Publications

This study presents the development and implementation of an AI-driven control system for dynamic regulation of hydrogen blending in natural gas networks. Leveraging supervised machine learning techniques a Random Forest Classifier was trained to accurately identify the origin of gas blends based on compositional fingerprints achieving rapid inference suitable for real-time applications. Concurrently a Random Forest Regression model was developed to estimate the optimal hydrogen flow rate required to meet a user-defined higher calorific value target demonstrating exceptional predictive accuracy with a mean absolute error of 0.0091 Nm3 and a coefficient of determination (R2 ) of 0.9992 on test data. The integrated system deployed via a Streamlit-based graphical interface provides continuous real-time adjustments of gas composition alongside detailed physicochemical property estimation and emission metrics. Validation through comparative analysis of predicted versus actual hydrogen flow rates confirms the robustness and generalizability of the approach under both simulated and operational conditions. The proposed framework enhances operational transparency and economic efficiency by enabling adaptive blending control and automatic source identification thereby facilitating optimized fuel quality management and compliance with industrial standards. This work contributes to advancing smart combustion technologies and supports the sustainable integration of renewable hydrogen in existing gas infrastructures.

Green hydrogen is critical for achieving net-zero emissions with water electrolysis offering a CO2-free solution. This study provides a comprehensive comparative financial and economic assessment of a hybrid PV/wind hydrogen production system using three types of electrolysers including Alkaline Electrolyser (AEL) Proton Exchange Membrane Electrolyser (PEMEL) and Solid Oxide Electrolyser (SOEL). Key performance metrics such as net present value (NPV) Internal Rate of Return (IRR) revenues Earnings Before Interest Tax Depreciation and Amortization (EBITDA) Earning Before Taxes (EBT) Debt Service Coverage Ratio (DSCR) and levelized cost of Hydrogen (LCOH) are evaluated to identify the most cost-effective option. The findings reveal that AEL is the most economical solution achieving a higher NPV (503374 k€) and IRR (16.94 % for project IRR) though PEMEL and SOEL remain competitive. Other metrics such as DSCR show that the hydrogen project generates 30 % more cash flow than is required to cover its debt service. Additionally the results of the LCOH analysis demonstrate that a hybrid plant consisting of 10 % PV and 90 % wind is more cost-effective in the studied region than both solar-based or wind-based hydrogen production plants. AEL and PEMEL are approximately 7–6 €/kg less expensive than SOEL but this gap is expected to be narrowed by 2030. The hybrid renewable energy project reduces CO2 emissions by 6786.6 Mt over its lifetime. These findings guide policymakers and investors toward scalable cost-effective green hydrogen deployment emphasizing the synergy of hybrid renewables and mature electrolysis technologies.

The main motivation for this paper was the lack of studies and comparative analyses on the new generation of alternative fuels in the marine sector such as methane methanol ammonia and hydrogen. Firstly a review of international legislation and the status of these new fuels was carried out highlighting the current situation and the different existing alternatives for reducing greenhouse gas (GHG) emissions. In addition the status and evolution of the current order book for ships since the beginning of this decade were used for this analysis. Secondly each fuel and its impact on the geometry and operation of the engine were evaluated in a theoretical engine called MW-1. Lastly an economic analysis of the current situation of each fuel and its availability in the sector was carried out in order to select using the indicated methodology the most viable fuel at present to replace traditional fuels with a view to the decarbonization set for 2050.

The transition to Hydrogen Fuel Cell Vehicles (HFCVs) is recognized for its potential to eliminate tailpipe emissions and promote cleaner urban mobility. This study examines the impact of varying HFCV adoption rates as well as the number and location of hydrogen refueling stations on emissions driving behavior and traffic dynamics in urban environments. A hybrid methodology combining statistical analyses and machine learning techniques was used to simulate all scenarios in the city of Linz Austria. The simulation results indicate that the configuration of hydrogen refueling infrastructure along with smoother driving patterns can contribute to reduced congestion and significantly lower CO2 emissions in high-traffic urban areas. Increasing the proportion of HFCVs was also found to be beneficial due to their use of electric motors powered by hydrogen fuel cells which offer features such as instant torque regenerative braking and responsive acceleration. Although these features are not unique to HFCVs they contributed to a slight shift in driving behavior toward smoother and more energy-efficient patterns. This change occurred due to improved acceleration and deceleration capabilities which reduced the need for harsh maneuvers and supported steadier driving. However the overall effect is highly dependent on traffic conditions and real-world driving behavior. Furthermore marginal and contextdependent improvements in traffic flow were observed in certain areas. These were attributed to HFCVs’ responsive acceleration which might assist in smoother merging and reduce stop-and-go conditions. These findings provide valuable insights for transportation planners and policymakers aiming to promote sustainable urban development.

The publication presents methods and pre-test results of a stand for testing CHSS in terms of resistance to open fire. The basis for the conducted research is the applicable provisions contained in the UN/ECE Regulation R134. The study includes an overview of contemporary solutions for hydrogen storage systems in high-pressure tanks in means of transport. Development in this area is a response to the challenge of reducing global carbon dioxide emissions and limiting the emissions of toxic compounds. The variety of storage systems used is driven by constraints including energy demand and available space. New tank designs and conducted tests allow for an improvement in systems in terms of their functionality and safety. Today the advancement of modern technologies for producing high-pressure tanks allows for the use of working pressures up to 70 MPa. The main goal of the presented research is to present the requirements and research methodology verifying the tank structure and the security systems used in open-fire conditions. These tests are the final stage of the approval process for individual pressure vessels or complete hydrogen storage systems. Their essence is to eliminate the occurrence of an explosion in the event of a fire.

Buildings are major energy consumers accounting for a significant portion of global energy consumption. Integrating hydrogen systems electrolyzers accumulation and fuel cells is proposed as a clean and efficient energy alternative to mitigate this impact and move toward a more sustainable future. This paper presents a systematic procedure for incorporating these technologies into buildings considering building engineers and stakeholders. First an in-depth analysis of buildings’ main energy consumption parameters is conducted identifying areas of energy need with the most significant optimization potential. Next a detailed review of the various opportunities for hydrogen applications in buildings is conducted evaluating their advantages and limitations. Performing a scientific review to find and understand the requirements of building engineers and the stakeholders has given notions of integration that emphasize the needs. As a result of the review process and identifying the needs to integrate hydrogen into buildings a flowchart is proposed to facilitate decision-making regarding integrating hydrogen systems into buildings. This flowchart is accompanied by a matrix of variables that considers the defined requirements allowing for combining the most suitable solution for each case. The results of this research contribute to advancing the adoption of hydrogen technologies in buildings thus promoting the transition to a more sustainable and resilient energy model.

This study explores the potential of hydrogen-enriched internal combustion engines (H2ICEs) as a sustainable alternative to fossil fuels. Hydrogen offers advantages such as high combustion efficiency and zero carbon emissions yet challenges related to NOx formation storage and specialized modifications persist. Machine learning (ML) techniques including artificial neural networks (ANNs) and XGBoost demonstrate strong predictive capabilities in optimizing engine performance and emissions. However concerns regarding overfitting and data representativeness must be addressed. Integrating AI-driven strategies into electronic control units (ECUs) can facilitate real-time optimization. Future research should focus on infrastructure improvements hybrid energy solutions and policy support. The synergy between hydrogen fuel and ML optimization has the potential to revolutionize internal combustion engine technology for a cleaner and more efficient future.

