Production & Supply Chain

This study introduces a novel hydrogen production system using the three-step copper chlorine (Cu-Cl) cycle. The proposed thermochemical cycle offers an innovative configuration that performs hydrogen production without an electrolysis step eliminating high-cost components such as membranes catalysts and electricity. The Cu-Cl cycle enables large-scale hydrogen production and is examined in various configurations including two- three- four- and five-step Cu-Cl cycles. Microscale experimental studies are conducted on a novel three-step Cu-Cl thermochemical cycle that works entirely on thermal energy input without electrolysis. In experimental studies some parameters that directly affect the amount of hydrogen production are investigated. The effects of parameters such as temperature steam/copper (S/C) ratio and reaction time on hydrogen production in the hydrolysis step are evaluated. The investigation also examined the impact of increasing temperature in the hydrolysis reaction on the generation of undesirable byproducts. Additionally the effect of increased temperatures in the decomposition process on oxygen formation is examined. In the optimization studies the individual and interactive effects of the parameters are analyzed using the Response Surface Methodology (RSM) and BoxBehnken Design (BBD) of experimental methods. The results of this study further show that the conditions with the highest hydrogen production are a S/C ratio of 55 a temperature of 400 ◦C and a reaction time between 30 and 40 min. It is also observed that hydrogen concentration increases with the increase in temperature and time and that the maximum level of 134.8 ppm is reached under optimum conditions.

Global attention is being given to hydrogen as it is seen as a versatile energy carrier and a flexible energy vector in transitioning to a low-carbon economy. Hydrogen production/storage/conveyance is metal intensive and it is crucial to understand if there is material availability to fulfil the committed plans. Using the material intensity of electrolysers pipelines and desalinators along with the projected Portuguese and European Union roadmaps we are able to identify possible bottlenecks in the supply chains. The availability of the vast majority of raw materials does not represent a threat to hydrogen technologies implementation with electrolysers requiring almost up to 3 Mt of raw materials and pipelines up to 2.5 Mt. The evident exception is iridium although representing less than 0.001 % of the material requirements it may hinder the widespread implementation of proton exchange membrane electrolysers. Desalinators have the least material footprint of the studied infrastructure.

This study focuses on the potential valorization of brewers’ spent grain (BSG) through gasification for ultra-pure green hydrogen production via membrane separation. First a fundamental physicochemical characterization of BSG samples from two different Spanish brewing industries was conducted revealing high energy content and good reproducibility of elemental composition thus providing great potential for hydrogen generation in the context of circular economy for the brewery industry. The syngas composition reached by BSG gasification has been predicted and main operating conditions optimized to maximize the hydrogen yield (25–75 vol% air-steam mixture ratio GR = 0.75 T = 800 ◦C and P = 5 bar). For gas purification two Pd-membranes were fabricated by ELP-PP onto tubular PSS supports with high reproducibility (Pd-thickness in the range 8.22–8.75 μm) exhibiting an almost complete H2-selectivity good fitting to Sieverts’ law and hydrogen permeate fluxes ranging from 175 to 550 mol m− 2 h− 1 under ideal gas feed composition conditions. The mechanical resistance of membranes was maintained at pressure driving forces up to 10 bar thus highlighting their potential for commercialization and industrial application. Furthermore long-term stability tests up to 75 h indicated promising membrane performance for continuous operation offering valuable insights for stakeholders in the brewery industry to enhance economic growth and environmental sustainability through green hydrogen production from BSG.

Hydrogen production by seawater electrolysis is significantly hindered by high energy costs and undesirable detrimental chlorine chemistry in seawater. In this work energy-saving hydrogen production is reported by chlorine-free seawater splitting coupling tip-enhanced electric field promoted electrocatalytic sulfion oxidation reaction. We present a bifunctional needle-like Co3S4 catalyst grown on nickel foam with a unique tip structure that enhances the kinetic rate by improving the current density in the tip region. The assembled hybrid seawater electrolyzer combines thermodynamically favorable sulfion oxidation and cathodic seawater reduction can enable sustainable hydrogen production at a current density of 100 mA cm−2 for up to 504 h. The hybrid seawater electrolyzer has the potential for scale-up industrial implementation of hydrogen production by seawater electrolysis which is promising to achieve high economic efficiency and environmental remediation.

