Publications

Hydrogen offers the UK a unique opportunity to deliver on our Net Zero ambitions enabling deep decarbonisation of the parts of the energy system that are challenging to electrify balancing the energy system by providing large scale long duration energy storage and reducing pressure on electricity infrastructure. The UK Government in recognition of the centrality of hydrogen to the future energy system has set a 10GW hydrogen production ambition to be achieved by 2030. This ambition and its supporting policies such as the Hydrogen Business Model the Low Carbon Hydrogen Standard and the Hydrogen Transport and Storage Business Models will unlock private sector investment and kick-start the UK’s hydrogen activity. Encouragingly the UK has a positive track record of deploying low carbon technologies. The  combination of the UK’s world leading policies and incentive schemes alongside a vibrant  Research Development and Innovation (RD&I)  and engineering environment has enabled rapid  deployment of technologies such as offshore wind  and electric vehicles. Yet despite being world leaders  in deployment early opportunities for regional  supply chain growth and job creation were not fully  realised and taken advantage of from inception. The  hydrogen sector is therefore at a tipping point. To  capitalise on the economic opportunity hydrogen  offers the UK must learn from prior technology  deployments and build a strong domestic hydrogen  supply chain in parallel to championing deployment.

Hydrogen is unique amongst low carbon  technologies. It represents a significant economic  opportunity with future hydrogen markets estimated  by the Hydrogen Innovation Initiative to be worth  $8tn and hydrogen technology markets estimated to reach $1tn by 20501 but crucially it is also still a nascent market. Unlike many other low carbon technologies where supply chains are already well established hydrogen supply chains are embryonic meaning that the UK has an opportunity to anchor these supply chains here and establish itself as a global leader.

The UK is well placed to capitalise on this opportunity with favourable geography and geology  that enables us to produce and store hydrogen cost effectively coupled with a strong pipeline of hydrogen projects a stable policy environment that is attractive to investors and a wealth of transferable skills and expertise from the oil and gas industry.

We must ensure that alongside our focus on deployment we are also investing in technology and supply chains. Not only will this deliver exponential economic benefits from the projects supported by Government but it will also enable us to tackle increasing global supply chain constraints. Hydrogen UK estimated in its Economic Impact Assessment that hydrogen could deliver 30000 jobs annually and £7bn of GVA by 2030

It is important to be targeted and strategic in our investment and activities and recognise that hydrogen represents a wide range of technologies and the UK should not expect to lead in every area. Hydrogen UK with the support of the Hydrogen Delivery Council has undertaken analysis of the hydrogen value chain building on UK strengths and identifying the high value items that can deliver significant impact and benefit to the UK. We have also conducted widespread engagement with project developers to identify the barriers to utilising UK technology in projects and with technology developers to identify the challenges and barriers to investing and siting development and manufacturing in the UK.

The report can be found on Hydrogen UK's website.

The current study presents a comprehensive investigation of different energy system configurations for a remote village community in India with entirely renewable electricity. Excess electricity generated by the systems has been stored using two types of energy storage options: lithium-ion batteries and green hydrogen production through the electrolysers. The hybrid renewable energy system (HRES) configurations have been sized by minimising the levelised cost of energy (LCOE). In order to identify the best-performing HRES configuration economic and environmental performance indicators has been analysed using the multi-criteria decision-making method (MCDM) TOPSIS. Among the evaluated system configurations system-1 with a photovoltaic panel (PV) size of 310.24 kW a wind turbine (WT) size of 690 kW a biogas generator (BG) size of 100 kW a battery (BAT) size of 174 kWh an electrolyser (ELEC) size of 150 kW a hydrogen tank (HT) size of 120 kg and a converter (CONV) size of 106.24 kW has been found to be the best-performing system since it provides the highest relative closeness (RC) value (∼0.817) and also has the lowest fuel consumption rate of 2.31 kg/kWh. However system-6 shows the highest amount of CO2 (143.97 kg/year) among all the studied system configurations. Furthermore a detailed technical economic and environmental analysis has been conducted on the optimal HRES configuration. The minimum net present cost (NPC) LCOE and cost of hydrogen (COH) for system 1 has been estimated to be $1960584 $0.44/kWh and $22.3/kg respectively.