This study examines the economic and regulatory implications of the development of Germany’s hydrogen core network. Using a mathematical-economic model of the amortization account and a reproduction of the network topology based on the German transmission system operators’ draft proposals the analysis evaluates the impact of delaying the network expansion with completion postponed from 2032 to 2037. The proposed phased approach prioritizes geographically clustered regions and ensures sufficient demand alignment during each expansion stage. The results demonstrate that strategic adjustments to the network size and timing significantly enhance cost-efficiency. In the initially reduced and delayed scenario uncapped network tariffs remain below €15/ kWh/h/a suggesting that under specific conditions the amortization account may become redundant while maintaining supply security and supporting the market ramp-up of hydrogen. These findings highlight the potential for demand-driven phased hydrogen infrastructure development to reduce financial burdens and foster a sustainable transition to a hydrogen-based energy system.

Hydrogen is widely recognized as a key enabler of the clean energy transition but the lack of safe efficient and scalable storage technologies continues to hinder its broad deployment. Conventional hydrogen storage approaches such as compressed hydrogen storage cryo-compressed hydrogen storage and liquid hydrogen storage face limitations including high energy consumption elevated cost weight and safety concerns. In contrast solid-state hydrogen storage using carbon-based adsorbents has gained growing attention due to their chemical tunability low cost and potential for modular integration into energy systems. This review provides a comprehensive evaluation of hydrogen storage using carbon-based materials covering fundamental adsorption mechanisms classical materials emerging architectures and recent advances in computationally AI-guided material design. We first discuss the physicochemical principles driving hydrogen physisorption chemisorption Kubas interaction and spillover effects on carbon surfaces. Classical adsorbents such as activated carbon carbon nanotubes graphene carbon dots and biochar are evaluated in terms of pore structure dopant effects and uptake capacity. The review then highlights recent progress in advanced carbon architectures such as MXenes three-dimensional architectures and 3D-printed carbon platforms with emphasis on their gravimetric and volumetric performance under practical conditions. Importantly this review introduces a forward-looking perspective on the application of artificial intelligence and machine learning tools for data-driven sorbent design. These methods enable high-throughput screening of materials prediction of performance metrics and identification of structure– property relationships. By combining experimental insights with computational advances carbon-based hydrogen storage platforms are expected to play a pivotal role in the next generation of energy storage systems. The paper concludes with a discussion on remaining challenges utilization scenarios and the need for interdisciplinary efforts to realize practical applications.

The transition to 100% renewable energy systems is critical for achieving global sustainability and reducing dependence on fossil fuels. Island power systems due to their geographical isolation limited interconnectivity and reliance on imported fuels face unique challenges in this transition. These systems’ vulnerability to supply–demand imbalances voltage instability and frequency deviations necessitates tailored strategies for achieving grid stability. This study conducts a systematic review of the technical and operational challenges associated with transitioning island energy systems to fully renewable generation following the Preferred Reporting Items for Systematic Reviews and MetaAnalyses (PRISMA) methodology. Out of 991 identified studies 81 high-quality articles were selected focusing on key aspects such as grid stability energy storage technologies and advanced control strategies. The review highlights the importance of energy storage solutions like battery energy storage systems hydrogen storage pumped hydro storage and flywheels in enhancing grid resilience and supporting frequency and voltage regulation. Advanced control strategies including grid-forming and grid-following inverters as well as digital twins and predictive analytics emerged as effective in maintaining grid efficiency. Real-world case studies from islands such as El Hierro Hawai’i and Nusa Penida illustrate successful strategies and best practices emphasizing the role of supportive policies and community engagement. While the findings demonstrate that fully renewable island systems are technically and economically feasible challenges remain including regulatory financial and policy barriers.

Biogas is a crucial renewable energy source for green hydrogen (H2) production reducing greenhouse gas emissions and serving as a carbon-free energy carrier with higher specific energy than traditional fuels. Currently methane reforming dominates H2 production to meet growing global demand with biogas/landfill gas (LFG) reform offering a promising alternative. This study provides a comprehensive simulation-based evaluation of Steam Methane Reforming (SMR) and Dry Methane Reforming (DMR) of biogas/LFG using Aspen Plus. Simulations were conducted under varying operating conditions including steam-to-carbon (S/C) for SMR and steam-to-carbon monoxide (S/CO) ratios for DMR reforming temperatures pressures and LFG compositions to optimize H2 yield and process efficiency. The comparative study showed that SMR attains higher specific H2 yields (0.14–0.19 kgH2/Nm3 ) with specific energy consumption between 0.048 and 0.075 MWh/kg of H2 especially at increased S/C ratios. DMR produces less H2 than SMR (0.104–0.136 kg H2/Nm3 ) and requires higher energy inputs (0.072–0.079 MWh/kg H2) making it less efficient. Both processes require an additional 1.4–2.1 Nm3 of biogas/LFG per Nm3 of feed for energy. These findings provide key insights for improving biogas-based H2 production for sustainable energy with future work focusing on techno–economic and environmental assessments to evaluate its feasibility scalability and industrial application.

Energy transformation is one of the processes shaping contemporary urban transport systems with public transport being the subject of initiatives designed to enhance its attractiveness and transport utility including electromobility. This article presents a case study for a metropolitan conurbation—the GZM Metropolis in Poland—considering the economic efficiency of implementing buses with conventional diesel engines electric buses (battery electric buses) and hydrogen fuel cell-powered buses. The analysis is based on the cost-benefit analysis (CBA) method using the discounted cash flow (DCF) method.

The turbocharging of hydrogen fuel cell systems (FCSs) has recently become a prominent research area aiming to improve FCS efficiency to help decarbonise the energy and transport sectors. This work compares the performance of an electrically assisted variable-geometry turbocharger (VGT) with a fixed-geometry turbocharger (FGT) by optimising both the sizing of the components and their operating points ensuring both designs are compared at their respective peak performance. A MATLAB-Simulink reducedorder model is used first to identify the most efficient components that match the fuel cell air path requirements. Maps representing the compressor and turbines are then evaluated in a 1D flow model to optimise cathode pressure and stoichiometry operating targets for net system efficiency using an accelerated genetic algorithm (A-GA). Good agreement was observed between the two models’ trends with a less than 10.5% difference between their normalised e-motor power across all operating points. Under optimised conditions the VGT showed a less than 0.25% increase in fuel cell system efficiency compared to the use of an FGT. However a sensitivity study demonstrates significantly lower sensitivity when operating at non-ideal flows and pressures for the VGT when compared to the FGT suggesting that VGTs may provide a higher level of tolerance under variable environmental conditions such as ambient temperature humidity and transient loading. Overall it is concluded that the efficiency benefits of VGT are marginal and therefore not necessarily significant enough to justify the additional cost and complexity that they introduce.