As the global shift toward a low-carbon economy accelerates hydrogen is emerging as a crucial energy source. Among conventional methods for hydrogen production steam methane reforming (SMR) commonly paired with pressure swing adsorption (PSA) for hydrogen purification stands out due to its established infrastructure and technological maturity. This comprehensive techno-economic analysis focuses on membrane-based hydrogen production evaluating four configurations namely SMR SMR with PSA SMR with a palladium membrane and SMR with a ceramic–carbonate membrane coupled with a carbon capture system (CCS). The life cycle cost (LCC) of each configuration was assessed by analyzing key factors including production rate hydrogen pricing equipment costs and maintenance expenses. Sensitivity analysis was also conducted to identify major cost drivers influencing the LCC providing insights into the economic and operational feasibility of each configuration. The analysis reveals that SMR with PSA has the lowest LCC and is significantly more cost-efficient than configurations involving the palladium and ceramic–carbonate membranes. SMR with a ceramic–carbonate membrane coupled with CCS also demonstrates the most sensitive to energy variations due to its extensive infrastructure and energy requirement. Sensitivity analysis confirms that SMR with PSA consistently provides the greatest cost efficiency under varying conditions. These findings underscore the critical balance between cost efficiency and environmental considerations in adopting membrane-based hydrogen production technologies.

In this work the wastewater obtained from the hydrothermal liquefaction of black liquor was treated and valorized for hydrogen production by supercritical water gasification (SCWG). The influence of the main process parameters on the conversion yield was studied. The experiments were conducted at three different temperatures (below and above the critical point of water): 350 ◦C 450 ◦C and 600 ◦C. The results showed that by increasing the temperature from 350 ◦C to 600 ◦C the total gas yield was highly improved (from 1.9 mol gas/kg of dried feedstock to 13.1 mol gas/kg of dried feedstock). The H2 composition was higher than that of CH4 and CO2 at 600 ◦C and the HHV of the obtained gas was 61.2 MJ/kg. The total organic carbon (TOC) removal efficiency was also improved by increasing the temperature indicating that the SCWG process could be used for both applications: (i) for wastewater treatment; (ii) for producing a high calorific gas. The experiments with the Raney-nickel catalyst were performed in order to study the catalyst’s influence on the conversion yield. The results indicated that the catalyst enhances carbon conversion and gas production from mild to higher temperatures. The maximum total gas yield obtained with this catalyst was 32.4 mol gas/kg of dried feedstock at 600 ◦C which is 2.5 times higher than that obtained at the same operating conditions without a catalyst. The H2 yield and the HHV of the obtained gas with the catalyst were 20.98 mol gas/kg dried feedstock and 80.2 MJ/kg respectively. However the major contribution of the catalytic SCWG process was the improvement of the total gas yield at mild operating temperatures (450 ◦C) and the obtained performance was even higher than that obtained at 600 ◦C without catalyst (17.81 mol gas/kg dried feedstock and 13.1 mol gas/kg dried feedstock respectively). This is a sustainable approach for treating wastewater at mild temperatures by catalytic SCWG.

A new type of hydrogen produced in situ in petroleum reservoirs is proposed. This technology is based on ex situ catalytic gasification of biomass combining two thermal enhanced oil recovery techniques currently used in industrial fields: cyclic steam stimulation and in situ combustion. This hydrogen named “light-blue hydrogen” is produced in reservoirs like naturally occurring white hydrogen and from fossil fuels like blue hydrogen. The color light blue results from the blending of white and blue. This approach is particularly suitable for mature petroleum reservoirs which are in the final stages of production or no longer producing oil. This manuscript describes the method for producing light-blue hydrogen in situ its commercial application prospects and the challenges for developing and scaling up this technology.

