Publications

The type IV hydrogen storage tank with a polymer liner is a promising storage solution for fuel cell electric vehicles (FCEVs). The polymer liner reduces the weight and improves the storage density of tanks. However hydrogen commonly permeates through the liner especially at high pressure. If there is rapid decompression damage may occur due to the internal hydrogen concentration as the concentration inside creates the pressure difference. Thus a comprehensive understanding of the decompression damage is significant for the development of a suitable liner material and the commercialization of the type IV hydrogen storage tank. This study discusses the decompression damage mechanism of the polymer liner which includes damage characterizations and evaluations influential factors and damage prediction. Finally some future research directions are proposed to further investigate and optimize tanks.

This paper navigates the critical role of hydrogen in catalyzing a sustainable energy transformation. This review delves into hydrogen production methodologies spotlighting green and blue hydrogen as pivotal for future energy systems because of their potential to significantly reduce greenhouse gas emissions. Through a comprehensive literature review and a bibliometric analysis this study underscores the importance of technological advancements policy support and market incentives in promoting hydrogen as a key energy vector. It also explores the necessity of expanding renewable energy sources and international cooperation to secure a sustainable low-carbon future. The analysis highlights the importance of scalable and cost-effective hydrogen production methods such as solar-thermochemical and photo-electrochemical processes and addresses the challenges posed by resource availability and geopolitical factors in establishing a hydrogen economy. This paper serves as a guide for policy and innovation toward achieving global sustainability goals illustrating the essential role of hydrogen in the energy transition.

The ambitious targets set by the International Maritime Organization for reducing greenhouse gas emissions from shipping require radical actions by all relevant stakeholders. In this context the interest in high efficiency and low emissions (even zero in the case of hydrogen) fuel cell technology for maritime applications has been rising during the last decade pushing the research developed by academia and industries. This paper aims to present a comparative review of the fuel cell systems suitable for the maritime field focusing on PEMFC and SOFC technologies. This choice is due to the spread of these fuel cell types concerning the other ones in the maritime field. The following issues are analyzed in detail: (i) the main characteristics of fuel cell systems; (ii) the available technology suppliers; (iii) international policies for fuel cells onboard ships; (iv) past and ongoing projects at the international level that aim to assess fuel cell applications in the maritime industry; (v) the possibility to apply fuel cell systems on different ship types. This review aims to be a reference and a guide to state both the limitations and the developing potential of fuel cell systems for different maritime applications.

Though being attractive on railway decarbonisation for regional lines excessive cost caused by immature hydrogen supply chain is one of the significant hurdles for promoting hydrogen traction to rolling stocks. Therefore we conduct bespoke research on the UK’s hydrogen supply chain for railway concentrating on hydrogen transportation. Firstly a map for the planned hydrogen production plants and potential hydrogen lines is developed with the location capacity and usage. A spatially explicit model for the hydrogen supply chain is then introduced which optimises the existing grid-based methodology on accuracy and applicability. Compressed hydrogen at three pressures and liquid hydrogen are considered as the mediums incorporating by road and rail transport. Furthermore three scenarios for hydrogen rail penetration are simulated respectively to discuss the levelised cost and the most suitable national transport network. The results show that the developed model with mix-integer linear programming (MILP) can well design the UK’s hydrogen distribution for railway traction. Moreover the hydrogen transport medium and vehicle should adjust to suit for different era where the penetration of hydrogen traction varies. The levelised cost of hydrogen (LCOH) decreases from 6.13 £/kg to 5.13 £/kg on average from the conservative scenario to the radical scenario. Applying different transport combinations according to the specific situation can satisfy the demand while reducing cost for multi-supplier and multitargeting hydrogen transport.

Reduction of the carbon dioxide emissions is a vital important environmental element in achieving the global climate neutrality. The integration of renewables and the Carbon Capture Utilization and Storage (CCUS) technologies is seen as an important pillar for overall decarbonization. This work presents several innovative concepts in which the biogas reforming process in integrated with pre- and post-combustion CO2 capture using membranes for green hydrogen production. The assessment evaluates the most relevant techno-economic and environmental performances for 100 MWth green hydrogen plant capacity. Several biogas reforming designs with and without CO2 capture capability were evaluated. In respect to the CO2 capture rate several pre- and postcombustion systems provided decarbonization yields between 55% up to 99%. The results show that the decarbonized membrane-based green hydrogen production shows attractive performances such as high energy efficiency (55–60%) reduced energy and cost penalties for CO2 capture (3.6–15.5 net efficiency points depending on the carbon capture rate) low specific CO2 emissions at system level (down to 2 kg/MWh green hydrogen) and overall negative carbon emission for whole biogas value chain (up to − 468 kg/MWh green hydrogen). This analysis clearly shows how the integration of renewables with CCUS technologies can deliver applications with negative CO2 emissions for climate neutrality.