In the sixth episode titled Exploring Opportunities for EU-Canada Hydrogen Cooperation our CEO Jorgo Chatzimarkakis discusses with John Risley Charmain and CEO of CFFI Ventures and Stefan Kaufmann former Innovation Commissioner for Green Hydrogen of the German government and now adviser to Thyssenkrupp. In the discussion about hydrogen market and technology's development in Canada and in Germany the businessman and the policy advisor bring two different geographical and expertise perspectives about the topic. Taking into consideration the US' IRA Canada's investments in the hydrogen sector and the European plans regarding H2Global and the Hydrogen Bank our guests compare North America and the EU. They debate over the economic and financial support the industry needs to invest in the green energy transition and the role global cooperation and competition play.

The global population is predicted to increase from ~7.3 billion to over 9 billion people by 2050.Together with rising economic growth this is forecast to result in a 50% increase in fueldemand which will have to be met while reducing carbon dioxide (CO 2 ) emissions by 50–80%to maintain social political energy and climate security. This tension between rising fuel demandand the requirement for rapid global decarbonization highlights the need to fast-track thecoordinated development and deployment of efficient cost-effective renewable technologies forthe production of CO 2 neutral energy. Currently only 20% of global energy is provided aselectricity while 80% is provided as fuel. Hydrogen (H 2) is the most advanced CO 2 -free fuel andprovides a ‘common’ energy currency as it can be produced via a range of renewabletechnologies including photovoltaic (PV) wind wave and biological systems such as microalgaeto power the next generation of H 2 fuel cells. Microalgae production systems for carbon-basedfuel (oil and ethanol) are now at the demonstration scale. This review focuses on evaluating thepotential of microalgal technologies for the commercial production of solar-driven H2 fromwater. It summarizes key global technology drivers the potential and theoretical limits ofmicroalgal H2 production systems emerging strategies to engineer next-generation systems andhow these fit into an evolving H 2 economy.

This paper presents the application of an active energy management strategy to a hybrid system consisting of a proton exchange membrane fuel cell (PEMFC) battery and supercapacitor. The purpose of energy management is to control the battery and supercapacitor states of charge (SOCs) as well as minimizing hydrogen consumption. Energy management should be applied to hybrid systems created in this way to increase efficiency and control working conditions. In this study optimization of an existing model in the literature with different meta-heuristic methods was further examined and results similar to those in the literature were obtained. Ant lion optimizer (ALO) moth-flame optimization (MFO) dragonfly algorithm (DA) sine cosine algorithm (SCA) multi-verse optimizer (MVO) particle swarm optimization (PSO) and whale optimization algorithm (WOA) meta-heuristic algorithms were applied to control the flow of power between sources. The optimization methods were compared in terms of hydrogen consumption and calculation time. Simulation studies were conducted in Matlab/Simulink R2020b (academic license). The contribution of the study is that the optimization methods of ant lion algorithm moth-flame algorithm and sine cosine algorithm were applied to this system for the first time. It was concluded that the most effective method in terms of hydrogen consumption and computational burden was the sine cosine algorithm. In addition the sine cosine algorithm provided better results than similar meta-heuristic algorithms in the literature in terms of hydrogen consumption. At the same time meta-heuristic optimization algorithms and equivalent consumption minimization strategy (ECMS) and classical proportional integral (PI) control strategy were compared as a benchmark study as done in the literature and it was concluded that meta-heuristic algorithms were more effective in terms of hydrogen consumption and computational time.

Interest in more sustainable energy sources has increased rapidly in the maritime industry and ambitious goals have been set for decreasing ship emissions. All industry stakeholders have reacted to this with different approaches including the optimisation of ship power plants the development of new energy-improving sub-systems for existing solutions or the design of entirely novel power plant concepts employing alternative fuels. This paper assesses the feasibility of different ship energy sources for an icebreaking Arctic research ship. To that end possible energy sources are assessed based on fuel infrastructure availability and operational endurance criteria in the operational area of interest. Promising alternatives are analysed further using the evidence-based Strengths Weaknesses Opportunities and Threats (SWOT) method. Then a more thorough investigation with respect to the required fuel tank space life cycle cost and CO2 emissions is implemented. The results demonstrate that marine diesel oil (MDO) is currently still the most convenient solution due to the space operational range and endurance limitations although it is possible to use liquefied natural gas (LNG) and methanol if the ship’s arrangement is radically redesigned which will also lead to reduced emissions and life cycle costs. The use of liquefied hydrogen as the only energy solution for the considered vessel was excluded from the potential options due to low volumetric energy density and high life cycle and capital costs. Even if it is used with MDO for the investigated ship the reduction in CO2 emissions will not be as significant as for LNG and methanol at a much higher capital and lifecycle cost. The advantage of the proposed approach is that unrealistic alternatives are eliminated in a systematic manner before proceeding to detailed techno-economic analysis facilitating the decision-making and investigation of various options in a more holistic manner.

