present study we established an experimental procedure in the REKO-4 facility a 5.5 m³ vessel to determine the recombination rate obtained from a recombiner. Based on the experimental data an engineering correlation was developed to be used for simulations in safety assessments.

Hydrogen blending in natural gas pipelines facilitates renewable energy integration and cost-effective hydrogen transport. Due to hydrogen’s lower density and higher leakage potential compared to natural gas understanding hydrogen concentration distribution is critical. This study employs ANSYS Fluent 2022 R1 with a realizable k-ε model to analyze flow dynamics of hydrogen–methane mixtures in horizontal and undulating pipelines. The effects of hydrogen blending ratios pressure (3–8 MPa) and pipeline geometry were systematically investigated. Results indicate that in horizontal pipelines hydrogen concentrations stabilize near initial values across pressure variations with minimal deviation (maximum increase: 1.6%). In undulating pipelines increased span length of elevated sections reduces maximum hydrogen concentration while maintaining proximity (maximum increase: 0.65%) to initial levels under constant pressure. Monitoring points exhibit concentration fluctuations with changing pipeline parameters though no persistent stratification occurs. However increasing the undulating height elevation difference leads to an increase in the maximum hydrogen concentration at the top of the pipeline rising from 3.74% to 9.98%. The findings provide theoretical insights for safety assessments of hydrogen–natural gas co-transport and practical guidance for pipeline design optimization.

The development of new energy vehicles particularly electric vehicles (EVs) and hydrogen fuel cell vehicles (HFCVs) represents a strategic initiative to address climate change and foster sustainable development. Integrating PV with hydrogen production into hybrid electricity-hydrogen energy stations enhances land and energy efficiency but introduces scheduling challenges due to uncertainties. A multi-time scale scheduling framework which includes day-ahead and intraday optimization is established using fuzzy chance-constrained programming to minimize costs while considering the uncertainties of PV generation and charging/refueling demand. Correspondingly trapezoidal membership function and triangular membership function are used for the fuzzy quantification of day-ahead and intraday predictions of photovoltaic power generation and load demands. The system achieves 29.37% lower carbon emissions and 17.73% reduced annualized costs compared to day-ahead-only scheduling. This is enabled by real-time tracking of PV/load fluctuations and optimized electrolyzer/fuel cell operations maximizing renewable energy utilization. The proposed multi-time scale framework dynamically addresses short-term fluctuations in PV generation and load demand induced by weather variability and temporal dynamics. By characterizing PV/load uncertainties through fuzzy methods it enables formulation of chance-constrained programming models for operational risk quantification. The confidence level – reflecting decision-makers’ reliability expectations – progressively increases with refined temporal resolution balancing economic efficiency and operational reliability.

According to the international standard ISO 14687:2019 for hydrogen fuel quality the maximum allowable concentration of water in hydrogen for use in refueling stations and storage systems must not exceed 5 µmol/mol. Therefore an adsorption purification process following the electrolyzer is necessary. This study numerically investigates the adsorption of water and the corresponding water loading on zeolite 13X BFK based on the mass flows entering the adsorption column from three 5 MW electrolyzers coupled to a 15 MW offshore wind turbine. As the mass flow is influenced by wind speed a direct comparison between realistic wind speeds and adsorption loading is presented. The presented numerical discretization of the model also accounts for perturbations in wind speed and consequently mass flows. In addition adsorption isobars were measured for water on zeolite 13X BFK within the required pressure and temperature range. The measured data was utilized to fit parameters to the Langmuir–Freundlich isotherm.

The growing demand for low-emission urban freight has intensified efficiency challenges in lastmile delivery especially in dense city centres. This study assesses hydrogen-powered cargo bikes as a scalable zero-emission alternative to fossil fuel vans and battery-electric cargo bikes. Using real-world logistics data from Rome we apply simulation models including Monte Carlo cost analysis Artificial Intelligence driven routing K-means station placement and fleet scaling. Results show hydrogen bikes deliver 15% more parcels daily than electric counterparts reduce refuelling detours by 31.4% and lower per-trip fuel use by 32%. They can cut up to 120 metric tons of CO2 annually per 100-bike fleet. While battery-electric cargo bikes remain optimal for short trips hydrogen bikes offer superior uptime range and rapid refuelling—ideal for highfrequency mid-distance logistics. Under supportive pricing and infrastructure hydrogen cargo bikes represent a resilient and sustainable solution for decarbonizing last-mile delivery in city areas.