Electrolysis of water to generate hydrogen fuel is an attractiverenewable energy storage technology. However grid-scale fresh-water electrolysis would put a heavy strain on vital water re-sources. Developing cheap electrocatalysts and electrodes that cansustain seawater splitting without chloride corrosion could ad-dress the water scarcity issue. Here we present a multilayer anodeconsisting of a nickel–iron hydroxide (NiFe) electrocatalyst layeruniformly coated on a nickel sulfide (NiSx) layer formed on porousNi foam (NiFe/NiSx-Ni) affording superior catalytic activity andcorrosion resistance in solar-driven alkaline seawater electrolysisoperating at industrially required current densities (0.4 to 1 A/cm2)over 1000 h. A continuous highly oxygen evolution reaction-active NiFe electrocatalyst layer drawing anodic currents towardwater oxidation and an in situ-generated polyatomic sulfate andcarbonate-rich passivating layers formed in the anode are respon-sible for chloride repelling and superior corrosion resistance of thesalty-water-splitting anode.

The transition to cleaner energy sources particularly in hard-to-abate industrial sectors often requires the gradual integration of new technologies. Hydrogen crucial for decarbonization is explored as a fuel in blended combustions. Blending or replacing fuels impacts combustion stability and heat transfer rates due to differing densities. An extensive literature review examines blended combustion focusing on hydrogen/methane mixtures. While industrial burners claim to accommodate up to 20% hydrogen theoretical support is lacking. A novel thermodynamic analysis methodology is introduced evaluating methane/hydrogen combustion using the Wobbe index. The findings highlight practical limitations beyond 25% hydrogen volume necessitating a shift to “totally hydrogen” combustion. Blended combustion can be proposed as a medium-term strategy acknowledging hydrogen’s limited penetration. Higher percentages require burner and infrastructure redesign.

From navigating the rainbow of colours to the lack of consensus in establishing a common taxonomy the labelling and definition of green or renewable hydrogen presents a growing challenge. In this context carbon taxonomy is understood through five critical aspects: carbon intensity temporal and geographical correlation additionality of renewable energy generation and different system boundaries in Life Cycle Assessment (LCA). This study examines the effect of carbon taxonomy on the design and operation of Power-to-Gas (PtG) systems for renewable hydrogen production including the electricity supply portfolio via Power Purchase Agreements (PPA) and grid-connected electrolysis. To this end an optimisation model combining energy system modelling and LCA is developed and then applied to a case study in the Japanese context. The importance of the PPA portfolio in securing cheap and low-carbon electricity to produce hydrogen is addressed. To support this evaluation process an eco-efficiency metric is introduced and proved to be a comprehensive tool for evaluating renewable hydrogen production. Regarding carbon taxonomies the findings emphasize additionality as the key determinant factor followed by temporal correlation and the definition of carbon intensity thresholds. The application of a cradle-togate LCA boundary influenced the cabron intensity accounting playing an unexpected role on the design and optimal PtG dispatch strategy.

This article presents the concept of green transformation of the coal mining sector. Pump stations that belong to Spółka Restrukturyzacji Kopal´n S.A. (SRK S.A. Bytom Poland) pump out approximately 100 million m3 of mine water annually. These pump stations protect neighboring mines and lower-lying areas from flooding and protect subsurface aquifers from contamination. The largest cost component of maintaining a pumping station is the expenditure for purchasing electricity. Investment towards renewable energy sources will reduce the environmental footprint of pumping station operation by reducing greenhouse gas emissions. The concept of liquidation of an exemplary mining site in the context of a circular economy by proposing the development/revitalization of a coal mine site is presented. This concept involves the construction of a complex consisting of photovoltaic farms combined with efficient energy storage in the form of green hydrogen produced by water electrolysis. For this purpose the potential of liquidated mining sites will be utilized including the use of pumped mine wastewater. This article is conceptual. In order to reach the stated objective a body of literature and legal regulations was analyzed and an empirical study was conducted. Various scenarios for the operation of mine pumping stations have been proposed. The options presented provide full or nearly full energy self-sufficiency of the proposed pumping station operation concept. The effect of applying any option for upgrading the pumping station could result in the creation of jobs that are alternatives to mining jobs and a guarantee of efficient asset management.