The increasing political momentum advocating for decarbonization efforts has led many governments around the world to unveil national hydrogen strategies. Hydrogen is viewed as a potential enabler of deep decarbonization notably in hard-to-abate sectors such as the industry. A multi-modal hourly resolved linear programming model was developed to assess the infrastructure requirements of a low-carbon supply chain over a large region. It optimizes the deployment of infrastructure from 2025 up to 2050 by assessing four years: 2025 2030 2040 and 2050 and is location agnostic. The considered infrastructure encompasses several technologies for production transmission and storage. Model results illustrate supply chain requirements in Texas and Louisiana. Edge cases considering 100% electrolytic production were analyzed. Results show that by 2050 with an assumed industrial demand of 276 TWh/year Texas and Louisiana would require 62 GW of electrolyzers 102 GW of onshore wind and 32 GW of solar panels. The resulting levelized cost of hydrogen totaled $5.6–6.3/kgH2 in 2025 decreasing to $3.2–3.5/ kgH2 in 2050. Most of the electricity production occurs in Northwest Texas thanks to high capacity factors for both renewable technologies. Hydrogen is produced locally and transmitted through pipelines to demand centers around the Gulf Coast instead of electricity being transmitted for electrolytic production co-located with demand. Large-scale hydrogen storage is highly beneficial in the system to provide buffer between varying electrolytic hydrogen production and constant industrial demand requirements. In a system without low-cost storage liquid and compressed tanks are deployed and there is a significant renewable capacity overbuild to ensure greater electrolyzer capacity factors resulting in higher electricity curtailment. A system under carbon constraint sees the deployment of natural gas-derived hydrogen production. Lax carbon constraint target result in an important reliance on this production method due to its low cost while stricter targets enforce a great share of electrolytic production.

Over 35% of the CO2 associated with cement production comes from operational energy. The cement industry needs alternative fuels to meet its net zero emissions target. This study investigated the influence of hydrogen mixed with biofuels herein designated net zero fuel as an alternative to coal on the clinker quality and performance of cement produced in an industrial cement plant. Scanning electron microscopy X-ray diffraction and nuclear magnetic resonance were coupled to study the clinker mineralogy and polymorphs. Hydration and microstructure development in plain and slag blended cements based on the clinker were compared to commercial cement equivalent. The results revealed a lower alite/belite ratio but a significant proportion of the belite was of the α’H-C2S polymorph. These reacted faster and compensated for the alite/belite ratio. Gel and micro-capillary pores were densified which reduced total porosity and attained comparable strength to the reference plain and blended cement. This study demonstrates that the investigated net zero fuel-produced clinker meets compositional and strength requirements for plain and blended cement providing a feasible pathway for the cement industry to lower its operational carbon significantly.

The transition to hydrogen as a clean energy source is critical for addressing climate change and supporting environmental sustainability. This review provides an accessible summary of general research trends in hydrogen risk assessment methodologies enabling diverse stakeholders including researchers policymakers and industry professionals to gain insights into this field. By examining representative studies across theoretical experimental and simulation-based approaches the review highlights prominent trends and applications within academia and industry. The key focus is on evaluating risks in stationary and transportation applications paying particular attention to hydrogen storage systems transportation infrastructures and energy systems. By offering a concise yet informative summary of hydrogen risk assessment trends this paper aims to serve as a foundational resource for fostering safer and more sustainable hydrogen systems.

This bibliometric study examines the evolution of compressed-hydrogen storage technologies over the last 20 years revealing exponential growth in research and highlighting key advancements in compressed-hydrogen storage materials-based solutions and integration with renewable energy systems. The analysis highlights the pivotal role of composite material tanks and the filament-winding process in revolutionizing storage technology. These innovations have enhanced safety reduced weight and facilitated adaptation for use in automotive and industrial applications. Global research efforts are characterized by substantial international collaboration spearheaded by a small cohort of highly productive researchers and supported by a broader network of contributors. Notwithstanding the ongoing challenges pertaining to safety considerations and cost scalability the potential of hydrogen as a clean energy carrier and its role in balancing renewable energy systems serve to reinforce its importance in the transition to sustainable energy.