Life Cycle Assessments (LCAs) are predominantly conducted using a static approach which aggregates emissions over time without considering emissions timing. Additionally LCAs often assume biogenic carbon neutrality neglecting site-specific forest carbon fluxes and temporal trade-offs. This study applies both static and dynamic LCA and incorporates biogenic carbon to evaluate the climate change impact of hydrogen production. It focuses on gasification of eucalyptus woodchips cultivated on former marginal grasslands (BIO system) which avoids competition with land used for food production. A case study is presented in western Andalusia (Spain) with the aim to replace hydrogen produced via the conventional steam methane reforming (SMR) pathway (BAU system) at La Rabida ´ refinery. The CO2FIX model was used to simulate biogenic carbon fluxes providing insights into carbon sequestration dynamics and it was found that the inclusion of biogenic carbon flows from eucalyptus plantations dramatically reduced CO₂ equivalent emissions (176 % in the static approach and 369 % in the dynamic approach) primarily due to soil and belowground biomass carbon sequestration. The dynamic LCA showed significantly lower CO₂ emissions than the static LCA (106 % reduction) shifting emissions from − 1.79 kg CO₂/kg H₂ in the static approach to − 3.69 kg CO₂/kg H₂ in the dynamic approach. These findings highlight the need to integrate emission dynamics and biogenic carbon flows into LCA methodologies to support informed decision-making and the development of more effective environmental policies.

The escalating global demand for electricity coupled with environmental concerns and economic considerations has driven the exploration of alternative energy sources creating competition for land with other sectors. A comprehensive analysis of a 10 MW floating photovoltaic (FPV) system deployed across different Köppen climate zones along with techno-economic analysis involves evaluating technical efficiency and economic viability. Technical parameters are assessed using PVsyst simulation and HOMER Pro. While economic analysis considers return on investment net present value internal rate of return and payback period. Results indicate that temperate and dry zones exhibit significant electricity generation potential from an FPV. The study outlines the payback period with the lowest being 5.7 years emphasizing the system’s environmental benefits by reducing water loss in the form of evaporation. The system is further integrated with hydrogen generation while estimating the number of cars that can be refueled at each location with the highest amount of hydrogen production being 292817 kg/year refueling more than 100 cars per day. This leads to an LCOH of GBP 2.84/kg for 20 years. Additionally the comparison across different Koppen climate zones suggests that even with the high soiling losses dry climate has substantial potential; producing up to 18829587 kWh/year of electricity and 292817 kg/year of hydrogen. However factors such as high inflation can reduce the return on investment to as low as 13.8%. The integration of FPV with hydropower plants is suggested for enhanced power generation reaffirming its potential to contribute to a sustainable energy future while addressing the UN’s SDG7 SDG9 SDG13 and SDG15.

The transition to decarbonized energy systems positions hydrogen as a critical vector for achieving climate neutrality yet its large-scale transportation and storage remain key challenges. This study presents a comprehensive life cycle assessment (LCA) and economic analysis of large-scale H2 supply chains evaluating the liquid organic hydrogen carrier (LOHC) system based on benzyltoluene/perhydro-benzyltoluene (H0-BT/H12-BT) against conventional technologies: compressed gaseous hydrogen (CGH2) liquid hydrogen (LH2) and liquid ammonia (LNH3). The analysis includes multiple H2 transportation scenarios across Europe considering the steps: conditioning sea transportation post-processing and land distribution by truck or pipeline. Environmentally LOHC currently faces higher environmental impacts than CGH2 driven by energy-intensive dehydrogenation process. Truck-based distribution further amplifies impacts particularly over long distances while pipeline-based distribution significantly reduces the environmental burdens where infrastructure exists. Sensitivity analysis reveals that using H2 for dehydrogenation heat lowers process-level impacts but increases overall supply chain impacts questioning its net environmental benefit. Economically LOHC remains competitive despite high dehydrogenation costs benefiting from low sea transportation expenses compatibility with existing fossil fuel infrastructure and potential for future CAPEX and OPEX improvements. While CGH2 outperforms LH2 and LNH3 avoiding energy-intensive liquefaction and cracking its storage requirements add considerable costs. For land distribution LOHC trucks are optimal at lower capacities whereas repurposed natural gas pipelines favour CGH2 at higher scale reducing costs by up to 84 %. Despite current trade-offs the scalability flexibility and synergies with existing infrastructure position LOHC as a promising solution for long-distance H2 transport contingent on technological maturation to mitigate dehydrogenation impacts.