This report lays out roadmaps for the nine technology families identified in the UK Hydrogen Innovation Opportunity. The content in these roadmaps has been developed through a combination of extensive industrial engagement and aggregation of existing sector and technology roadmaps. This document also signposts to reports that highlight innovation challenges and opportunities for two underpinning technology families - materials and digital. The technology roadmaps in this document each include the following:

♦ UK and global market forecast for 2030 and 2050 for the respective technology family.

♦ Key technologies that make up the technology family.

♦ The associated innovation opportunities associated with each key technology together with development and industrialisation timelines and the sectors that will benefit from the innovation.

The list of innovation opportunities on each roadmap is by no means exhaustive but they are a sample that were selected because they highlighted some key innovation actions for the UK. To make this selection a range of factors were considered including global and UK economic demand the UK political imperative and UK potential to win market share. The development and industrialisation timelines are recommendations only and do not signify that this work is already planned or funded.

This report can also be downloaded for free on the Hydrogen Innovation Initiative website.

In addition to the promotion of pumped storage and electricity storage batteries the minimum use of inexpensive thermal power generation for the regulation of power in Japan and other countries is being considered as a supply-demand stabilization device with the expected widespread introduction of renewable energy by 2050. Therefore this study analyzed the economics related to the introduction of solid oxide fuel cell combined cycle using liquefied natural gas as a regulating power. The commercialization of recovered CO2 has been investigated for reducing the overall system operating costs. This study investigated a combined solid oxide fuel cell CO2 utilization system that employed green hydrogen methanolation and methanation to facilitate the use of the CO2 captured by the system. CO2 was separated from the exhaust gas of the system captured stored and used through methanation and methanolation. Consequently the synthesized methane was used for solid oxide fuel cell power generation and the synthesized methanol was sold. The discounted cash flow method was employed to evaluate the economic performance of the proposed system. At a unit price of 0.7–0.9 USD/kWh for electricity sold rated outputs of 1250 and 390 MW for solid oxide fuel cell combined cycle and photovoltaics respectively carbon capture and storage equipment cost of 800 USD/kWh and discount rate of 0.3 % the simple integrated payback period was obtained as 9 years whereas the dynamic payback period was 11–30 years. Consequently the economic feasibility of the proposed system was demonstrated.

In this study the Bald Eagle Search Algorithm performed hydrogen consumption and battery cycle optimization of a fuel cell electric vehicle. To save time and cost the digital vehicle model created in Matlab/Simulink and validated with real-world driving data is the main platform of the optimization study. The digital vehicle model was run with the minimum and maximum battery charge states determined by the Bald Eagle Search Algorithm and hydrogen consumption and battery cycle values were obtained. By using the algorithm and digital vehicle model together hydrogen consumption was minimized and range was increased. It was aimed to extend the life of the parts by considering the battery cycle. At the same time the number of battery packs was included in the optimization and its effect on consumption was investigated. According to the study results the total hydrogen consumption of the fuel cell electric vehicle decreased by 57.8% in the hybrid driving condition 23.3% with two battery packs and 36.27% with three battery packs in the constant speed driving condition.

Hydrogen-fueled internal combustion engines are a promising CO2-free and zero-impact emission alternative to battery or fuel cell electric powertrains. Advantages include long service life robustness against fuel impurities and a strong infrastructural base with existing production lines and workshop stations. In order to make hydrogen engines harmless in terms of pollutant emissions as well NOX emissions at the tailpipe must be reduced as low as the zero-impact emission level. Here the application of selective catalytic reduction (SCR) catalysts is a promising solution that can be rapidly adopted from conventional diesel engines. This paper therefore investigates the influences of the hydrogen concentration in the raw exhaust gas of the NO2/NOX ratio and of the space velocity on the performance of two different SCR technologies. The results show that both types of SCR copper-zeolite and vanadium-based have their advantages and drawbacks. Copper-based SCR catalysts have an early light-off temperature and reach maximum efficiencies of up to >99%. On the other hand vanadium systems promise almost no secondary N2O emissions. As a result we combined both approaches to create a superior solution with high efficiency and lowest secondary emissions.