Steel production is a highly energy-intensive industry responsible for significant greenhouse gas emissions. Electrification of this sector is challenging making green hydrogen technology a promising alternative. This research performs a thermodynamic analysis of green hydrogen production for steel manufacturing using the direct reduction method. Four solid oxide electrolyzer (SOE) modules replace the traditional reformer to produce 2.88 kg/s of hydrogen gas serving as a reducing agent for iron pellets to yield 30 kg/s of molten steel. These modules are powered by 37801 photovoltaic units. Additionally a thermal storage system utilizing 1342 tons of steel slag stores waste heat from Electric Arc Furnace (EAF) exhaust gases. This stored energy preheats iron scraps charged into the EAF reducing energy consumption by 5%. A life cycle assessment conducted using open LCA software reveals that the global warming potential (GWP) for the entire process with a capacity of 30 kg/s equates to 93 kg of CO2. The study also assesses other environmental impacts such as acidification potential ozone formation fine particle formation and human toxicity. Results indicate that the EAF significantly contributes to global warming and fine particle formation while the direct reduction process notably impacts ozone formation and acidification potential.

Faced with a global consensus on net-zero emissions the use of clean fuels to entirely or substantially replace traditional fuels has emerged as the industry’s primary development direction. Alcohol–hydrogen fuels primarily based on methanol are a renewable and sustainable energy source. This research focuses on energy sustainability and presents a boiler fuel blending system that uses methanol–hydrogen combinations. This system uses the boiler’s waste heat to catalytically decompose methanol into a gas mostly consisting of H2 and CO which is then co-combusted with the original fuel to improve thermal efficiency and lower emissions. A comparative experimental study considering natural gas (NG) blending with hydrogen and dissociated methanol gas (DMG) was carried out in a small natural gas boiler. The results indicate that with a controlled mixed fuel flow of 10 m3/h and an excess air coefficient of 1.2 a 10% hydrogen blending ratio maximizes the boiler’s thermal efficiency (ηt) resulting in a 3.5% increase. This ratio also results in a 1% increase in NOx emissions a 25% decrease in HC emissions and a 5.66% improvement in the equivalent economics (es). Meanwhile blending DMG at 15% increases the boiler’s ηt by 3% reduces NOx emissions by 13.8% and HC emissions by 20% and improves the es by 8.63%. DMG as a partial substitute for natural gas outperforms hydrogen in various aspects. If this technology can be successfully applied and promoted it could pave a new path for the sustainable development of energy in the boiler sector.

Underground Hydrogen Storage (UHS) as an emerging large-scale energy storage technology has shown great promise to ensure energy security with minimized carbon emission. A set of comprehensive UHS site evaluation criteria based on important factors that affect UHS performances is needed for its potential commercialization. This study focuses on the UHS site evaluation of gas mixing. The economic implications of gas mixing between injected hydrogen gas and the residual or cushion gas in a porous storage reservoir is an emerging problem for Underground Hydrogen Storage (UHS). It is already clear that reservoir scale heterogeneity such as formation structure (e.g. formation dip angle) and facies heterogeneity of the sedimentary rock may considerably affect the reservoir-scale mechanical dispersion-induced gas mixing during UHS in high permeability braided-fluvial systems (a common depleted reservoir type for UHS). Following this finding the current study uses the processmimicking modeling software to build synthetic meandering-fluvial reservoir models. Channel dimensions and the presence of abandoned channel facies are set as testing parameters resulting in 4 simulation cases with 200 realizations. Numerical flow simulations are performed on these models to investigate and compare the effects of reservoir and metre-scale heterogeneity on UHS gas mixing. Through simulation channel dimensions (reservoir-scale heterogeneity) are found to affect the uncertainty of produced gas composition due to mixing (represented by the P10-P90 difference of hydrogen fraction in a produced stream) by up to 42%. The presence of abandoned channel facies (metre-scale heterogeneity) depending on their architectural relationship with meander belts could also influence the gas mixing process to a comparable extent (up to 40%). Moreover we show that there is no clear statistical correlation between gas mixing and typical reservoir characterization parameters such as original gas in place (OGIP) average reservoir permeability and the Dykstra-Parsons coefficient. Instead the average time of travel of all reservoir cells calculated from flow diagnostics shows a negative correlation with the level of gas mixing. These results reveal the importance of 3D reservoir architecture analysis (integration of multiple levels of heterogeneity) to UHS site evaluation on gas mixing in depleted gas reservoirs. This study herein provides valuable insights into UHS site evaluation regarding gas mixing.

