United States

Natural ventilation is a well-known passive mitigation method to limit hydrogen build-up in confined spaces in case of accidental release [1-3]. In most cases a basic design of H2 infrastructure is adopted and vents installed for natural ventilation are adjusted according to safety targets and constraints of the considered structure. With the growing H2 mobility market the demand for H2 refueling infrastructure in our urban environment is on the rise. In order to meet both safety requirements and societal acceptance the design of such infrastructure is becoming more important. In this study a novel design concept is proposed for the hydrogen refueling station (HRS) by modifying physical structure while keeping safety consideration as the top priority of the concept. In this collaborative project between Air Liquide and the University of Delaware an extensive evaluation was performed on new structures of the processing container and dispenser of HRS by integrating safety protocols via passive means. Through a SWOT analysis combined with the most relevant approaches including analytical engineering models numerical simulations [4] and dedicated experimental trials an optimized design was obtained and its safety enhancement was fully evaluated. A small-scale processing container and an almost full-scale dispenser were built and tested to validate the design concepts by simulating accidental H2 release scenarios and assessing the associated consequences in terms of accumulation and potential flammable volumes formation. A conical dispenser and a V-shaped roof-top processing container which were easy to build and implement were designed and tested for this proof-of-concept study. This unique methodology from conception fundamental analysis investigation and validation through experimental design execution and evaluation is fully described in this study.

This perspective article delves into the critical role of hydrogen as a sustainable energy carrier in the context of the ongoing global energy transition. Hydrogen with its potential to decarbonize various sectors has emerged as a key player in achieving decarbonization and energy sustainability goals. This article provides an overview of the current state of hydrogen technology its production methods and its applications across diverse industries. By exploring the challenges and opportunities associated with hydrogen integration we aim to shed light on the pathways toward achieving a sustainable hydrogen economy. Additionally the article underscores the need for collaborative efforts among policymakers industries and researchers to overcome existing hurdles and unlock the full potential of hydrogen in the transition to a low-carbon future. Through a balanced analysis of the present landscape and future prospects this perspective article aims to contribute valuable insights to the discourse surrounding hydrogen’s role in the global energy transition.

The present paper offers a thorough examination of the safety measures enforced at hydrogen filling stations emphasizing their crucial significance in the wider endeavor to advocate for hydrogen as a sustainable and reliable substitute for conventional fuels. The analysis reveals a wide range of crucial safety aspects in hydrogen refueling stations including regulated hydrogen dispensing leak detection accurate hydrogen flow measurement emergency shutdown systems fire-suppression mechanisms hydrogen distribution and pressure management and appropriate hydrogen storage and cooling for secure refueling operations. The paper therefore explores several aspects including the sophisticated architecture of hydrogen dispensers reliable leak-detection systems emergency shut-off mechanisms and the implementation of fire-suppression tactics. Furthermore it emphasizes that the safety and effectiveness of hydrogen filling stations are closely connected to the accuracy in the creation and upkeep of hydrogen dispensers. It highlights the need for materials and systems that can endure severe circumstances of elevated pressure and temperature while maintaining safety. The use of sophisticated leak-detection technology is crucial for rapidly detecting and reducing possible threats therefore improving the overall safety of these facilities. Moreover the research elucidates the complexities of emergency shut-off systems and fire-suppression tactics. These components are crucial not just for promptly managing hazards but also for maintaining the station’s structural soundness in unanticipated circumstances. In addition the study provides observations about recent technical progress in the industry. These advances effectively tackle current safety obstacles and provide the foundation for future breakthroughs in hydrogen fueling infrastructure. The integration of cutting-edge technology and materials together with the development of upgraded safety measures suggests a positive trajectory towards improved efficiency dependability and safety in hydrogen refueling stations.

Hydrogen primarily produced from steam methane reforming plays a crucial role in oil refining and provides a solution for the oil and gas industry's long-term energy transition by reducing CO2 emissions. This paper examines hydrogen’s role in this transition. Firstly experiences from oil and gas exploration including in-situ gasification can be leveraged for hydrogen production from subsurface natural hydrogen reservoirs. The produced hydrogen can serve as fuel for generating steam and heat for thermal oil recovery. Secondly hydrogen can be blended into gas for pipeline transportation and used as an alternative fuel for oil and gas hauling trucks. Additionally hydrogen can be stored underground in depleted gas fields. Lastly oilfield water can be utilized for hydrogen production using geothermal energy from subsurface oil and gas fields. Scaling up hydrogen production faces challenges such as shared use of oil and gas infrastructures increased carbon tax for promoting blue hydrogen and the introduction of financial incentives for hydrogen production and consumption hydrogen leakage prevention and detection.

Hydrogen fuel cell vehicles (HFCVs) are a promising technology for reducing vehicle emissions and improving energy efficiency. Due to the ongoing evolution of this technology there is limited comprehensive research and documentation regarding the energy modeling of HFCVs. To address this gap the paper develops a simple HFCV energy consumption model using new fuel cell efficiency estimation methods. Our HFCV energy model leverages real-time vehicle speed acceleration and roadway grade data to determine instantaneous power exertion for the computation of hydrogen fuel consumption battery energy usage and overall energy consumption. The results suggest that the model’s forecasts align well with real-world data demonstrating average error rates of 0.0% and −0.1% for fuel cell energy and total energy consumption across all four cycles. However it is observed that the error rate for the UDDS drive cycle can be as high as 13.1%. Moreover the study confirms the reliability of the proposed model through validation with independent data. The findings indicate that the model precisely predicts energy consumption with an error rate of 6.7% for fuel cell estimation and 0.2% for total energy estimation compared to empirical data. Furthermore the model is compared to FASTSim which was developed by the National Renewable Energy Laboratory (NREL) and the difference between the two models is found to be around 2.5%. Additionally instantaneous battery state of charge (SOC) predictions from the model closely match observed instantaneous SOC measurements highlighting the model’s effectiveness in estimating real-time changes in the battery SOC. The study investigates the energy impact of various intersection controls to assess the applicability of the proposed energy model. The proposed HFCV energy model offers a practical versatile alternative leveraging simplicity without compromising accuracy. Its simplified structure reduces computational requirements making it ideal for real-time applications smartphone apps in-vehicle systems and transportation simulation tools while maintaining accuracy and addressing limitations of more complex models.