The diffusive process between hydrogen (H2) and cushion gas affects the purity of H2 stored in the subsurface porous media. It is essential to understand the diffusive mass transfer and its impact on the migration of H2. Carbon dioxide (CO2) serves as a promising option for cushion gas. However due to experimental challenges there has been limited research conducted to quantify the diffusion between H2 and CO2 under reservoir conditions. For the first time we quantitatively measured the horizontal diffusive process between H2 and CO2 without convection interference in a high-pressure optical cell. The Raman spectroscopy is used to monitor the diffusive process in real-time and the diffusion coefficient is determined based on the measured concentration profiles. We showed that the Fick’s second law with a constant diffusion coefficient describes adequately the observed diffusive process. The resulting diffusion coefficient scales linearly with the reciprocal viscosity of CO2. Based on the measured diffusion coefficient we conducted a numerical study at field-scale. Results suggest that the dispersive mixing plays a role in the purity of produced H2.

The coupling of photovoltaics (PVs) and PEM water electrolyzers (PEMWE) is a promising method for generating hydrogen from a renewable energy source. While direct coupling is feasible the variability of solar radiation presents challenges in efcient sizing. This study proposes an innovative energy management strategy that ensures a stable hydrogen production rate even with fuctuating solar irradiation. By integrating battery-assisted hydrogen production this approach allows for decentralized grid-independent renewable energy systems mitigating instability from PV intermittency. The system utilizes electrochemical storage to absorb excess energy during periods of low or very high irradiation which falls outside the electrolyzer’s optimal power input range. This stored energy then supports the PV system ensuring the electrolyzer operates near its nominal capacity and optimizing its lifetime. The system achieves an efciency of 7.78 to 8.81% at low current density region and 6.6% at high current density in converting solar energy into hydrogen.

This study presents an innovative home energy management system (HEMS) that incorporates PV WTs and hybrid backup storage systems including a hydrogen storage system (HSS) a battery energy storage system (BESS) and electric vehicles (EVs) with vehicle-to-home (V2H) technology. The research conducted in Liaoning Province China evaluates the performance of the HEMS under various demand response (DR) scenarios aiming to enhance resilience efficiency and energy independence in green buildings. Four DR scenarios were analyzed: No DR 20% DR 30% DR and 40% DR. The findings indicate that implementing DR programs significantly reduces peak load and operating costs. The 40% DR scenario achieved the lowest cumulative operating cost of $749.09 reflecting a 2.34% reduction compared with the $767.07 cost in the No DR scenario. The integration of backup systems particularly batteries and fuel cells (FCs) effectively managed energy supply ensuring continuous power availability. The system maintained a low loss of power supply probability (LPSP) indicating high reliability. Advanced optimization techniques particularly the reptile search algorithm (RSA) are crucial in enhancing system performance and efficiency. These results underscore the potential of hybrid backup storage systems with V2H technology to enhance energy independence and sustainability in residential energy management.

The transition to sustainable energy has ushered in the era of electrofuels (e-fuels) which are synthesised using electricity from renewable sources water and CO2 as a sustainable alternative to fossil fuels. This paper presents a systematic review of the techno-economic (TEA) and life cycle assessments (LCAs) of e-fuel production. We critically evaluate advancements in production technologies economic feasibility environmental implications and potential societal impacts. Our findings indicate that while e-fuels offer a promising solution to reduce carbon emissions their economic viability depends on optimising production processes and reducing input material costs. The LCA highlights the necessity of using renewable energy for hydrogen production to ensure the genuine sustainability of e-fuels. This review also identifies knowledge gaps suggesting areas for future research and policy intervention. As the world moves toward a greener future understanding the holistic implications of e-fuels becomes paramount. This review aims to provide a comprehensive overview to guide stakeholders in their decision-making processes.

Conventional methods of parameterizing fuel cell hybrid power systems (FCHPS) often rely on engineering experience which leads to problems such as increased economic costs and excessive weight of the system. These shortcomings limit the performance of FCHPS in real-world applications. To address these issues this paper proposes a novel method for optimizing the parameter configuration of FCHPS. First the power and energy requirements of the vehicle are determined through traction calculations and a real-time energy management strategy is used to ensure efficient power distribution. On this basis a multi-objective parameter configuration optimization model is developed which comprehensively considers economic cost and system weight and uses a particle swarm optimization (PSO) algorithm to determine the optimal configuration of each power source. The optimization results show that the system economic cost is reduced by 8.76% and 18.05% and the weight is reduced by 11.47% and 9.13% respectively compared with the initial configuration. These results verify the effectiveness of the proposed optimization strategy and demonstrate its potential to improve the overall performance of the FCHPS.