Increasing renewable energy technology penetration into electrical grids to meet net zero CO2 emission targets is a key challenge in terms of intermittency; one solution is the provision of sufficient energy storage. In the current study we considered future projections of electrical demand and renewable energy (in 2042) for the Southwest Interconnected System grid in Western Australia. Required energy storage considered is a mixture of battery energy storage systems and underground hydrogen storage in a depleted gas reservoir. The Southwest Interconnected System serves as an excellent case study given that it is a comparatively large isolated grid with substantial potential access to renewable energy resources as well as potential underground hydrogen storage sites. This work utilised a dynamic energy model that summates the wind and solar energy resources on an hourly basis. Excess energy utilised battery energy storage systems capacity first followed by underground hydrogen storage. The relative size of the renewables and the storage options is then optimised in terms of minimising wholesale energy production costs. This unique optimisation analysis across the full integrated system clearly indicated that both battery energy storage systems and underground hydrogen storage are required; underground hydrogen storage is predominately necessary to meet seasonal unmet energy demand that amounts to approximately 6% of total demand. Underground hydrogen storage costs were dominated by the required electrolyser requirements. The optimised levelised cost of electricity was found to be US$106/MWh which is approximately 45% larger than current wholesale electricity prices.

Hydrogen is considered a clean and efficient energy carrier crucial for shapingthe net-zero future. Large-scale production transportation storage and use of greenhydrogen are expected to be undertaken in the coming decades. As the smallest element inthe universe however hydrogen can adsorb on diffuse into and interact with many metallicmaterials degrading their mechanical properties. This multifaceted phenomenon isgenerically categorized as hydrogen embrittlement (HE). HE is one of the most complexmaterial problems that arises as an outcome of the intricate interplay across specific spatialand temporal scales between the mechanical driving force and the material resistancefingerprinted by the microstructures and subsequently weakened by the presence of hydrogen. Based on recent developments in thefield as well as our collective understanding this Review is devoted to treating HE as a whole and providing a constructive andsystematic discussion on hydrogen entry diffusion trapping hydrogen−microstructure interaction mechanisms and consequencesof HE in steels nickel alloys and aluminum alloys used for energy transport and storage. HE in emerging material systems such ashigh entropy alloys and additively manufactured materials is also discussed. Priority has been particularly given to these lessunderstood aspects. Combining perspectives of materials chemistry materials science mechanics and artificial intelligence thisReview aspires to present a comprehensive and impartial viewpoint on the existing knowledge and conclude with our forecasts ofvarious paths forward meant to fuel the exploration of future research regarding hydrogen-induced material challenges.

Liquid hydrogen (LH2) is a promising energy carrier to decrease the climate impact of aviation. However the inevitable formation of hydrogen boil-off gas (BOG) is a main drawback of LH2. As the venting of BOG reduces the overall efficiency and implies a safety risk at the airport means for capturing and re-using should be implemented. Metal hydrides (MHs) offer promising approaches for BOG recovery as they can directly absorb the BOG at ambient pressures and temperatures. Hence this study elaborates a design concept for such an MH-based BOG recovery system at hydrogen-ready airports. The conceptual design involves the following process steps: identify the requirements establish a functional structure determine working principles and combine the working principles to generate a promising solution.

Driven by the current round of technological revolution and industrial transformation and based on a consensus among countries around the world the world’s energy landscape is undergoing profound adjustments to promote a transition to clean low-carbon energy in order to cope with global climate change. As a clean and carbon-free secondary energy source hydrogen energy is an important component of the energy strategy in various countries. Fuel cell technology is also of great importance in directing the current global energy technology revolution. China has clarified its sustainable energy goals: to peak its carbon dioxide emissions [1] and achieve carbon neutrality [2]. With thorough development of technology and the industry hydrogen energy will play a significant role in achieving these goals.

Transport and storage of hydrogen as a liquid (LH2) is being widely investigated as a solution for scaling up the supply infrastructure and addressing the growth of hydrogen demand worldwide. While there is a relatively wellestablished knowledge and understanding of hazards and associated risks for gaseous hydrogen at ambient temperature several knowledge gaps are yet open regarding the behaviour in incident scenarios of cryogenic hydrogen including LH2. This paper aims at presenting the models and tools that can be used to close relevant knowledge gaps for hydrogen safety engineering of LH2 systems and infrastructure. Analytical studies and computational fluid dynamics (CFD) modelling are used complementarily to assess relevant incident scenarios and compare the consequences and hazard distances for hydrogen systems at ambient and cryogenic temperature. The research encompasses the main phenomena characterising an incident scenario: release and dispersion ignition and combustion. Experimental tests on cryogenic hydrogen systems are used for the validation of correlations and numerical models. It is observed that engineering tools originally developed for hydrogen at ambient temperature are yet applicable to the cryogenic temperature field. For a same storage pressure and nozzle diameter the decrease of hydrogen temperature from ambient to cryogenic 80 K may lead to longer hazard distances associated to unignited and ignited hydrogen releases. The potential for ignition by spark discharge or spontaneous ignition mechanism is seen to decrease with the decrease of hydrogen temperature. CFD modelling is used to give insights into the pressure dynamics created by LH2 vessels rupture in a fire using experimental data from literature.

Ports have significant emissions from using carbon-based electricity and fuels. This paper presents a scoping literature review of port energy models providing interpretations of the models capabilities and limitations in representing activities coverages of hydrogen technologies use as decarbonisation prediction tools and to highlight research directions. Three model categories were assessed. The Conceptual-Driven use a top-down analytical structure for objectives optimisation. Recent publications have increasing coverages of port activities by electrical with hydrogen technologies but limited representation of diesel equipment. The Data-Driven represent entire ports as top-down or focus on electrical mobile equipment in bottom-up data-only abstract structures for algorithm analysis. Both model types omit coverage of hydrogen powered mobile equipment at temporal resolutions representing typical duties and measured emissions for weighting predictions. A HybridDriven model is proposed as a decarbonisation assessment tool for improved representation of diesel mobile equipment duty-profiles referenceable baselines and matching with hydrogen technologies characteristics.

Hydrogen holds immense potential to assist in the transition from fossil fuels to sustainable energy sources but its environmental impact depends on how it is produced. This study introduces the pale-blue hydrogen production method which is a hybrid approach utilizing both carbon capture and bioenergy inputs. Comparative life cycle analysis is shown for grey blue green and pale-blue hydrogen using cumulative energy demand carbon footprint (CF) and water footprint. Additionally the integration of solar-powered production methods (ground-based photovoltaic and floating photovoltaic (FPV) systems) is examined. The results showed blue hydrogen [steam methane reforming (SMR) + 56% carbon capture storage (CCS)] was 72% less green hydrogen gas membrane (GM) 75% less blue hydrogen [SMR+90%CCS] 88% less and green hydrogen FPV have 90% less CF compared to grey hydrogen. Pale-blue hydrogen [50%B-50%G] blue hydrogen (GM + plasma reactor(PR)) PV and blue hydrogen (GM + PR) FPV offset 26 48 and 52 times the emissions of grey hydrogen.