This week’s episode is a discussion between EAH hosts Patrick Molloy Alicia Eastman and Chris Jackson. The team cover the current status of hydrogen regulation innovation financing markets and consolidation. Hanging over most conversations in the decarbonization or future fuels space is the perpetual question: When will investors actually step up with significant capital to help companies make it through the development desert instead of letting promising companies languish in the double dunes of despair? There has been a lot of talk but not a lot of action. Listen to the team unpack recent developments and hopes for the future.

The podcast can be found on their website.

The production of hydrogen-based dense energy carriers (DECs) has been proposed as a combined solution for the storage and dispatch of power generated through intermittent renewables. Frameworks that model and optimize the production storage and dispatch of generated energy are important for data-driven decision making in the energy systems space. The proposed multiperiod framework considers the evolution of technology costs under different levels of promotion through research and targeted policies using the year 2021 as a baseline. Furthermore carbon credits are included as proposed by the 45Q tax amendment for the capture sequestration and utilization of carbon. The implementation of the mixed-integer linear programming (MILP) framework is illustrated through computational case studies to meet set hydrogen demands. The trade-offs between different technology pathways and contributions to system expenditure are elucidated and promising configurations and technology niches are identified. It is found that while carbon credits can subsidize carbon capture utilization and sequestration (CCUS) pathways substantial reductions in the cost of novel processes are needed to compete with extant technology pathways. Further research and policy push can reduce the levelized cost of hydrogen (LCOH) by upwards of 2 USD/kg.

The transportation industry’s transition to carbon neutrality is essential for addressing sustainability concerns. This study details a model for calculating the carbon footprint of the transportation sector as it progresses towards carbon neutrality. The model aims to support policymakers in estimating the potential impact of various decisions regarding transportation technology and infrastructure. It accounts for energy demand technological advancements and infrastructure upgrades as they relate to each transportation market: passenger vehicles commercial vehicles aircraft watercraft and trains. A technology roadmap underlies this model outlining anticipated advancements in batteries hydrogen storage biofuels renewable grid electricity and carbon capture and sequestration. By estimating the demand and the technologies that comprise each transportation market the model estimates carbon emissions. Results indicate that based on the technology roadmap carbon neutrality can be achieved by 2070 for the transportation sector. Furthermore the model found that carbon neutrality can still be achieved with slippage in the technology development schedule; however delays in infrastructure updates will delay carbon neutrality while resulting in a substantial increase in the cumulative carbon footprint of the transportation sector.

Financing sizing operating or upgrading a hydrogen refueling station (HRS) is challenging and may be complex much more so in today's rapidly changing and growing hydrogen industry. There is a significant information gap regarding experimental hydrogen station activities. A high-level perspective on such data and information may facilitate the transition between present and future HRS operations. To address the need for such high-level perspective this paper presents a comprehensive data set on the performance of the California State University Los Angeles Hydrogen Research and Fueling Facility based on multi-year operational data. The analysis of over 4500 refueling events and over 8800 kg of hydrogen dispensed as well as the operation of the facility electrolyzer and of both storage and refueling compressors from 2016 to 2020 reveals a comprehensive picture of HRS energy performance and the identification of useful key performance indicators. In 2016 the station's energy efficiency was 25% but in 2017 and the first three quarters of 2018 it dropped to 15%. Station-specific energy consumption increased during these quarters. The 2020 first quarter energy consumption was between 70 and 80 kWh/kg. At this time the energy efficiency of the station reached 40%.<br/>This research is based on an unprecedented and unique dataset of an HRS operating under real-world conditions with an approach that can be informative for modeling the performance of other stations providing a dataset that HRS designers operators and investors may utilize to make data-driven choices regarding HRS components and their specs and size as well as operating strategies.

Civil aviation provides an essential transportation network that connects the world and supports global economic growth. To maintain these benefits while meeting environmental goals next-generation aircraft must have drastically reduced climate impacts. Hydrogen-powered aircraft have the potential to fly existing routes with no carbon emissions and reduce or eliminate other emissions. This paper is a comprehensive guide to hydrogen-powered aircraft that explains the fundamental physics and reviews current technologies. We discuss the impact of these technologies on aircraft design cost certification and environment. In the long term hydrogen aircraft appear to be the most compelling alternative to today’s kerosene-powered aircraft. Using hydrogen also enables novel technologies such as fuel cells and superconducting electronics which could lead to aircraft concepts that are not feasible with kerosene. Hydrogen-powered aircraft are technologically feasible but require significant research and development. Lightweight liquid hydrogen tanks and their integration with the airframe is one of the critical technologies. Fuel cells can eliminate in-flight emissions but must become lighter more powerful and more durable to make large fuel cell-powered transport aircraft feasible. Hydrogen turbofans already have these desirable characteristics but produce some emissions albeit much less damaging than kerosene turbofans. Beyond airframe and propulsion technologies the viability of hydrogen aircraft hinges on low-cost green hydrogen production which requires massive investments in the energy infrastructure.