Creating a hydrogen market in Africa is a great opportunity to assist in the promotion of sustainable energy solutions and economic growth. This article addresses the legislation and regulations that need to be developed to facilitate growth in the hydrogen market and allow local green hydrogen offtake across the continent. By reviewing current policy and strategy within particular African countries and best practices globally from key hydrogen economies the review establishes compelling issues challenges and opportunities unique to Africa. The study identifies the immense potential in Africa for renewable energy and in particular for solar and wind as the foundation for the production of green hydrogen. It examines how effective policy frameworks can establish a vibrant hydrogen economy by bridging infrastructural gaps cost hurdles and regulatory barriers. The paper also addresses how local offtake contracts for green hydrogen can be used to stimulate economic diversification energy security and sustainable development. Policy advice is provided to assist African authorities and stakeholders in the deployment of enabling regulatory frameworks and the mobilization of funds. The paper contributes to global hydrogen energy discussions by introducing Africa as an eligible stakeholder in the emerging hydrogen economy and outlining prospects for its inclusion into regional and global energy supply chains.

This study explores the safety problems of hydrogen leakage and explosion in hydrogen fuel cell buses through Computational Fluid Dynamics simulations. The research investigates the diffusion behavior of hydrogen in the passenger cabin depending on the leakage position and flow rates identifying a stratified constant-concentration layer formed at the top of the cabin. Leakage near the rear wall of the vehicle provided the highest hydrogen concentration while at higher flow rates the diffusive process accelerated the spreading of flammable hydrogen concentrations. Hydrogen ignition simulations showed a fast internal pressure increase and secondary explosions outside the vehicle. Thermal hazards in the cases were higher than overpressure. The research’s additional analysis of ignition timing and source location shows that overpressure peaked initially with delayed ignition but declined afterward while rear-ignited flames exhibited the farthest high-temperature hazard range at 10.88 m. These findings are fundamental for giving insight into hydrogen behavior in confined spaces and thus guiding risk assessment and emergency response planning for the development of safety protocols in hydrogen fuel cell buses contributing to the safer implementation of hydrogen energy in public transportation.

Natural hydrogen is generated via serpentinization radiolysis and organic metagenesis in geological settings. After expulsion from the source and along its upward migration path the free gas may encounter hydratebearing sediments. To simulate this natural scenario CH4 hydrate and CH4 + C3H8 hydrate were synthesized at 5.0 MPa and exposed to a hydrogen-containing gas mixture. In-situ Raman spectroscopic measurements demonstrated the incorporation of H2 molecules into the hydrate phase even at a partial pressure of 0.5 MPa. Exsitu Raman spectroscopic characterization of hydrates formed from a CH4 + H2 gas mixture at 5.0 MPa confirmed the H2 inclusion within the large cavities of structure I. The results show that the interactions between H2 and the natural gas hydrate phase range from the incorporation of H2 molecules into the hydrate phase to the rapid dissociation of the gas hydrate depending on thermodynamic conditions and H2 concentration in the coexisting gas phase.

Infrastructure projects can act as niches for innovation development contribute to strategic goals of network owners and drive broader systemic transitions. However limited research has examined how sustainability transitions are shaped through narratives and counternarratives around infrastructure projects. Using a case study of the port of Rotterdam we analyze how three embedded projects - Maasvlakte 2 RDM Campus and the Hydrogen Pipeline - reflected and shaped evolving narratives and counter-narratives over a 20-year sustainability transition. Grounded in the Multi-Level Perspective (MLP) the study demonstrates how an infrastructure owner like the Port of Rotterdam Authority (PoRA) strategically mobilized narrative framing to reshape existing regimes over time. The study contributes to the debate on project management and transition studies by highlighting how infrastructure project owners respond to transition-related tensions by shaping defending and adapting project narratives over time thereby influencing sustainability trajectories.