Hydrogen as an energy carrier is a promising alternative to fossil fuels and it becomes more and more popular in developed countries as a carbon-free fuel. The low boiling temperature of hydrogen (20 K or −253.15 ◦C) provides a unique opportunity to implement superconductors with a critical temperature above 20 K such as MgB2 or high-temperature superconductors. Superconductors increase efficiency and reduce the loss of energy which could compensate for the high price of LH2 to some extent. Norway is one of the pioneer countries with adequate infrastructure for using liquid hydrogen in the industry especially in marine technology where a superconducting propulsion system can make a remarkable impact on its economy. Using superconductors in the motor of a propulsion system can increase its efficiency from 95% to 98% when the motor operates at full power. The difference in efficiency is even greater when the motor does not work at full power. Here we survey the applications of liquid hydrogen and superconductors and propose a realistic roadmap for their synergy specifically for the Norwegian economy in the marine industry.

Many industrial processes such as ammonia fuel or steel production require considerable amounts of fossil feedstocks contributing significantly to global greenhouse gas emissions. Some of these fossil feedstocks and processes can be decarbonised via Power-to-X (P2X) production concepts based on hydrogen (H2) requiring considerable amounts of renewable electricity. Creating hydrogen valleys (HV) may facilitate a cost-efficient H2 production feeding H2 to multiple customers and purposes. At a large scale these HVs will shift from price takers to price makers in the local electricity market strongly affecting investments in renewable electricity. This paper analysed the dynamic evolution of a HV up to GW-scale by adopting a stepwise approach to HV development in North Ostrobothnia Finland considering multiple H₂ end uses such as P2X fuel manufacturing including ammonia methanol liquefied methane and H2 for mobility. The analysis was conducted by employing a dynamic linear optimization model “SmartP2X” to minimize LCOH within the HV boundaries. The analysis predicts that with ex-factory sales prices that are equal to or higher than marginal costs for P2X fuels production a LCOH of 3.4–3.9 EUR/kgH2 could be reached. The LCOH slightly increased with the size of the HV due to a H2 transmission pipeline investment; omitting the pipeline cost the LCOH exhibited a decreasing trend. The produced H2 will generally meet the EU definitions for clean Renewable Fuel of Non-Biological Origin (RFNBO). The additional wind power required for the HV scenarios was up to 2.1–3.0 GW depending on the RFNBO-fuel sales price. This represents a fraction of the current investment plans in the North Ostrobothnia region. The results of this paper contribute to the discussion on the interplay between hydrogen ecosystems and the power market particularly in relation to power-intensive P2X processes.

Demand for low-carbon sources of hydrogen and power is expected to rise dramatically in the coming years. Individually steam methane reformers (SMRs) and combined cycle gas power plants (CCGTs) when combined with carbon capture utilisation and storage (CCUS) can produce large quantities of ondemand decarbonised hydrogen and power respectively. The ongoing trend towards the development of CCUS clusters means that both processes may operate in close proximity taking advantage of a common infrastructure for natural gas supply electricity grid connection and the CO2 transport and storage network. This work improves on a previously described novel integration process which utilizes flue gas sequential combustion to incorporate the SMR process into the CCGT cycle in a single “combined fuel and power” (CFP) plant by increasing the level of thermodynamic integration through the merger of the steam cycles and a redesign of the heat recovery system. This increases the 2nd law thermal efficiency by 2.6% points over un-integrated processes and 1.9% points the previous integration design. Using a conventional 35% wt. monoethanolamine (MEA) CO2 capture process designed to achieve two distinct and previously unexplored CO2 capture fractions; 95% gross and 100% fossil (CO2 generated is equal to the quantity of CO2 captured). The CFP configuration reduces the overall quantity of flue gas to be processed by 36%–37% and increases the average CO2 concentration of the flue gas to be treated from 9.9% to 14.4% (wet). This decreases the absorber packing volume requirements by 41%–56% and decreases the specific reboiler duty by 5.5% from 3.46–3.67 GJ/tCO2 to 3.27–3.46 GJ/tCO2 further increasing the 2nd law thermal efficiency gains to 3.8%–4.4% points over the un-integrated case. A first of a kind techno economic analysis concludes that the improvements present in a CO2 abated CFP plant results in a 15.1%–17.3% and 7.6%–8.0% decrease in capital and operational expenditure respectively for the CO2 capture cases. This translates to an increase in the internal rate of return over the base hurdle rate of 7.5%–7.8% highlighting the potential for substantial cost reductions presented by the CFP configuration.

Hydrogen injection (HI) is an emerging decarbonisation technology for ironmaking blast furnaces (BFs) yet its impact on the in-furnace phenomenon in the raceway of an industry BF remains unclear. In this study an industrialscale Reactive Computational Fluid Dynamic Discrete Element Method coupling model (rCFD-DEM) is developed to study the impacts of HI on the raceway dynamics and coke combustion inside an industrial-scale BF. To overcome the limit in previous CFD-DEM works this work considers the impact of top loading on the in-raceway reacting flow for the first time. The comparisons show that the raceway size is sensitive to the top loading ratio suggesting that the top loading should be considered in future raceway modelling. Then the quantitative effect of the HI rate is numerically evaluated. It is indicated that when the HI rate increases from zero to 8 kg/tHM the raceway height and depth increase by 95% and 81% respectively under the investigated conditions. The underlying mechanism is explored: the increase in HI rate leads to an increase in inter-phase drag force and interparticle collision and in the convection and radiation heat transfer rates by 33 and 32 times respectively. This study provides a cost-effective tool to understand and optimise HI in industrial-scale BFs for a lower carbon footprint empowering the steel industry with crucial insights.

Portugal’s commitment to carbon neutrality by 2050 has intensified the search for renewable energy alternatives with biomass gasification emerging as a promising pathway for hydrogen production. This comprehensive review analyzes the potential of 39 Portuguese biomass species for gasification processes based on extensive laboratory characterization data including proximate analysis ultimate analysis heating values and metal content. The studied biomasses encompass woody shrubland species (matos arbustivos lenhosos) forest residues and energy crops representative of Portugal’s diverse biomass resources. Results indicate significant variability in gasification potential with moisture content ranging from 0.5% to 14.9% ash content from 0.5% to 5.5% and higher heating values between 16.8 and 21.2 MJ/kg. Theoretical hydrogen yield calculations suggest that Portuguese biomasses could produce between 85 and 120 kg H2 per ton of dry biomass with species such as Eucalyptus globulus Pinus pinaster and Cytisus multiflorus showing the highest potential. Statistical analysis reveals strong negative correlations between moisture content and hydrogen yield potential (r = −0.63) while carbon content shows positive correlation with gasification efficiency. The comprehensive characterization provides essential data for optimizing gasification processes and establishing Portugal’s biomass-tohydrogen production capacity contributing to the national hydrogen strategy and renewable energy transition.