Electrofuels fuels produced from electricity water and carbon or nitrogen are of interest as substitutes for fossil fuels in all energy and chemical sectors. This paper focuses on electrofuels for transportation where some can be used in existing vehicle/vessel/aircraft fleets and fueling infrastructure. The aim of this study is to review publications on electrofuels and summarize costs and environmental performance. A special case denoted as bio-electrofuels involves hydrogen supplementing existing biomethane production (e.g. anaerobic digestion) to generate additional or different fuels. We use costs identified in the literature to calculate harmonized production costs for a range of electrofuels and bio-electrofuels. Results from the harmonized calculations show that bio-electrofuels generally have lower costs than electrofuels produced using captured carbon. Lowest costs are found for liquefied bio-electro-methane bio-electro-methanol and bio-electro-dimethyl ether. The highest cost is for electro-jet fuel. All analyzed fuels have the potential for long-term production costs in the range 90–160 € MWh−1 . Dominant factors impacting production costs are electrolyzer and electricity costs the latter connected to capacity factors (CFs) and cost for hydrogen storage. Electrofuel production costs also depend on regional conditions for renewable electricity generation which are analyzed in sensitivity analyses using corresponding CFs in four European regions. Results show a production cost range for electro-methanol of 76–118 € MWh−1 depending on scenario and region assuming an electrolyzer CAPEX of 300–450 € kWelec −1 and CFs of 45%–65%. Lowest production costs are found in regions with good conditions for renewable electricity such as Ireland and western Spain. The choice of system boundary has a large impact on the environmental assessments. The literature is not consistent regarding the environmental impact from different CO2 sources. The literature however points to the fact that renewable energy sources are required to achieve low global warming impact over the electrofuel life cycle.

To achieve deep decarbonization renewable energy generation must be substantially increased. The technologies with the lowest levelized cost of electricity (LCOE) are land-based photovoltaics (PVs) and wind energy. Agri-PVs offer the potential for dual land use combining energy generation with agricultural activities. However the costs of agri-PVs are higher than those of ground-mounted PV. To enhance the competitiveness of agri-PV we investigate the synergies between agri-PVs and hydrogen electrolysis through process simulation. Additionally we analyse current technological developments in agri-PVs based on a market analysis of start-up companies. Our results indicate that the levelized cost of hydrogen (LCOH) can be comparable for agri-PVs and ground-mounted PVs due to the somewhat smoother electricity generation for the same installed capacity. The market analysis reveals the emergence of a technology ecosystem that integrates agri-PVs with next-generation agricultural technologies such as sensors robotics and artificial intelligence (AI) agents along with localized electricity generation forecasting. The integrated agri-PV and hydrogen generation system has significant global scaling potential for renewable energy generation. Furthermore it positively impacts local economies and energy resilience may reduce water scarcity in agriculture and leverages advancements in AI robotics PV and hydrogen generation technologies.

This review sets out to investigate the detrimental impacts of hydrogen gas (H2 ) on critical boiler components and provide appropriate state-of-the-art mitigation measures and future research directions to advance its use in industrial boiler operations. Specifically the study focused on hydrogen embrittlement (HE) and high-temperature hydrogen attack (HTHA) and their effects on boiler components. The study provided a fundamental understanding of the evolution of these damage mechanisms in materials and their potential impact on critical boiler components in different operational contexts. Subsequently the review highlighted general and specific mitigation measures hydrogen-compatible materials (such as single-crystal PWA 1480E Inconel 625 and Hastelloy X) and hydrogen barrier coatings (such as TiAlN) for mitigating potential hydrogen-induced damages in critical boiler components. This study also identified strategic material selection approaches and advanced approaches based on computational modeling (such as phase-field modeling) and data-driven machine learning models that could be leveraged to mitigate potential equipment failures due to HE and HTHA under elevated H2 conditions. Finally future research directions were outlined to facilitate future implementation of mitigation measures material selection studies and advanced approaches to promote the extensive and sustainable use of H2 in industrial boiler operations.

Low-carbon hydrogen plays a key role in European industrial decarbonization strategies. This work investigates the cost-optimal planning of European low-carbon hydrogen supply chains in the near term (2025–2035) comparing several hydrogen production technologies and considering multiple spatial scales. We focus on mature hydrogen production technologies: steam methane reforming of natural gas biomethane reforming biomass gasification and water electrolysis. The analysis includes carbon capture and storage for natural gas and biomass-derived hydrogen. We formulate and solve a linear optimization model that determines the costoptimal type size and location of hydrogen production and transport technologies in compliance with selected carbon emission targets including the EU fit for 55 target and an ambitious net-zero emissions target for 2035. Existing steam methane reforming capacities are considered and optimal carbon and biomass networks are designed. Findings identify biomass-based hydrogen production as the most cost-efficient hydrogen technology. Carbon capture and storage is installed to achieve net-zero carbon emissions while electrolysis remains costdisadvantageous and is deployed on a limited scale across all considered sensitivity scenarios. Our analysis highlights the importance of spatial resolution revealing that national perspectives underestimate costs by neglecting domestic transport needs and regional resource constraints emphasizing the necessity for highly decarbonized infrastructure designs aligned with renewable resource availabilities.

Back by popular demand Christopher Jackson Alicia Eastman and Patrick Molloy speak about the industry highlights and lowlights expectations for 2025 and what we can do to improve outcomes across the board. Equal parts sweepingly generalist and mind numbing minutiae create the perfect pundit cocktail. Wallow in the bad news and celebrate the bright sides together.