Source-load output uncertainty poses significant risks to the stable operation of Integrated Energy Systems (IESs). To ensure safe and stable system operation while optimizing the balance among robustness economic viability and low-carbon emissions this paper presents a two-stage robust optimal scheduling model for IESs. This model is supported by hydrogen-containing electric dual-energy conversion characteristics under source-load uncer tainty. Additionally to promote the low-carbon characteristics of the system a ladder carbon trading mechanism is introduced on the source side of the carbon source equipment. Furthermore the integration of hydrogen energy enhances the clean characteristics of source-side multi-energy coupling. The proposed utilization mode Power-to-Hydrogen Hydrogen-to-Power Hydrogen Energy Storage and Hydrogen Load (P2H-H2P-HES-HL) allows for bidirectional conversion thereby increasing the flexibility and responsiveness of overall system scheduling. Finally to ensure that the model closely reflects actual operational and scheduling conditions a twophase robust approach is employed to address source-load uncertainties. This approach is solved iteratively using the linear transformation of the Karush-Kuhn-Tucker (KKT) conditions and the Column-and-Constraint Gener ation (C&CG) algorithm. The results demonstrate that the proposed model significantly enhances the scheduling capability of the system in coping with uncertainty thereby effectively ensuring its flexibility and security

A thermodynamic assessment using Gibbs free energy minimization to explore the potential of winery wastewater steam reforming (WWWSR) as a technique to treat water while simultaneously producing renewable hydrogen was conducted for the first time. This assessment focused on four types of reactors: a conventional reactor (CR) a sorption-enhanced reactor (SER) with CO2 capture a membrane reactor (MR) with H2 removal and a sorption-enhanced membrane reactor (SEMR) that combines features of both the SER and MR. The effects on WWWSR of temperature pressure water content in the feed composition of winery wastewater (WWW) sorbent to feed ratio (SFR) and the split fraction of H2 in the membrane were studied. For the CR SER MR and SEMR the study showed that low pressures and high water content in the reactor inlet resulted in higher hydrogen production. Considering a representative WWW composition with a water content of 75 wt% in the feed it was shown that the CR needed to operate at extremely high temperatures (over 600 ◦C) to maximize H2 yield while producing less hydrogen than its counterparts. In contrast the MR and SER achieved higher hydrogen production at optimal temperatures around 500 ◦C while the SEMR performed even better producing more hydrogen at just 400 ◦C. Moreover the organic composition of the feed stream did not significantly influence the optimal temperature and pressure conditions for maximizing hydrogen production. However wastewater with a higher fraction of sugars generated more hydrogen whereas wastewater with a higher fraction of acetic acid produced less hydrogen via the steam reforming reaction. Notably a novel energy analysis was conducted demonstrating that the energy self-sufficiency of this process changed drastically when different reactor types were considered. Only the MR with a high degree of hydrogen separation in the membrane the SER with optimal quantities of CO2-capturing sorbent and the SEMR can be energetically selfsufficient as they produce enough hydrogen to offset the energy expenditure associated with steam reforming

The renewable hydrogen economy is recognized as an integral solution for decarbonizing energy sectors. However high costs have hindered widespread deployment. One promising way of reducing the costs is optimization. Optimization generally involves finding the configuration of the renewable generation and hydrogen system components that maximizes return on investment. Previous studies have included many aspects into their optimisations including technical parameters and different costs/socio-economic objective functions however there is no clear best-practice framework for model development. To address these gaps this critical review examines the latest development in renewable hydrogen microgrid models and summarises the best modeling practice. The findings show that advances in machine learning integration are improving solar electricity generation forecasting hydrogen system simulations and load profile development particularly in data-scarce regions. Additionally it is important to account for electrolyzer and fuel cell dynamics rather than utilizing fixed performance values. This review also demonstrates that typical meteorological year datasets are better for modeling solar irradiation than first-principle calculations. The practicability of socio-economic objective functions is also assessed proposing that the more comprehensive Levelized Value Addition (LVA) is best suited for inclusion into models. Best practices for creating load profiles in regions like the Global South are discussed along with an evaluation of AI-based and traditional optimization methods and software tools. Finally a new evidence-based multi-criteria decision-making framework integrated with machine learning insights is proposed to guide decision-makers in selecting optimal solutions based on multiple attributes offering a more comprehensive and adaptive approach to renewable hydrogen system optimization.