With the fast-growing implementation of renewable energy projects Morocco is positioned as a pioneer in green and sustainable development aiming to achieve 52% of its electricity production from renewable sources by 2030. This ambitious target faces challenges due to the intermittent nature of renewable energy which impacts grid stability. Hydrogen offers a promising solution but identifying the most cost-effective production configurations is critical due to high investment costs. Despite the growing interest in renewable energy systems the techno-economic analysis of (Concentrating Solar PowerPhotovoltaic) CSP-PV hybrid configurations remain insufficiently explored. Addressing this gap is critical for optimizing hybrid systems to ensure cost-effective and scalable hydrogen production. This study advances the field by conducting a detailed technoeconomic assessment of CSP-PV hybrid systems for hydrogen production at selected locations in Morocco leveraging high-precision meteorological data to enhance the accuracy and reliability of the analysis. Three configurations are analyzed: (i) a standalone 10 MW PV plant (ii) a standalone 10 MW Stirling dish CSP plant and (iii) a 10 MW hybrid system combining 5 MW from each technology. Results reveal that hybrid CSP-PV systems with single-axis PV tracking achieve the lowest levelized cost of hydrogen (LCOH2) reducing costs by up to 11.19% and increasing hydrogen output by approximately 10% compared to non-tracking systems. Additionally the hybrid configuration boosts annual hydrogen production by 2.5–11.2% compared to PV-only setups and reduces production costs by ~25% compared to standalone CSP systems. These findings demonstrate the potential of hybrid solar systems for cost-efficient hydrogen production in regions with abundant solar resources.

Hydrogen production via water electrolysis and renewable electricity is expected to play a pivotal role as an energy carrier in the energy transition. This fuel emerges as the most environmentally sustainable energy vector for non-electric applications and is devoid of CO2 emissions. However an electrolyzer´s infrastructure relies on scarce and energyintensive metals such as platinum palladium iridium (PGM) silicon rare earth elements and silver. Under this context this paper explores the exergy cost i.e. the exergy destroyed to obtain one kW of hydrogen. We disaggregated it into non-renewable and renewable contributions to assess its renewability. We analyzed four types of electrolyzers alkaline water electrolysis (AWE) proton exchange membrane (PEM) solid oxide electrolysis cells (SOEC) and anion exchange membrane (AEM) in several exergy cost electricity scenarios based on different technologies namely hydro (HYD) wind (WIND) and solar photovoltaic (PV) as well as the different International Energy Agency projections up to 2050. Electricity sources account for the largest share of the exergy cost. Between 2025 and 2050 for each kW of hydrogen generated between 1.38 and 1.22 kW will be required for the SOEC-hydro combination while between 2.9 and 1.4 kW will be required for the PV-PEM combination. A Grassmann diagram describes how non-renewable and renewable exergy costs are split up between all processes. Although the hybridization between renewables and the electricity grid allows for stable hydrogen production there are higher non-renewable exergy costs from fossil fuel contributions to the grid. This paper highlights the importance of nonrenewable exergy cost in infrastructure which is required for hydrogen production via electrolysis and the necessity for cleaner production methods and material recycling to increase the renewability of this crucial fuel in the energy transition.

Novel hydrogen-based aircraft concepts pose significant challenges for the system development process. This paper proposes a generic adaptable and multidisciplinary framework for integrated model-based systems engineering (MBSE) and model-based safety assessment (MBSA) for the conceptual design of complex systems. The framework employs a multi-granularity modelcentric approach whereby the architectural specification is utilized for design as well as query purposes as part of a qualitative and quantitative graphbased preliminary safety assessment. For the qualitative assessment design and safety rules based on existing standards and best practices are formalized in the model and applied to a graph-based architecture representation. Consequently the remaining architectures are quantitatively assessed using automated fault trees. This safety-integrated approach is applied to the conceptual design of a liquid hydrogen fuel system architecture as a novel uncertain and complex system with many unknown system interrelations. This paper illustrates the potential of a combined MBSE-MBSA framework to streamline complex early-stage system design and demonstrates that all qualitatively down-selected hydrogen system architecture variants also satisfy quantitative assessment. Furthermore it is shown that the design space of novel systems is also constrained by safety and certification requirements significantly reducing the number of actual feasible solutions.

Tilos a Greek island in the Mediterranean Sea hosts a pioneering hybrid energy system combining an 800-kW wind turbine and a 160-kWp photovoltaic (PV) field. The predominance of wind power makes the energy production of the island almost constant during the year while the consumption peaks in summer in correspondence with the tourist season. If the island wants to achieve complete selfsufficiency seasonal storage becomes compulsory. This study makes use of measured production data over 1 year to understand the best combination of renewable energy generation and storage to match energy production with consumption. A stochastic optimization based on a differential evolution algorithm is carried out to showcase the configuration that minimizes the levelized cost of required energy (LCORE) in different scenarios. System performance is simulated by progressively increasing the size of the storage devices including a combination of Lithium-ion batteries and power-to-gas-topower (P2G2P) technologies and the PV field. An in-depth market review of current and forecasted prices for RES and ESS components supports the economic analysis including three time horizons (current and projections to 2030 and 2050) to account for the expected drop in component prices. Currently the hybrid storage system combining BESS and P2G2P is more cost-effective (264 €/MWh) than a BESS-only system (320 €/MWh). In the mid-term (2030) the expected price drop in batteries will shift the optimal solution towards this technology but the LCORE reached by the hybrid storage (174 €/MWh) will still be more economical than BESS-only (200 €/MWh). In the long term (2050) the expected price drop in hydrogen technologies will push again the economic convenience of P2G2P and further reduce the LCORE (132.4 €/MWh).

Environmental concerns and the imperative to achieve net-zero carbon emissions have driven the exploration of efficient and sustainable advancements in automobile technologies. The automotive sector is undergoing a significant transformation primarily propelled by the adoption of green fuel technologies. Among the most promising innovations are green vehicle technologies and the integration of non-conventional power sources including advanced batteries (featuring high energy density) fuel cells (capable of long-range energy generation with water as the sole byproduct) and super-capacitors (characterized by rapid charge–discharge capabilities). This article examines the performance efficiency and adaptability of these power sources for electric vehicles (EVs) providing a comprehensive comparison of their functional capabilities. Additionally it analyzes the integration of super-capacitors with batteries and fuel cells emphasizing the potential of hybrid systems to enhance vehicle performance optimize energy management and extend operational range. The role of power converters in such systems is also discussed underscoring their critical importance in ensuring efficient energy transfer and effective energy management.

Hydrogen (H2) will play a vital role in the global shift towards sustainable energy systems. Due to the high cost and challenges associated with storing hydrogen in large quantities for industrial applications Underground Hydrogen Storage (UHS) in geological formations has emerged as a promising solution. Clay minerals abundant in subsurface environments play a critical role in UHS by providing low permeability cation exchange capacity and stability essential for preventing hydrogen leakage. However microorganisms in the subsurface particularly hydrogenotrophic species interact with clay minerals in ways that can affect the integrity of these storage systems. Microbes form biofilms on clay surfaces which can cause pore clogging and reduce the permeability of the reservoir potentially stabilizing H2 storage and limiting injectivity. Microbial-induced chemical weathering through the production of organic acids and redox reactions can degrade clay minerals releasing metal ions and destabilizing the storage site. These interactions raise concerns about the long-term storage capacity of UHS as microbial processes could lead to H2 loss and caprock degradation compromising the storage system’s effectiveness. This mini review aims to cover the current understanding of the interactions between clay minerals and microorganisms and how these dynamics can affect the safe and sustainable deployment of UHS.