The podcast can be found on their website.

Securing decarbonized economies for energy and commodities will requireabundant and widely available green H2. Ubiquitous wastewaters and nontraditional watersources could potentially feed water electrolyzers to produce this green hydrogen withoutcompeting with drinking water sources. Herein we show that the energy and costs of treatingnontraditional water sources such as municipal wastewater industrial and resource extractionwastewater and seawater are negligible with respect to those for water electrolysis. We alsoillustrate that the potential hydrogen energy that could be mined from these sources is vast.Based on these findings we evaluate the implications of small-scale distributed waterelectrolysis using disperse nontraditional water sources. Techno-economic analysis and lifecycle analysis reveal that the significant contribution of H2 transportation to costs and CO2emissions results in an optimal levelized cost of hydrogen at small- to moderate-scale waterelectrolyzer size. The implications of utilizing nontraditional water sources and decentralizedor stranded renewable energy for distributed water electrolysis are highlighted for severalhydrogen energy storage and chemical feedstock applications. Finally we discuss challengesand opportunities for mining H2 from nontraditional water sources to achieve resilient and sustainable economies for water andenergy.

This study aims to advance the understanding of hydrogen embrittlement (HE) in low-carbon and low-alloy steels by developing a predictive framework for assessing fracture toughness (FT) a critical parameter for mitigating HE in hydrogen infrastructure. A machine learning (ML) model was constructed by analyzing data from relevant literature to evaluate the fracture toughness of steels exposed to hydrogen environments. Seven ML modeling techniques were initially considered with four selected for detailed evaluation based on predictive accuracy. The chosen modeling techniques were k-nearest neighbors (KNN) random forest (RF) gradient boosting (GB) and decision tree regression (DT). The selected models were further evaluated for their predictive accuracy and reliability and the best model was used to perform parametric studies to investigate the impact of relevant parameters on FT. According to the results the KNN model demonstrated reliable predictive performance supported by high R-squared values and low error metrics. Among the variables considered hydrogen pressure and yield strength emerged as the most influential with hydrogen pressure alone accounting for 32% of the variation in FT. The model revealed a distinct trend in FT behavior showing a significant decline at low hydrogen pressures (0–6.9 MPa) and a plateau at higher pressures (>8 MPa) indicating a saturation point. Alloying element contents specifically those of carbon and phosphorus also played a notable role in FT prediction. Additionally the study confirmed that low concentrations of oxygen (

Hydrogen is recognized as a key alternative fuel for mitigating greenhouse-gas emissions owing to its high fuel efficiency and carbon-free combustion. In the stratified charge combustion (SCC) mode ensuring optimal air-fuel mixing in the combustion chamber is crucial because the local equivalence ratio has a dominant influence on combustion characteristics. Therefore this study aims to build a detailed understanding of stratified hydrogen combustion under various local equivalence ratios. Laser-induced breakdown spectroscopy (LIBS) was used to measure the local equivalence ratios in hydrogen jets at different mixture-formation times (MFTs) and laserignition points (LIPs). The results showed that shorter MFTs induced highly stratified mixtures with elevated local equivalence ratios exceeding 2.0 enhancing the laminar flame speed and maximizing the conversion of chemical energy into pressure gain resulting in a representative total heat release over three times higher compared to longer MFTs. Furthermore ignition near the injector tip produced leaner mixtures with equivalence ratios around 0.3 whereas downstream LIPs generated peak local equivalence ratios around 2.0 facilitating rapid flame propagation and increased heat release by 25 %.

Underground Hydrogen Storage (UHS) in depleted oil and gas reservoirs could provide a cost-effective solution to balance seasonal fluctuations in renewable energy generation. However data and knowledge on UHS at subsurface conditions are limited so it is difficult to estimate how effective this type of storage could be. In this study we perform high pressure experiment to measure the effectiveness of cyclic hydrogen (H2) storage in a specimen of Temblor sandstone retrieved from the San Joaquin Basin of California. Our experiment mimics reservoir pressure conditions to measure H2-brine relative permeability and fluid-rock interactions over the course of ten charging and discharging cycles. Initial gas breakthrough occurred at 15 % to 25 % H2 saturation in the specimen with 3 % NaCl brine as the resident fluid. Continuing injecting to 4 pore volumes (PV) of H2 yielded an asymptotic H2 saturation of 38 % to 41 % a level often referred to as the irreducible gas saturation based on two-phase flow. The boundary condition in this study mimics the near wellbore region which experiences bidirectional H2 flow. This bi-directional flow led to evaporative drying of the specimen resulting in 94 % H2 saturation at the end of 10th cycle. This indicates that cyclic flow and evaporative drying can lead to more efficient reservoir storage where a larger fraction of the reservoir porosity is usable to store H2. The produced gas stream consisted of H2 mixed with 8 % to 22 % H2O indicating formation dry-out by evaporation. Meanwhile produced water chemistry indicated calcite and silicate dissolution with calcite sourced from fossil fragments. This led to a loss of cementation and weakened the rock sample. Combined our results indicate dry-out compaction increased H2 saturation rock weakening and permeability loss during cyclic UHS. Overall we anticipate that the combined effects should lead to higher than anticipated UHS storage efficiency per volume of sandstone reservoir rock.