In order to minimize emissions of the aerospace sector and thus its impact on the climate several novel concepts of propulsion systems for aircraft are being developed. Many of these concepts do not use an energy source based on the combustion of hydrocarbons but other means of energy generation and storage like hydrogen fuel cells and corresponding hydrogen storage systems. The use of hydrogen as a primary energy carrier in aircraft poses novel and different hazards when compared to conventional propulsion and fuel storage systems. The study described in the present paper identifies analyzes and evaluates failure conditions and corresponding hazards that are associated with the electrified propulsion systems. Mitigation strategies to prevent failures to occur or decrease their severity are recommended. The effects of the assessed failures on aircraft crew and occupants are classified as catastrophic hazardous or major as defined in the according Certification Specifications. Failure Conditions occurring at the aircraft system and subsystem levels are considered and their effect on the aircraft and propulsion system is assessed. The hazards identified mostly emerge due to the properties of the gaseous or liquid hydrogen. They include the flammability of gaseous hydrogen and the very low temperatures of cryogenic liquid hydrogen as well as the installation of high voltage power infrastructure and high capacity heat exchangers.

Hydrogen is increasingly recognised as a potential critical energy carrier in decarbonising global energy systems. Australia is positioning itself as a potential leader in offshore renewable hydrogen production by leveraging existing liquified natural gas export infrastructure activating its abundant renewable energy resources and harnessing its extensive offshore marine acreage. Despite this there is limited research on the techno-economic and regulatory pathways for offshore hydrogen development in Australia as an enabler of its net zero manufacturing and export ambitions. This study offers a multidisciplinary assessment and review of Australia’s offshore renewable hydrogen potential. It aims to examine the technical legal and economic challenges and opportunities to enable and adapt the existing Australian offshore electricity regulatory regime and enable policy to facilitate future renewable offshore hydrogen licensing and production. Overall the findings provide practical insights for advancing Australia’s offshore hydrogen transition including technical innovations needed to scale offshore wind development. The study demonstrates how a specific offshore hydrogen licensing framework could reduce legal uncertainties to create economies of scale and reduce hydrogen investment risk to unlock the full potential of developing offshore renewable hydrogen projects.

This paper provides authors’ perspective on the current advances and challenges in utilising polymers and composites in hydrogen economy. It has originated from ‘Polymers and Composites for Hydrogen Economy’ symposium organised in March 2025 at the University of Warwick. This paper presents views from the event and thus provides a perspective from academia and industry on the ongoing advances and challenges for those materials in hydrogen applications.

The utilisation of renewable energy sources for hydrogen production is increasingly vital for ensuring the long-term sustainability of global energy systems. Currently the Sultanate of Oman is actively integrating renewable energy particularly through the deployment of solar photovoltaic (PV) systems as part of its ambitious targets for the forthcoming decades. Also Oman has target to achieve 1 million tonnes of green-H2 production annually. Leveraging Oman's abundant solar resources to produce green hydrogen and promote the clean transportation industry could significantly boost the country's sustainable energy sector. This paper outlines a standalone bifacial solar-powered system designed for large-scale green hydrogen (H2) production and storage to operate both a hydrogen refuelling station and an electric vehicle charging station in Sohar Oman. Using HOMER software three scenarios: PV/Hydrogen/Battery PV/Hydrogen PV/Battery systems were compared from a techno-economic perspective. Also the night-time operation (Battery/Hydrogen) was investigated. Varying cost of electricity were obtained depending on the system from $3.91/kWh to $0.0000565kWh while the bifacial PV/Hydrogen/Battery system emerged as the most efficient option boasting a unit cost of electricity (COE) of $3.91/kWh and a levelized cost of hydrogen (LCOH) value of $6.63/kg with net present cost 199M. This system aligns well with Oman's 2030 objectives with the capacity to generate 1 million tonnes of green-H2 annually. Additionally the findings show that the surplus electricity from the system could potentially cover over 30% of Oman's total energy consumption with zero harmful emissions. The implementation of this system promises to enhance Oman's economic and transportation industries by promoting the adoption of electric and fuel cell vehicles while reducing reliance on traditional energy sources.