Green hydrogen is a promising solution within carbon free energy systems with Sub-Saharan Africa being a possibly well-suited candidate for its production. However green hydrogen production in Sub-Saharan Africa is not yet investigated in detail. This work determines the cost-potential for green hydrogen production within this region. Therefore a potential analysis for PV wind and hydropower groundwater analysis and energy systems optimization are conducted. The results are evaluated under local socio-economic factors. Results show that hydrogen costs start at 1.6 EUR/kg in Mauritania with a total potential of ~259 TWh/a under 2 EUR/kg in 2050. Two third of the region experience groundwater limitations and need desalination at an added costs of ~1% of hydrogen costs. Socio-economic analysis show that green hydrogen deployment can be hindered along the Upper Guinea Coast and the African Great Lakes driven by limited energy access low labor costs in West Africa and high labor potential in other regions.

This week the EAH team discusses LIFTE H2’s plans for the future and discusses the challenges in hydrogen markets expansion and rollout the need for resiliency for offtakers and how to build consumer confidence.

The podcast can be found on their website.

In this study the applicability of an integrated-hybrid process was performed in a divided electrochemical cell for removing organic matter from a polluted effluent with simultaneous production of green H2. After that the depolluted water was reused for the first time in the cathodic compartment once again in the same cell to be a viable environmental alternative for converting water into energy (green H2) with higher efficiency and reasonable cost requirements. The production of green H2 in the cathodic compartment (Ni-Fe-based steel stainless (SS) mesh as cathode) in concomitance with the electrochemical oxidation (EO) of wastewater in the anodic compartment (boron-doped diamond (BDD) supported in Nb as anode) was studied (by applying different current densities (j = 30 60 and 90 mA cm−2 ) at 25 ◦C) in a divided-membrane type electrochemical cell driven by a photovoltaic (PV) energy source. The results clearly showed that in the first step the water anodically treated by applying 90 mA cm−2 for 180 min reached high-quality water parameters. Meanwhile green H2 production was greater than 1.3 L with a Faradaic efficiency of 100%. Then in a second step the water anodically treated was reused in the cathodic compartment again for a new integrated-hybrid process with the same electrodes under the same experimental conditions. The results showed that the reuse of water in the cathodic compartment is a sustainable strategy to produce green H2 when compared to the electrolysis using clean water. Finally two implied benefits of the proposed process are the production of green H2 and wastewater cleanup both of which are equally significant and sustainable. The possible use of H2 as an energetic carrier in developing nations is a final point about sustainability improvements. This is a win-win solution.

This paper addresses public acceptance of a proposed sub-regional hydrogen– electric aviation service reporting initial empirical evidence from the UK HEART project. The objective was to assess public acceptance of a wide range of service features including hydrogen power electric motors and pilot assistance automation in the context of an ongoing realisable commercial plan. Both qualitative and quantitative data collection instruments were leveraged including focus groups and stakeholder interviews as well as the questionnaire-based Scottish National survey coupled with the advanced discretechoice modelling of the data. The results from each method are presented compared and contrasted focusing on the strength reliability and validity of the data to generate insights into public acceptance. The findings suggest that public concerns were tempered by an incomplete understanding of the technology but were interpretable in terms of key service elements. Respondents’ concerns and opinions centred around hydrogen as a fuel singlepilot automation safety and security disability and inclusion environmental impact and the perceived usefulness of novel service features such as terminal design automation and sustainability. The latter findings were interpreted under a joint framework of technology acceptance theory and the diffusion of innovation. From this we drew key insights which were presented alongside a discussion of the results.

This study introduces an effective analysis framework for exploring the complex interrelation between the renewable energy factor (REF) and the economic dimensions of a PV-driven microgrid featuring a dual-level storage system that incorporates both hydrogen and electrical energy storage. By establishing a coupled model that integrates dynamic simulations with a statistical multi-objective optimization algorithm the research aims to achieve optimal component sizing—a critical step in assessing the hybrid system across various REF levels—while effectively reducing the levelized cost of electricity (LCOE). Using the analysis outcomes of a case study a comprehensive techno-economic assessment facilitates a nuanced evaluation of the interplay between the REF system economics across various equipment cost quartiles and grid tariffs addressing the feasibility of the proposed solution for a sustainable energy transition. The results highlight how grid tariffs and REF jointly influence LCOE values across cost quartiles impacting hybrid system design and decision-making. An exponential correlation is observed between life cycle cost (LCC) and REF with the increase in annual operating costs being marginal compared to the initial cost rise. For the net-zero energy case the LCOE ranges from 0.0380 to 0.1873 $/kWh while at REF = 0.6 it spans from 0.0461 to 0.1334 $/kWh reflecting a 71 % larger difference (range). A sensitivity analysis indicates that each 5 % increase in REF leads to an average 20.7 % rise in payback period (PBP) for a given grid tariff.

Hydrogen and electric buses are considered effective options for decarbonizing the public transportation sector positioning them as a leader in this transition. This study models the environmental and economic performances of a set of bus powertrain technologies considering a real case-study of suburban public transport in Italy and including fuel cell electric vehicles (FCEV) battery electric vehicles (BEV) biomethane-powered vehicles (CBM) natural gas (CNG) and diesel buses. The environmental performances of FCEV and BEV are significantly influenced by the energy source used for hydrogen production or battery charging. Specifically using the electricity mix for FCEV leads to the highest greenhouse gas emissions and fossil fuel demand. In contrast BEV show better environmental performance than conventional powertrains especially when powered by photovoltaics. When powered by photovoltaics BEV reveal similar results to FCEV in terms of environmental impacts except for resource depletion where both perform poorly. Transitioning from diesel to BEV or FCEV can enhance local air quality regardless of the energy source. The economic analysis indicates that FCEV are the most expensive option followed by BEV both of which are currently costlier than diesel and CNG systems. CBM from waste streams emerges as a cost-effective and environmentally friendly solution. This study suggests prioritizing biomethane derived from biowaste manure and residual biomass (excluding energy crops) as a part of the fuels for public transport decarbonization in the EU to advance EU decarbonization goals despite limitations due to resource availability. Furthermore BEV powered by renewables should be prioritized whenever their range is adequate.

To enable hydrogen-powered aircraft operations liquid hydrogen infrastructure has to be planned well in advance. This study analyses the transition pathway of liquid hydrogen supply infrastructure from the initial development phase to market penetration optimizing the design and dispatch of the system. The findings reveal that the single-year approach used in previous studies significantly underestimates the costs associated with supply infrastructure. During the transition phase substantial investments are required in specific years leading to high supply costs particularly in the early years. Off-take agreements could be used to achieve a more balanced cost distribution. For the considered location of a generic airport on-site liquid hydrogen supply costs range between 3.83 and 5.03 USD/kgH2 assuming a long-term supply agreement. At a less favourable airport supply costs are 29% higher compared to a favourable location. However costs could be reduced by up to 12% if hydrogen is imported via vessels or the European Hydrogen Backbone. The primary factors influencing supply costs are the availability of renewable energy resources and the distances to the nearest port as well as hydrogen production hubs. Therefore the optimal supply chain must be assessed individually for each airport. Overall this study provides insights and a methodology that can support the development of future liquid hydrogen infrastructure roadmaps for hydrogen-powered aviation.