This study presents preliminary findings from an experimental campaign conducted on a pilot-scale green hydrogen production plant powered by a photovoltaic (PV) system. The integrated setup implemented at the University “Mediterranea” of Reggio Calabria includes renewable energy generation hydrogen production via electrolysis on-site storage and reconversion through fuel cells. The investigation assessed system performance under different configurations (on-grid and selective stand-alone modes) focusing on key operational phases such as inerting purging pressurization hydrogen generation and depressurization. Results indicate a strong linear correlation between the electrolyser’s power setpoint and the pressure rise rate with a maximum gradient of 0.236 bar/min observed at 75% power input. The system demonstrated robust and stable operation efficient control of shutdown sequences and effective integration with PV input. These outcomes support the technical feasibility of small-scale hydrogen systems driven by renewables and offer valuable reference data for calibration models and future optimization strategies.

Methane cracking (MC) is emerging as a low-carbon hydrogen production technology. This review conducts a comprehensive bibliometric analysis of 46 studies examining the sustainability of MC process. The review employs Life Cycle Assessment (LCA) Life Cycle Cost (LCC) Techno-Economic Analysis (TEA) and Social Life Cycle Assessment (SLCA) methodologies. The findings reveal that LCOH for MC technologies ranges from 0.9 to 6.6 $/kg H2 at the same time GHG emissions span 0.8–14.5 kg CO2eq/kg H2 depending on the specific reactor configurations plant geographical locations and carbon revenues. These results indicate that MC can be competitive with steam methane reforming with carbon capture and electrolysis under certain conditions. However the review identifies significant research gaps including limited comprehensive LCA studies a lack of social impact assessments insufficient environmental impact analysis of molten media catalysts and particulate matter formation in MC processes as well as insufficient analysis of the potential of biomethane cracking.

Clean hydrogen is expected to play a crucial role in the future decarbonized energy mix. This places the gasification of biomass as a critical conversion pathway for hydrogen production owing to its carbon neutrality. However there is limited research on the direction of the body of literature on this subject matter. Utilising the Bibliometrix package R this paper conducts a systematic review and bibliometric analysis of the literature on gasification-derived hydrogen production over the previous three decades. The results show a decade-wise spike in hydrogen research mostly contributed by China the United States and Europe whereas the scientific contribution of Africa on the topic is limited with less than 6% of the continent’s research output on the subject matter sponsored by African institutions. The current trend of the research is geared towards alignment with the Paris Agreement through feedstock diversification to include renewable sources such as biomass and municipal solid waste and decarbonising the gasification process through carbon-capture technologies. This review reveals a gap in the experimental evaluation of heterogenous organic municipal solid waste for hydrogen production through gasification within the African context. The study provides an incentive for policy actors and researchers to advance the green hydrogen economy in Africa.

The production of green hydrogen requires renewable electricity and a supply of sustainable water. Due to global water scarcity using seawater to produce green hydrogen is particularly important in areas where freshwater resources are scarce. This study establishes a system model to simulate and optimize the integrated technology of seawater desalination by membrane distillation and hydrogen production by alkaline water electrolysis. Technical economics is also performed to evaluate the key factors affecting the economic benefits of the coupling system. The results show that an increase in electrolyzer power and energy efficiency will reduce the amount of pure water. An increase in the heat transfer efficiency of the membrane distillation can cause the breaking of water consumption and production equilibrium requiring a higher electrolyzer power to consume the water produced by membrane distillation. The levelized costs of pure water and hydrogen are US$1.28 per tonne and $1.37/kg H2 respectively. The most important factors affecting the production costs of pure water and hydrogen are electrolyzer power and energy efficiency. When the price of hydrogen rises the project’s revenue increases significantly. The integrated system offers excellent energy efficiency compared to conventional desalination and hydrogen production processes and advantages in terms of environmental protection and resource conservation.