This study compares hydrogen ammonia-hydrogen fuel blends and Jet-A2 fuel in gas turbine combustors using a well-stirred reactor model and validated MATLAB library H2ools to assess flame temperature pollutant generation combustion stability and thermal efficiency. The aim is to address a significant deficiency in existing research which frequently lacks standardized turbine-related comparisons among new zero-carbon fuels. Quantitative data indicate that pure hydrogen attains the maximum adiabatic flame temperature (2552 Kelvin) laminar flame speed (7.73 meters per second) and heat generation (9.02 × 1010 watts per cubic meter) while also demonstrating increased nitrogen oxide emissions (up to 6400 parts per million). Jet-A2 exhibits reduced flame temperatures (2429 Kelvin) and minimal nitrogen oxide emissions (1308 parts per million) whereas a 50% ammonia-hydrogen blend yields the maximum nitrogen oxide output (7022 parts per million) attributable to the nitrogen content in ammonia. Hydrogen generates the minimal nitrogen oxide emissions per unit of energy output—approximately 0.1 grams per kilowatt-hour at a residence time of five milliseconds. This study integrates reactor-level study with a high-fidelity modeling tool providing insights for combustor design fuel selection and emissions control strategies in low-carbon aircraft and power systems.

In this study a novel thermo-economic analysis on a membrane reactor adopted to generate hydrogen coupled to a carbon-dioxide capture system is proposed. Exergy destruction fuel and environmental as well as pur chased equipment costs have been accounted to estimate the cost of hydrogen production in the aforementioned integrated plant. It has been found that the integration of the CO2 capture system with the membrane reactor is responsible for the reduction of the hydrogen production cost by 12 % due to the decrease in environmental penalty cost. In addition the effects of operating parameters (steam-to-carbo ratio and biogas temperature) on the hydrogen production cost are investigated. Hence this work demonstrates that the latter can be decreased by approximately 2 $/kgH2 when steam to carbon ratio increases from 1.5 to 4. The analyses reveal that steam-tocarbo ratio increases exergy destruction cost affecting consequently also the hydrogen production cost. How ever from a thermodynamic point of view it enhances the hydrogen production in the membrane reactor mutually lowering the hydrogen production cost. It has been also estimated that a decrease in the biogas inlet temperature from 450 to 400◦C can reduce the hydrogen production cost by 7 %. This study demonstrates that the fuel cost is a major economic parameter affecting commercialization of hydrogen production while exergy destruction and environmental costs are also significant factors in determining the hydrogen production cost.

This paper presents a techno-economic assessment of adding state-of-the-art solvent-based CO2 capture technologies to greenfield steam methane reforming (SMR)-based H2 production plants and quantifies the impacts of improvements in CO2 capture technology. Current conventional capture technologies are reviewed and future technologies in intermediate and long-term scenarios are analyzed. The results show that adding significantly more efficient solvent-based capture technologies leads to an equivalent rate of natural gas consumption as that of a conventional SMR plant without capture despite capturing most of the CO2 and producing the same amount of H2. Overall improvements in reboiler duty and reductions in capital costs can significantly reduce the cost of H2 production and cost of capture. Particularly the reboiler duty of pre-combustion capture and the capital cost of post-combustion capture have the greatest impact. Based on the results research goals are suggested. Solvent development is recommended—particularly pre-combustion solvents—for reducing the reboiler duties and process schemes to reduce the capital costs. Costlier but more efficient solvents can be considered. A sensitivity analysis using natural gas price shows that technological improvements can reduce the impacts of high natural gas prices. The degree of economic feasibility of CO2 capture increases with improvements to the capture technology.

The Department of Energy’s (DOE) hydrogen and fuel cell activities are presented focussing on key targets and progress. Recent results on the cost durability and performance of fuel cells are discussed along with the status of hydrogen-related technologies and cross-cutting activities. DOE has deployed fuel cells in key early markets including backup power and forklifts. Recent analyses show that fuel cell electric vehicles (FCEVs) are among the most promising options to reduce greenhouse gas emissions and petroleum use. Preliminary analysis also indicates that the total cost of ownership of FCEVs will be comparable to other advanced vehicle and fuel options.

As a zero-emission fuel hydrogen provides a promising solution with significant potential to meet the increasing demand for clean energy alternatives. Hydrogen fueling stations are essential infrastructure for the commercialization of hydrogen fuel cells but the flammability of hydrogen poses safety challenges throughout its lifecycle. Past incidents highlight the need for robust risk assessments starting with comprehensive hazard identification and failure scenario analysis.<br/>This paper proposes using Multilevel Flow Modelling (MFM) a functional modeling method integrated with reasoning capability to support safety evaluations. MFM enables the structured representation of system functions and supports tasks such as fault diagnosis and hazard analysis. Previously applied in nuclear offshore and chemical systems MFM is here used to model a liquid hydrogen fueling station. This paper demonstrates that a developed MFM model identifies failure scenarios related to hydrogen leaks overpressure and operational reliability issues.<br/>This paper conducts a comparison between MFM and traditional methods FMEA and FTA and demonstrates MFM's strength in handling the key challenges rooted from complex failure interactions. Results suggest MFM is complementary to traditional methods and can enhance risk assessments. MFM also contributes to digitalization in safety assessment and monitoring systems ultimately improving hydrogen fueling station reliability and safety.

The EAH team discuss Nataliya’s plan for a green Ukraine including working with the current government on the Hydrogen Road Map. We also get another example of incredible Ukrainian resilience and discuss its importance for the current and future energy system.

The podcast can be found on their website.

On this weeks episode we have Juergen Guldner General Program Manager Hydrogen Technology at BMW. The role of hydrogen in passenger vehicles has for many years been seen as a lonely pursuit for Toyota and Hyundai but the landscape is changing. With the Warrego from startup H2X the Ford H2 pick up the Grenadier/Defender F-Cell from INEOS and now the BMW IX5 it is clear that the race to net zero is far from settled!