Today hydrogen (H2) is overwhelmingly produced through steam methane reforming (SMR) of natural gas which emits about 12 kg of carbon dioxide (CO2) for 1 kg of H2 (∼12 kg-CO2/kg-H2). Water electrolysis offers an alternative for H2 production but today’s electrolyzers consume over 55 kWh of electricity for 1 kg of H2 (>55 kWh/kg-H2). Electric grid-powered water electrolysis would emit less CO2 than the SMR process when the carbon intensity for grid power falls below 0.22 kg-CO2/kWh. Solar- and wind-powered electrolytic H2 production promises over 80% CO2 reduction over the SMR process but large-scale (megawatt to gigawatt) direct solar- or wind-powered water electrolysis has yet to be demonstrated. In this paper several approaches for solar-powered electrolysis are analyzed: (1) coupling a photovoltaic (PV) array with an electrolyzer through alternating current; (2) direct-current (DC) to DC coupling; and (3) direct DC-DC coupling without a power converter. Co-locating a solar or wind farm with an electrolyzer provides a lower power loss and a lower upfront system cost than long-distance power transmission. A load-matching PV system for water electrolysis enables a 10%–50% lower levelized cost of electricity than the other systems and excellent scalability from a few kilowatts to a gigawatt. The concept of maximum current point tracking is introduced in place of maximum power point tracking to maximize the H2 output by solarpowered electrolysis.

Hydrogen fueling stations are critical infrastructure for deploying zero emission hydrogen fuel cell electric vehicles (FCEV). Stations with greater dispensing capacities and higher energy efficiency are needed and cryogenic liquid hydrogen (LH2) has the potential to meet these needs. It is necessary to ensure that hazards and risks are appropriately identified and managed. This paper presents a Quantitative Risk Assessment (QRA) methodology for high-capacity (dispensing >1000 kg/day) hydrogen fueling stations with liquid hydrogen storage and presents the application of that methodology by presenting a Failure Mode and Effect Analysis (FMEA) and data curation for the design developed for this study. This methodology offers a basis for risk and reliability evaluation of these systems as their designs evolve and as operational data becomes available. We developed a generic station design and process flow diagram for a high-capacity hydrogen fueling station with LH2 storage. Following the system description is hazard identification done from FMEA to identify the causes of hydrogen releases and the critical components causing the releases. Finally data collection and curation is discussed including challenges stemming from the limited public availability of reliability data on components used in liquid hydrogen systems. This paper acts as an introduction to the full QRA presented in its companion paper Schaad et al. [1].

This report by the Clean Energy Technology Observatory (CETO) provides an updated strategic analysis of the EU clean energy technology sector. The EU's renewable share in gross final energy consumption rose to 24.5% in 2023 and to 44.7% of gross electricity consumption. The electrification rate however has remained almost unchanged at 26% over the decade to 2023 indicating slow progress on decarbonisation of transport and heating sectors. The EU renewable energy industry saw growth in turnover and gross value added in 2023 outperforming the overall economy. However the production value of clean energy technologies declined in some areas such as bioenergy PV and hydrogen electrolyser production. EU public investment in energy research and innovation has increased but it remains lower as a share of GDP compared to other major economies. Employment in the renewable energy sector reached 1.7 million in 2022 growing at a faster rate than the economy as a whole. The clean energy sector however faces challenges in manufacturing. A new sustainability assessment framework has been applied for clean energy technologies highlighting the need for a harmonized basis for comparing results. The report also underscores the general need to improve data quality and timeliness to better inform policy makers and investors.

To mitigate challenges arising from renewable energy volatility and multi-energy load uncertainty this paper introduces a dynamic hydrogen blending (DHB) strategy for an integrated energy system. The strategy is categorized into Continuous Hydrogen Blending (CHB) and Time-phased Hydrogen Blending (THB) based on the temporal variations in the hydrogen blending ratio. To evaluate the regulatory effect of DHB on uncertainty a datadriven distributionally robust optimization method is employed in the day-ahead stage to manage system uncertainties. Subsequently a hierarchical model predictive control framework is designed for the intraday stage to track the day-ahead robust scheduling outcomes. Experimental results indicate that the optimized CHB ratio exhibits step characteristics closely resembling the THB configuration. In terms of cost-effectiveness CHB reduces the day-ahead scheduling cost by 0.87% compared to traditional fixed hydrogen blending schemes. THB effectively simplifies model complexity while maintaining a scheduling performance comparable to CHB. Regarding tracking performance intraday dynamic hydrogen blending further reduces upper- and lower-layer tracking errors by 4.25% and 2.37% respectively. Furthermore THB demonstrates its advantage in short-term energy regulation effectively reducing tracking errors propagated from the upper layer MPC to the lower layer resulting in a 2.43% reduction in the lower-layer model’s tracking errors.

In response to the greenhouse gas (GHG) reduction targets set by the Paris Agreement green hydrogen has become a key solution for global decarbonisation. However research on the design of green hydrogen production facilities remains limited particularly in Brazil. This study bridges this gap by developing a comprehensive design for a green hydrogen production plant powered by an 81 MW photovoltaic (PV) system in Ceará Brazil. The facility layout equipment sizing and resource requirements were determined using the Systematic Layout Planning (SLP) method based on the available energy for daily hydrogen production. The design also integrates safety regulations including local standards in Ceará as well as raw material needs and production capacity. This study delivers a detailed facility layout specifying equipment placement and capacity based on the PV plant’s output while ensuring compliance with safety protocols. This research contributes to the green hydrogen literature by providing a structured methodology for facility design serving as a reference for future projects and fostering the advancement of green hydrogen technology particularly in developing countries.

The development of liquid hydrogen storage systems is a key aspect to enable future clean air transportation. However safety analysis research for such systems is still limited and is hindered by the limited experience with liquid hydrogen storage in aviation. This paper presents the outcomes of a preliminary safety assessment applied to this new type of storage system accounting for the hazards of hydrogen. The methodology developed is based on hazard identification and frequency evaluation across all system features to identify the most critical safety concerns. Based on the safety assessment a set of safety recommendations concerning different subsystems of the liquid hydrogen storage system is proposed identifying hazard scopes and necessary mitigation actions across various system domains. The presented approach has been proven to be suitable for identifying essential liquid hydrogen hazards despite the novelty of the technology and for providing systematic design recommendations at a relatively early design stage.