Hydrogen is a crucial energy carrier for the Clean Energy Sustainable Development Goals and the just transition to low/zero-carbon energy. As a top CO2-emitting country hydrogen (especially green hydrogen) production in South Africa has gained momentum due to the availability of resources such as solar energy land wind energy platinum group metals (as catalysts for electrolysers) and water. However the demand for green hydrogen in South Africa is insignificant which implies that the majority of the production must be exported. Despite the positive developments there are unclear matters such as dependence on the national electricity grid for green hydrogen production and the cost of transporting it to Asian and European markets. Hence this study aims to explore opportunities for economic expansion for sustainable production transportation storage and utilisation of green hydrogen produced in South Africa. This paper uses a thematic literature review methodology. The key findings are that the available renewable energy sources incentivizing the green economy carbon taxation and increasing the demand for green hydrogen in South Africa and Africa could decrease the cost of hydrogen from 3.54 to 1.40 €/kgH2 and thus stimulate its production usage and export. The appeal of green hydrogen lies in diversifying products to green hydrogen as an energy carrier clean electricity synthetic fuels green ammonia and methanol green fertilizers and green steel production with the principal purpose of significant energy decarbonisation and economic and foreign earnings. These findings are expected to drive the African hydrogen revolution in agreement with the AU 2063 agenda.

A lot of countries have recently published updated hydrogen strategies with many of them increasing and renewing their commitment. In parallel corresponding policy mechanisms are increasingly coming into focus with the first ones already having awarded funding contracts to projects and construction being underway. However these policies are usually translated from renewable energy policy without considering the specific risks and uncertainties spillovers and positive externality of operating grid-conducive electrolyzers in electricity grids which are increasingly subjected to electricity supply volatility from renewables. This article details how different aspects of a dedicated hydrogen policy can address the technology’s specific issues from an economic perspective namely funding provision market and technology risk mitigation and the complex relationship with further actors in electricity markets. Results show that compared to renewable energy policy mechanisms need to emphasize the input side more strongly as price risks and intermittency from electricity markets are more prominent than from hydrogen markets. Also it proposes a targeted mechanism to capture the positive externality of mitigating excess electricity in the grid while keeping investment security high. Economic policy should consider such approaches before scaling support and avoiding the design shortcomings experienced with early RE policy.

This paper focuses on the critical role of long-duration energy storage (LDES) technologies in facilitating renewable energy integration and achieving carbon neutrality. It presents a systematic review of four primary categories: mechanical energy storage chemical energy storage electrochemical energy storage and thermal energy storage. The study begins by analyzing the technical advantages and geographical constraints of pumped hydro energy storage (PHES) and compressed air energy storage (CAES) in high-capacity applications. It then explores the potential of hydrogen and synthetic fuels for long-duration clean energy storage. The section on electrochemical energy storage highlights the high energy density and flexible scalability of lithium-ion batteries and redox flow batteries. Finally the paper evaluates innovative advancements in large-scale thermal energy storage technologies including sensible heat storage latent heat storage and thermochemical heat storage. By comparing the performance metrics application scenarios and development prospects of various energy storage technologies this work provides theoretical support and practical insights for maximizing renewable energy utilization and driving the sustainable transformation of global energy systems.

Ammonia is a versatile energy carrier without carbon emissions that can be used for power generation. In this article a techno-economic analysis has been done to predict the levelized cost of electricity production using gas turbines with clean fuel in Iran. In the technical discussion the analysis of different scenarios of ammonia and hydrogen fuel composition ratio was done and by keeping the turbine inlet temperature to the same gas turbine as the SGT5-2000E turbine the output power in different fuel ratios is around 192.8 to 229.0 MW was variable and reached the maximum value in some proportions. Also in the economic discussion the effects of fuel cost and interest rate parameters were investigated sensitivity analysis was performed on different combined ratios of ammonia and hydrogen in fuel and an economic analysis of the ideal ratio was conducted. The price of ammonia fuel was calculated from 222 $/ton to 2000 $/ton and the levelized cost of electricity production changed from 91.7 $/MWh to 673.4 $/MWh. Additionally an economic comparison was made between the utilization of ammonia-hydrogen and natural gas fuels. This alternative fuel can be a promising way to produce power without carbon emissions and suitable storage for renewables.