In this episode the team dive into the what why and how of the BMW story towards one of the world’s most exciting zero emission vehicle offerings. We explore the details of the vehicle and its performance the reasons why BMW are exploring the potential for hydrogen and why now is the time they feel for hydrogen as a passenger vehicle solution to compliment BEV and finally the How or rather the plan for the testing and broader roll-out of not only the IX5 but also the infrastructure that supports it.

The podcast can be found on their website.

Underground hydrogen storage (UHS) in shale and tight reservoirs offers a promising solution for large-scale energy storage playing a critical role in the transition to a hydrogenbased economy. However the successful deployment of UHS in these low-permeability formations depends on a thorough understanding of the geomechanical and geochemical factors that affect storage integrity injectivity and long-term stability. This review critically examines the geomechanical aspects including stress distribution rock deformation fracture propagation and caprock integrity which govern hydrogen containment under subsurface conditions. Additionally it explores key geochemical challenges such as hydrogen-induced mineral alterations adsorption effects microbial activity and potential reactivity with formation fluids to evaluate their impact on storage feasibility. A comprehensive analysis of experimental studies numerical modeling approaches and field applications is presented to identify knowledge gaps and future research directions.

China’s progress in decarbonizing its transportation particularly vehicle electrification is notable. However the economically effective pathways are underexplored. To find out how much cost is necessary for carbon neutrality for the light-duty vehicle (LDV) sector this study examines twenty decarbonization pathways combining the New Energy and Oil Consumption Credit model and the China-Fleet model. We find that the 2060 zero-greenhouse gas (GHG) emission goal for LDVs is achievable via electrification if the battery pack cost is under CNY483/kWh by 2050. However an extra of CNY8.86 trillion internal subsidies is needed under pessimistic battery cost scenarios (CNY759/kWh in 2050) to eliminate 246 million tonnes of CO2-eq by 2050 ensuring over 80% market penetration of battery electric vehicles (BEVs) in 2050. Moreover the promotion of fuel cell electric vehicles is synergy with BEVs to mitigate the carbon abatement difficulties decreasing up to 34% of the maximum marginal abatement internal investment.

Thermo-catalytic decomposition (TCD) presents a promising pathway for producing hydrogen from natural gas without emitting CO2. This process represents a form of fossil fuel decarbonization where the byproduct rather than being a greenhouse gas is a solid carbon material with potential for commercial value. This study examines the dynamic behavior of TCD showing that carbon formed during the reaction first enhances and later dominates methane decomposition. Three types of carbon materials were employed as starting catalysts. Methane decomposition was continuously monitored using on-line Fourier transform infrared (FT-IR) spectroscopy. The concentration and nature of surface-active sites were determined using a two-step approach: oxygen chemisorption followed by elemental analysis through X-ray photoelectron spectroscopy (XPS). Changes in the morphology and nanostructure of the carbon catalysts both before and after TCD were examined using high-resolution transmission electron microscopy (HRTEM). Thermogravimetric analysis (TGA) was used to study the reactivity of the TCD deposits in relation to the initial catalysts. Partial oxidation altered the structural and surface chemistry of the initial carbon catalysts resulting in activation energies of 69.7–136.7 kJ/mol for methane. The presence of C2 and C3 species doubled methane decomposition (12% → 24%). TCD carbon displayed higher reactivity than the nascent catalysts and sustained long-term activity.

The potential for hydrogen to reshape energy systems has been recognized for over a century. Yet as decarbonization priorities have sharpened in many regions three distinct frontier areas are critical to consider: hydrogen produced from wind; hydrogen produced from nuclear power; and the development of natural hydrogen. These pathways reflect technology and policy changes including a 54% increase in the globally installed wind capacity since 2020 plus new signs of potential emerging in nuclear energy and natural hydrogen. Broadly speaking there are a considerable number of studies covering hydrogen production from electrolysis yet none systematically examine wind- and nuclear-derived hydrogen natural hydrogen or the policies that enable their adoption in key countries. This article highlights international policy and technology developments with a focus on prime movers: Germany China the US and Russia.

Green hydrogen is viewed as a promising pathway to future decarbonized energy systems. However hydrogen production depends on a few critical minerals particularly platinum and iridium. Here we examine how the supply of these minerals is subject to vulnerabilities hidden in interdependent global networks of trade and investment. We develop an index to quantify these vulnerabilities for a combination of a target country an investing country an intermediary country and a commodity. Focusing on the US as the target country for the import of platinum and iridium we show how vulnerability-inducing investing countries changed between 2010 and 2019. We find that the UK is consistently among investing countries that can potentially induce US vulnerabilities via intermediary exporters of platinum and iridium with South Africa being the primary intermediary country. Future research includes incorporating geopolitical factors and technological innovations to move the index closer from potential to real-world vulnerabilities.

This study investigates the effects of varying hydrogen percentages in fuel blends on combustion dynamics engine performance and emissions. Experimental data and analytical equations were used to evaluate combustion parameters such as equivalent lambda in-cylinder pressure heat release rate and ignition timing. The findings demonstrate that hydrogen blending enhances combustion stability shortens ignition delay and shifts peak heat release to be closer to the top dead center (TDC). These changes improve thermal efficiency and reduce cycle-to-cycle variation. Hydrogen blending also significantly lowers carbon dioxide (CO2) and hydrocarbon (HC) emissions particularly at higher blend levels (H0–H5) while lower blends increase nitrogen oxides (NOx) emissions and risk pre-ignition due to advanced start of combustion (SOC). Engine performance improved with an average hydrogen energy contribution of 12% under a constant load. However the optimal hydrogen blending range is crucial to balancing efficiency gains and emission reductions. These results underline the potential of hydrogen as a cleaner additive fuel and the importance of optimizing blend ratios to harness its benefits effectively.