The introduction of several alternative marine fuels is considered an important strategy for maritime decarbonization. These alternative marine fuels include liquefied natural gas (LNG) liquefied biogas (LBG) hydrogen ammonia methanol ethanol hydrotreated vegetable oil (HVO) etc. In some studies nuclear power and electricity are also included in the scope of alternative fuels for merchant ships. However the operation of alternative-fuel-powered ships has some special risks such as fuel spills vapor dispersion and fuel pool fires. The existing international legal framework does not address these risks sufficiently. This research adopts the method of legal analysis to examine the existing international legal regime for regulating the development of alternative-fuel-powered ships. From a critical perspective it evaluates and predicts the consequences of these policies together with their shortcomings. Also this research explores the potential solutions and countermeasures that might be feasible to deal with the special marine environmental risks posed by alternative-fuel-powered ships in the future.

Volatile electricity prices have raised concerns about the economic feasibility of wind projects in Finland. This study assesses the economic viability and optimal operational strategies for integrating wind-powered green hydrogen production systems. Utilizing modeling and optimization this research evaluates various wind farms in Western Finland over electricity market scenarios from 2019 to 2022 with forecasts extending to 2030. Key economic metrics considered include internal rate of return future value net present value (NPV) and the levelized cost of hydrogen (LCOH). Results indicate that integration of hydrogen production with wind farms shows economic benefits over standalone wind projects potentially reducing LCOH to €2.0/kgH2 by 2030 in regular and low electricity price scenarios and to as low as €0.6/kgH2 in high-price scenarios. The wind farm with the highest capacity factor achieves 47% reductions in LCOH and 22% increases in NPV underscoring the importance of strategic site selection and operational flexibility.

Hydrogen is the energy vector that will lead us toward a more sustainable future. It could be the fuel of both fuel cells and internal combustion engines. Internal combustion engines are today the only motors characterized by high reliability duration and specific power and low cost per power unit. The most immediate solution for the near future could be the application of hydrogen as a fuel in modern internal combustion engines. This solution has advantages and disadvantages: specific physical chemical and operational properties of hydrogen require attention. Hydrogen is the only fuel that could potentially produce no carbon carbon monoxide and carbon dioxide emissions. It also allows high engine efficiency and low nitrogen oxide emissions. Hydrogen has wide flammability limits and a high flame propagation rate which provide a stable combustion process for lean and very lean mixtures. Near the stoichiometric air–fuel ratio hydrogen-fueled engines exhibit abnormal combustions (backfire pre-ignition detonation) the suppression of which has proven to be quite challenging. Pre-ignition due to hot spots in or around the spark plug can be avoided by adopting a cooled or unconventional ignition system (such as corona discharge): the latter also ensures the ignition of highly diluted hydrogen–air mixtures. It is worth noting that to correctly reproduce the hydrogen ignition and combustion processes in an ICE with the risks related to abnormal combustion 3D CFD simulations can be of great help. It is necessary to model the injection process correctly and then the formation of the mixture and therefore the combustion process. It is very complex to model hydrogen gas injection due to the high velocity of the gas in such jets. Experimental tests on hydrogen gas injection are many but never conclusive. It is necessary to have a deep knowledge of the gas injection phenomenon to correctly design the right injector for a specific engine. Furthermore correlations are needed in the CFD code to predict the laminar flame velocity of hydrogen–air mixtures and the autoignition time. In the literature experimental data are scarce on air–hydrogen mixtures particularly for engine-type conditions because they are complicated by flame instability at pressures similar to those of an engine. The flame velocity exhibits a non-monotonous behavior with respect to the equivalence ratio increases with a higher unburnt gas temperature and decreases at high pressures. This makes it difficult to develop the correlation required for robust and predictive CFD models. In this work the authors briefly describe the research path and the main challenges listed above.