This study investigates the potential for establishing a self-sufficient renewable hydrogen production facility utilising a floating photovoltaic (FPV) system on an artificial irrigation reservoir located in a small municipality in southern Italy. The analysis examines the impact of different system configurations and operating conditions on the technical economic and environmental performance with a particular focus on hydrogen production and water conservation resulting from reduced evaporation. Different sizes of the FPV plant are considered with and without a tracking system. The electrolyser performance is evaluated under both fixed and variable load conditions also considering the integration of battery storage to ensure consistent operation. The findings indicate that the adoption of the largest FPV plant can result in the conservation of approximately 1.87 million m3 of water annually while simultaneously producing up to 4199 tons of hydrogen per year in variable load mode—more than twice the output compared to fixed load conditions. Although battery integration increases hydrogen production it also leads to higher investment and maintenance costs. Therefore the variable load operation emerges as the most economically viable option reducing the levelized cost of hydrogen (LCOH) to €13.18/kg a 26 % reduction compared to fixed load operation. Moreover the implementation of a vertical axis tracking system leads to only marginal LCOH reductions (maximum 2.2 %) and does not justify the additional complexity. In all tested scenarios the system proves to be self-sustaining. Given the case study’s location in southern Italy—where a pilot project for fuel cell–battery hybrid trains is underway—the hydrogen produced is assumed to be used for railway applications as a possible offtaker. The analysis shows that the potential of the system in terms of hydrogen production is much higher (tens of times) than the estimated demand of the present hydrogen railway configuration thus suggesting that a significant expansion of the number of trains and routes served could be considered. Although this work is based on a specific case study its key findings are potentially replicable in other contexts—particularly in Mediterranean or semi-arid regions where water scarcity may otherwise act as a limiting factor for the deployment of hydrogen production systems.

Fuel cells have become a fundamental technology in the development of clean energy systems playing a vital role in the global shift toward a low-carbon future. With the growing need for sustainable hydrogen production perfluoro sulfonic acid (PFSA) ionomer membranes play a critical role in optimizing green hydrogen technologies and fuel cells. This study aims to investigate the effects of different environmental and solvent treatments on the chemical and physical properties of Nafion N−115 membranes to evaluate their suitability for both hydrogen production in proton exchange membrane (PEM) electrolyzers and hydrogen utilization in fuel cells supporting integrated applications in the local and global green hydrogen economy. To achieve this Nafion N−115 membranes were partially dissolved in various solvent mixtures including ethanol/isopropanol (EI) isopropanol/water (IW) dimethylformamide/N-methyl-2-pyrrolidone (DN) and ethanol/methanol/isopropanol (EMI) evaluated under water immersion and thermal stress and characterized for chemical stability mechanical strength water uptake and proton conductivity using advanced electrochemical and spectroscopic techniques. The results demonstrated that the EMI-treated membrane showed the highest proton conductivity and maintained its structural integrity making it the most promising for hydrogen electrolysis applications. Conversely the DN-treated membrane exhibited reduced stability and lower conductivity due to solvent-induced degradation. This study highlights the potential of EMI as an optimal solvent mixture for enhancing PFSA membranes performance in green hydrogen production contributing to the advancement of sustainable energy solutions.

: Hydrogen is a clean non-polluting fuel and a key player in decarbonizing the energy sector. Interest in hydrogen production has grown due to climate change concerns and the need for sustainable alternatives. Despite advancements in waste-to-hydrogen technologies the efficient conversion of mixed plastic waste via an integrated thermochemical process remains insufficiently explored. This study introduces a novel multi-stage pyrolysis-reforming framework to maximize hydrogen yield from mixed plastic waste including polyethylene (HDPE) polypropylene (PP) and polystyrene (PS). Hydrogen yield optimization is achieved through the integration of two water–gas shift reactors and a pressure swing adsorption unit enabling hydrogen production rates of up to 31.85 kmol/h (64.21 kg/h) from 300 kg/h of mixed plastic wastes consisting of 100 kg/h each of HDPE PP and PS. Key process parameters were evaluated revealing that increasing reforming temperature from 500 ◦C to 1000 ◦C boosts hydrogen yield by 83.53% although gains beyond 700 ◦C are minimal. Higher reforming pressures reduce hydrogen and carbon monoxide yields while a steam-to-plastic ratio of two enhances production efficiency. This work highlights a novel scalable and thermochemically efficient strategy for valorizing mixed plastic waste into hydrogen contributing to circular economy goals and sustainable energy transition.

Ports are critical hubs in the global supply chain yet they face mounting challenges in achieving carbon neutrality. Port Integrated Multi-Energy Systems (PIMESs) offer a comprehensive solution by integrating renewable energy sources such as wind photovoltaic (PV) hydrogen and energy storage with traditional energy systems. This study examines the implementation of a real-word PIMES showcasing its effectiveness in reducing energy consumption and emissions. The findings indicate that in 2024 the PIMES enabled a reduction of 1885 tons of CO2 emissions with wind energy contributing 84% and PV 16% to the total decreases. The energy storage system achieved a charge–discharge efficiency of 99.15% while the hydrogen production system demonstrated an efficiency of 63.34% producing 503.87 Nm3/h of hydrogen. Despite these successes challenges remain in optimizing renewable energy integration expanding storage capacity and advancing hydrogen technologies. This paper highlights practical strategies to enhance PIMESs’ performances offering valuable insights for policymakers and port authorities aiming to balance energy efficiency and sustainability and providing a blueprint for carbon-neutral port development worldwide.

The purpose of this Hydrogen Pipeline System COP is to provide guidance based on current knowledge for the design construction and operation of transmission pipeline systems transporting gaseous hydrogen or blends of hydrogen and hydrocarbon fluids.<br/>The objective of the code is to provide guidance for the safe reliable and efficient transportation and storage of hydrogen in transmission pipeline systems that are required to conform to the AS(/NZS) 2885 series. The document also references adoption of other international codes where suitable guidance is available.<br/>This document is intended to be updated with revised design criteria and methods as research and experience improves the understanding of hydrogen service in transmission pipelines. Although the CoP may be further developed into a published standard in the future within the AS(/NSZ) 2885 series framework this current revision of the CoP is not equivalent to a formal published Australian standard. The document also includes expanded commentary and background information as an informative code of practice that is more extensive than is typically covered in a standard.

Hydrogen is emerging as a crucial energy source in the global effort to reduce dependence on fossil fuels and meet climate goals. Integrating hydrogen into Integrated Assessment Models (IAMs) is essential for understanding its potential and guiding policy decisions. These models simulate various energy scenarios assess hydrogen’s impact on emissions and evaluate its economic viability. However uncertainties surrounding hydrogen technologies must be effectively addressed in their modeling. This review examines how different IAMs incorporate hydrogen technologies and their implications for decarbonization strategies and policy development considering underlying uncertainties. We begin by analyzing the configuration of the hydrogen supply chain focusing on production logistics distribution and utilization. The modeling characteristics of hydrogen integration in 12 IAM families are explored emphasizing hydrogen’s growing significance in stringent climate mitigation scenarios. Results from the literature and the AR6 database reveal gaps in the modeling of the hydrogen supply chain particularly in storage transportation and distribution. Model characteristics are critical in determining hydrogen’s share within the energy portfolio. Additionally this study underscores the importance of addressing both parametric and structural uncertainties in IAMs which are often underestimated leading to varied outcomes regarding hydrogen’s role in decarbonization strategies.