This paper compares national hydrogen (H2) infrastructure plans in Canada the United States (the USA) Singapore and Sri Lanka four countries with varying geographic and economic outlooks but shared targets for reaching net-zero emissions by 2050. It examines how each country approaches hydrogen production pipeline infrastructure policy incentives and international collaboration. Canada focuses on large-scale hydrogen production utilizing natural resources and retrofitted natural gas pipelines supplemented by carbon capture technology. The USA promotes regional hydrogen hubs with federal investment and intersectoral collaboration. Singapore suggests an innovation-based import-dominant strategy featuring hydrogen-compatible infrastructure in a land-constrained region. Sri Lanka maintains an import-facilitated pilot-scale model facilitated by donor funding and foreign collaboration. This study identifies common challenges such as hydrogen embrittlement leakages and infrastructure scalability as well as fundamental differences based on local conditions. Based on these findings strategic frameworks are proposed including scalability adaptability partnership policy architecture digitalization and equity. The findings highlight the importance of localized hydrogen solutions supported by strong international cooperation and international partnerships.

From an environmental standpoint carbon-free energy carriers such as ammonia and hydrogen are essential for future energy systems. However their hightemperature chemical behavior remains insufficiently understood posing challenges for the development and optimization of advanced combustion technologies. Ammonia in particular is globally available and cost-effective especially for energy-intensive industries. The addition of ammonia or hydrogen to methane significantly reduces the accuracy of existing predictive models. Therefore validated and detailed data are urgently needed to enable reliable design and performance predictions. This review highlights the compatibility of ammonia with existing combustion infrastructure facilitating a smoother transition to more sustainable heating methods without the need for entirely new systems. Applications in high-temperature heating processes such as metal processing ceramics and glass production and power generation are of particular interest. This review focuses on the systematic assessment of alternative fuel mixtures comprising ammonia and hydrogen as well as natural gas with particular consideration of existing safety-related parameters and combustion characteristics. Fundamental quantities such as the laminar burning velocity are discussed in the context of their relevance for fuel mixtures and their scalability toward turbulent flame propagation which is of critical importance for industrial burner and reactor design. The influence of fuel composition on ignition limits is examined as these are essential parameters for safety margin definitions and operational boundary conditions. Furthermore flame stability in mixed-fuel systems is addressed to evaluate the practical feasibility and robustness of combustion under varying process conditions. A detailed overview of current diagnostic and analysis methods follows encompassing both pollutant measurement techniques and the detection of key radical species. These diagnostics form the experimental basis for reaction kinetics modeling and mechanism validation. Given the importance of emission formation in combustion systems a dedicated subsection summarizes major emission trends even though a comprehensive treatment would exceed the scope of this review. Thermal radiation effects which are highly relevant for heat transfer and system efficiency in large-scale applications are then reviewed. In parallel current developments in numerical simulation approaches for industrial-scale combustion systems are presented including aspects of model accuracy boundary conditions and computational efficiency. The review also incorporates insights from materials engineering particularly regarding high-temperature material performance corrosion resistance and compatibility with combustion products. Based on these interdisciplinary findings operational strategies for high-temperature furnaces are outlined and selected industrial reference systems are briefly presented. This integrated approach aims to support the design optimization and safe operation of next-generation combustion technologies utilizing carbon-free or low-carbon fuels.

The potential for hydrogen production from heavy oil reservoirs has gained significant attention as a dual-benefit process for both enhanced oil recovery and low-carbon energy generation. This study investigates the technical and economic feasibility of producing hydrogen from heavy oil reservoirs using two primary in situ combustion gasification strategies: cyclic steam/air and CO2 + O2 injection. Through a comprehensive analysis of technical barriers economic drivers and market conditions we assess the hydrogen production potential of each method. While both strategies show promise they face considerable challenges: the high energy demands associated with steam generation in the steam/air strategy and the complexities of CO2 procurement capture and storage in the CO2 + O2 method. The novelty of this work lies in combining CMG-STARS reservoir simulations with GoldSim techno-economic modeling to quantify hydrogen yields production costs and oil–hydrogen revenue trade-offs under realistic field conditions. The analysis reveals that under current technological and market conditions the cost of hydrogen production significantly exceeds the market price rendering the process economically uncompetitive. Furthermore the dominance of oil production as the primary revenue source in both methods limits the economic viability of hydrogen production. Unless substantial advancements are made in technology or a more cost-efficient production strategy is developed hydrogen production from heavy oil reservoirs is unlikely to become commercially viable in the near term. This study provides crucial insights into the challenges that must be addressed for hydrogen production from heavy oil reservoirs to be considered a competitive energy source.