This paper presents a thorough initial evaluation of hydrogen gaseous storage and pipeline infrastructure emphasizing health and safety protocols as well as capacity considerations pertinent to industrial applications. As hydrogen increasingly establishes itself as a vital energy vector within the transition towards low-carbon energy systems the formulation of effective storage and transportation solutions becomes imperative. The investigation delves into the applications and technologies associated with hydrogen storage specifically concentrating on compressed hydrogen gas storage elucidating the principles underlying hydrogen compression and the diverse categories of hydrogen storage tanks including pressure vessels specifically designed for gaseous hydrogen containment. Critical factors concerning hydrogen gas pipelines are scrutinized accompanied by a review of appropriate compression apparatus types of compressors and particular pipeline specifications necessary for the transport of both hydrogen and oxygen generated by electrolysers. The significance of health and safety in hydrogen systems is underscored due to the flammable nature and high diffusivity of hydrogen. This paper defines the recommended health and safety protocols for hydrogen storage and pipeline operations alongside exemplary practices for the effective implementation of these protocols across various storage and pipeline configurations. Moreover it investigates the function of oxygen transport pipelines and the applications of oxygen produced from electrolysers considering the interconnected safety standards governing hydrogen and oxygen infrastructure. The conclusions drawn from this study facilitate the advancement of secure and efficient hydrogen storage and pipeline systems thereby furthering the overarching aim of scalable hydrogen energy deployment within both energy and industrial sectors.

We investigate the challenges and options for repurposing existing natural gas pipelines for hydrogen transportation. Challenges of re-purposing are mainly related to safety and due to the risk of hydrogen embrittlement of pipeline steels and the smaller molecular size of the gas. From an economic perspective the lower volumetric energy density of hydrogen compared to natural gas is a challenge. We investigate three pipeline repurposing options in depth: a) no modification to the pipeline but enhanced maintenance b) use of gaseous inhibitors and c) the pipe-in-pipe approach. The levelized costs of transportation of these options are compared for the case of the German Norddeutsche Erdgasleitung (NEL) pipeline. We find a similar cost range for all three options. This indicates that other criteria such as the sunk costs public acceptance and consumer requirements are likely to shape the decision making for gas pipeline repurposing.

The future of energy is of global concern with hydrogen emerging as a potential solution for sustainable energy development. This paper provides a comprehensive analysis of the current hydrogen energy landscape its potential role in a decarbonized future and the hurdles that need to be overcome for its wider implementation. The first elucidates the opportunities hydrogen energy presents including its potential for decarbonizing various sectors in addition addresses the challenges that stand in the way of hydrogen energy large-scale adoption. The obtained results provide a comprehensive overview of the hydrogen energy horizon emphasizing the need to balance opportunities and challenges for its successful integration into the global energy landscape. It highlights the importance of continued research development and collaboration across sectors to realize the full potential of hydrogen as a sustainable and low-carbon energy carrier.

Proton exchange membrane electrolyzer cell (PEMEC) will play a central role in future power-to-H2 plants. Current research focuses on the materials and operation parameters. Setting up experiments to explore operational accident scenarios about safety feasibility is not always practical. This paper focuses on building mathematical and prediction models of hydrogen and oxygen mixing scenarios of PEMEC. A mathematical model of the PEMEC device was customized in the Aspen Custom Model (ACM) software and integrated various critical Physico-chemical phenomena as the original data set for the prediction model. The results of the mathematical simulation verified the experimental results. The prediction model proposes an artificial neural network (ANN) framework to predict component distribution in the gas stream to prevent hydrogen-oxygen explosion scenarios. The presented approach by training ANN to 1000 sets of hydrogen-oxygen mixing simulation data from ACM is applicable to bypass tedious and non-smooth systems of equations for PEMEC.

This paper reports on the experimental data analysis and numerical results carried out by algorithms in order to meet the provisions of Industry 4.0 in the field of research of Solid Oxide Fuel Cell/Electrolyzer. A performance mapping of the analyzed SOFC/SOE systems is developed in order to enhance system efficiency when it is fed by biofuels. The analyses concern the main operative parameters such as pressure temperature fuel compositions and other main system parameters such as fuel and oxidant utilization factors and the recirculation of anode exhaust stream gas.