An equilibrium-based steady-state simulator model that predicts and optimizes hydrogen production from steam gasification ofbiomass is developed using ASPEN Plus software and artificial intelligence techniques. Corn cob’s chemical composition wascharacterized to ensure the biomass used as a gasifier and with potential for production of hydrogen. Artificial intelligence is usedto examine the effects of the significant input variables on response variables such as hydrogen mole fraction and hydrogen energycontent. Optimizing the steam-gasification process using response surface methodology (RSM) considering a variety of biomass-steam ratios was carried out to achieve the best results. Hydrogen yield and the impact of main operating parameters wereconsidered. A maximum hydrogen concentration is found in the gasifier and water-gas shift (WGS) reactor at the highest steam-to-biomass (S/B) ratio and the lowest WGS reaction temperature while the gasification temperature has an optimum value. ANFISwas used to predict hydrogen of mole fraction 0.5045 with the input parameters of S/B ratio of 2.449 and reactor pressure andtemperature of 1 bar and 848°C respectively. With the steam-gasification model operating at temperature (850°C) pressure (1 bar)and S/B ratio of 2.0 an ASPEN simulator achieved a maximum of 0.5862 mole fraction of hydrogen while RSM gave an increaseof 19.0% optimum hydrogen produced over the ANFIS prediction with the input parameters of S/B ratio of 1.053 and reactorpressure and temperature of 1 bar and 850°C respectively. Varying the gasifier temperature and S/B ratio have on the other handa crucial effect on the gasification process with artificial intelligence as a unique tool for process evaluation prediction andoptimization to increase a significant impact on the products especially hydrogen.

Efforts to direct the economies of many countries towards low-carbon economies are being made in order to reduce their impact on global climate change. Within this process replacing fossil fuels with hydrogen will play an important role in the sectors where electrification is difficult or technically and economically ineffective. Hydrogen may also play a critical role in renewable energy storage processes. Thus the global hydrogen demand is expected to rise more than five times by 2050 while in the European Union a seven-fold rise in this field is expected. Apart from many technical and legislative barriers the environmental impact of hydrogen production is a key issue especially in the case of new and developing technologies. Focusing on the various pathways of hydrogen production the essential problem is to evaluate the related emissions through GHG accounting considering the life cycle of a plant in order to compare the technologies effectively. Anion exchange membrane (AEM) electrolysis is one of the newest technologies in this field with no LCA studies covering its full operation. Thus this study is focused on a calculation of the carbon footprint and economic indicators of a green hydrogen plant on the basis of a life cycle assessment including the concept of a solar-to-hydrogen plant with AEM electrolyzers operating under Polish climate conditions. The authors set the range of the GWP indicators as 2.73–4.34 kgCO2eq for a plant using AEM electrolysis which confirmed the relatively low emissivity of hydrogen from solar energy also in relation to this innovative technology. The economic profitability of the investment depends on external subsidies because as developing technology the AEM electrolysis of green hydrogen from photovoltaics is still uncompetitive in terms of its cost without this type of support.

To reach climate neutrality by 2050 a goal that the European Union set itself it is necessary to change and modify the whole EU’s energy system through deep decarbonization and reduction of greenhouse-gas emissions. The study presents a current insight into the global energy-transition pathway based on the hydrogen energy industry chain. The paper provides a critical analysis of the role of clean hydrogen based on renewable energy sources (green hydrogen) and fossil-fuels-based hydrogen (blue hydrogen) in the development of a new hydrogen-based economy and the reduction of greenhouse-gas emissions. The actual status costs future directions and recommendations for low-carbon hydrogen development and commercial deployment are addressed. Additionally the integration of hydrogen production with CCUS technologies is presented.

In this study we developed a new hybrid mathematical model that combines wind-speed range with the log law to derive the wind energy potential for wind-generated hydrogen production in Pakistan. In addition we electrolyzed wind-generated power in order to assess the generation capacity of wind-generated renewable hydrogen. The advantage of the Weibull model is that it more accurately reflects power generation potential (i.e. the capacity factor). When applied to selected sites we have found commercially viable hydrogen production capacity in all locations. All sites considered had the potential to produce an excess amount of wind-generated renewable hydrogen. If the total national capacity of wind-generated was used Pakistan could conceivably produce 51917000.39 kg per day of renewable hydrogen. Based on our results we suggest that cars and other forms of transport could be fueled with hydrogen to conserve oil and gas resources which can reduce the energy shortfall and contribute to the fight against climate change and global warming. Also hydrogen could be used to supplement urban energy needs (e.g. for Sindh province Pakistan) again reducing energy shortage effects and supporting green city programs.