Hydrogen (H2) has the potential to become a cleaner fuel alternative to increase energy mix versatility as part of a low-carbon economy. Geological H2 storage represents a key component of the emerging H2 value chain since large-scale energy generation linked to energy generation and large-scale industrial applications will require significant upscaling of geological storage. Geological H2 storage can take place in both salt domes and bedded salt formations. Bedded salt formations offer a significant advantage for H2 storage over salt domes because of their widespread availability. This research focuses on evaluating the H2 storage potential of the Salado Formation a bedded salt deposit in the Permian Basin of West Texas in the United States. Using data from 3268 well logs this study analyzes an area of 136100 km2 to identify suitable depth and net halite thickness for H2 storage in salt caverns. In addition this work applies a novel geostatistical workflow to quantify the uncertainty in the formation’s storage potential. The H2 working gas potential of the Salado Formation ranges from 0.62 to 17.53 Tsm3 (1.75–49.68 PWh of stored energy) across low-risk to high-risk scenarios with a median potential of 1.19 Tsm3 (3.37 PWh). The counties with the largest storage potential are: Lea in New Mexico and Gaines and Andrews in Texas. These three counties account for more than 75 % of the formation’s total storage potential. This is the first study to quantify uncertainty in H2 storage estimates for a bedded salt formation while providing a detailed breakdown of results by county and 1 km2 grid sections. The findings of this work offer critical insights for developing H2 infrastructure in the Permian Basin. The Permian Basin of West Texas has the potential to become an important hub for H2 production from both natural gas and/or renewable energy. Estimating H2 storage potential is an important contribution to assess the feasibility of the entire H2 value chain in Texas. An interactive map accompanies this work allowing the readers to explore the results visually.

This research evaluates four hydrogen (H2) production technologies via water electrolysis (WE): alkaline water electrolysis (AWE) proton exchange membrane electrolysis (PEME) anion exchange membrane electrolysis (AEME) and solid oxide electrolysis (SOE). Two scoring and ranking methods the MACBETH method and the Pugh decision matrix are utilized for this evaluation. The scoring process employs nine decision criteria: capital expenditure (CAPEX) operating expenditure (OPEX) operating efficiency (SOE) startup time (SuT) environmental impact (EI) technology readiness level (TRL) maintenance requirements (MRs) supply chain challenges (SCCs) and levelized cost of H2 (LCOH). The MACBETH method involves pairwise technology comparisons for each decision criterion using seven qualitative judgment categories which are converted into quantitative scores via M-MACBETH software (Version 3.2.0). The Pugh decision matrix benchmarks WE technologies using a baseline technology—SMR with CCS—and a three-point scoring scale (0 for the baseline +1 for better −1 for worse). Results from both methods indicate AWE as the leading H2 production technology which is followed by AEME PEME and SOE. AWE excels due to its lowest CAPEX and OPEX highest TRL and optimal operational efficiency (at ≈7 bars of pressure) which minimizes LCOH. AEME demonstrates balanced performance across the criteria. While PEME shows advantages in some areas it requires improvements in others. SOE has the most areas needing enhancement. These insights can direct future R&D efforts toward the most promising H2 production technologies to achieve the net-zero goal.

Since the early days of space exploration the efficient production of oxygen and hydrogen via water electrolysis has been a central task for regenerative life-support systems. Water electrolysers are however challenged by the near-absence of buoyancy in microgravity resulting in hindered gas bubble detachment from electrodes and diminished electrolysis efficiencies. Here we show that a commercial neodymium magnet enhances water electrolysis with current density improvements of up to 240% in microgravity by exploiting the magnetic polarization of the electrolyte and the magnetohydrodynamic force. We demonstrate that these interactions enhance gas bubble detachment and displacement through magnetic convection and achieve passive gas–liquid phase separation. Two model magnetoelectrolytic cells a proton-exchange membrane electrolyser and a magnetohydrodynamic drive were designed to leverage these forces and produce oxygen and hydrogen at near-terrestrial efficiencies in microgravity. Overall this work highlights achievable lightweight low-maintenance and energy-efficient phase separation and electrolyser technologies to support future human spaceflight architectures.

Pilot projects to generate hydrogen using proton exchange membrane (PEM) electrolyzers coupled to nuclear power plants (NPPs) began in 2022 with further developments anticipated over the next decade. However the co-location of electrolyzers with NPPs requires an understanding and mitigation of potential risks. In this work we identify and rank failure contributors for a 1 MW PEM electrolysis system. We used fault trees to define the component failure logic parameterized them with generic data and calculated failure frequencies and minimal cut sets for four top events: hydrogen release oxygen release nitrogen release and hydrogen and oxygen mixing. We use risk reduction worth importance measures to determine the most risk-significant components. The results provide insight into primary risk drivers in PEM electrolyzer systems and provide the foundational steps towards quantitative risk assessment of large-scale PEM electrolyzers at NPPs. The results include recommended riskmitigation actions include recommendations about design maintenance and monitoring strategies.

The U.S. produces 10 million metric tons (MMT) of hydrogen annually emitting about 41 MMT of carbon dioxide equivalents (CO2-eqs). With rising hydrogen demand and new emission regulations integrating conventional and novel hydrogen production systems is crucial. This study presents an integrated optimization framework to model diversified hydrogen economies as mixed integer linear programs (MILPs). Moreover the accounting of emissions extends to the system exterior (scope 3) thus providing a comprehensive sustainability assessment. The primary focus of the presented computational example is to analyze the impact of scope 3 emissions particularly material emissions during the construction phase on process system optimization while complying with stringent environmental constraints such as carbon limits. By evaluating emission reduction scenarios the model highlights the role of power purchase agreements (PPAs) from renewable sources and the trade-offs between conventional and novel hydrogen production technologies. The key findings indicate that while electrolyzer-based systems (PEM and AWE) offer potential for emission reduction their high energy demand and significant scope 3 material emissions pose challenges for a complete transition in the near term. The study identified two optimal design configurations: one utilizing PPAs as the primary energy source coupled with the conventional SMR-CCS process and another that combines both conventional (SMR-CCS) and novel hydrogen production technologies under a hybrid purview. Ultimately the findings contribute toward the ongoing efforts to achieve true net-carbon neutrality.