In this paper we analyze the autothermal reforming (ATR) of methane through Gibbs energy minimization and entropy maximization methods to analyze isothermic and adiabatic systems respectively. The software GAMS® 23.9 and the CONOPT3 solver were used to conduct the simulations and thermodynamic analyses in order to determine the equilibrium compositions and equilibrium temperatures of this system. Simulations were performed covering different pressures in the range of 1 to 10 atm temperatures between 873 and 1073 K steam/methane ratio was varied in the range of 1.0/1.0 and 2.0/1.0 and oxygen/methane ratios in the feed stream in the range of 0.5/1.0 to 2.0/1.0. The effect of using pure oxygen or air as oxidizer agent to perform the reaction was also studied. The simulations were carried out in order to maintain the same molar proportions of oxygen as in the simulated cases considering pure oxygen in the reactor feed. The results showed that the formation of hydrogen and synthesis gas increased with temperature average composition of 71.9% and 56.0% using air and O2 respectively. These results are observed at low molar oxygen ratios (O2/CH4 = 0.5) in the feed. Higher pressures reduced the production of hydrogen and synthesis gas produced during ATR of methane. In general reductions on the order of 19.7% using O2 and 14.0% using air were observed. It was also verified that the process has autothermicity in all conditions tested and the use of air in relation to pure oxygen favored the compounds of interest mainly in conditions of higher pressure (10 atm). The mean reductions with increasing temperature in the percentage increase of H2 and syngas using air under 1.5 and 10 atm at the different O2/CH4 ratios were 5.3% 13.8% and 16.5% respectively. In the same order these values with the increase of oxygen were 3.6% 6.4% and 9.1%. The better conditions for the reaction include high temperatures low pressures and low O2/CH4 ratios a region in which there is no swelling in terms of the oxygen source used. In addition with the introduction of air the final temperature of the system was reduced by 5% which can help to reduce the negative impacts of high temperatures in reactors during ATR reactions.

Liquid hydrogen has attracted much attention due to its high energy storage density and suitability for long-distance transportation. An efficient hydrogen liquefaction process is the key to obtaining liquid hydrogen. In an effort to determine the parameter optimization of the hydrogen liquefaction process this paper employed process simulation software Aspen HYSYS to simulate the hydrogen liquefaction process. By establishing a dynamic model of the unit module this study carried out dynamic simulation optimization based on the steady-state process and process parameters of the hydrogen liquefaction process and analyzed the dynamic characteristics of the process. Based on the pressure drop characteristic experiment an equation for the pressure drop in the heat exchanger was proposed. The heat transfer of hydrogen conversion was simulated and analyzed and its accuracy was verified by comparison with the literature. The dynamic simulation of a plate-fin heat exchanger was carried out by coupling heat transfer simulation and the pressure drop experiment. The results show that the increase in inlet temperature (5 C and 10 C) leads to an increase in specific energy consumption (0.65 % and 1.29 % respectively) and a decrease in hydrogen liquefaction rate (0.63 % and 2.88 % respectively). When the inlet pressure decreases by 28.57 % the hydrogen temperature of the whole liquefaction process decreases and the specific energy consumption increases by 52.94 %. The research results are of great significance for improving the operating efficiency of the refrigeration cycle and guiding the actual liquid hydrogen production.

Hydrogen has become a prospective energy carrier for a cleaner more sustainable economy offering carbon-free energy to reduce reliance on fossil fuels and address climate change challenges. However hydrogen production faces significant technological and economic hurdles that must be overcome to reveal its highest potential. This study focused on evaluating the economics and technoeconomic resilience of two large-scale hydrogen production routes from African palm empty fruit bunches (EFB) by indirect gasification. Computer-aided process engineering (CAPE) assessed multiple scenarios to identify bottlenecks and optimize economic performance indicators like gross profits including depreciation after-tax profitability payback period and net present value. Resilience for each route was also assessed considering raw material costs and the market price of hydrogen in relation to gross profits and after-tax profitability. Route 1 achieved a gross profit (DGP) of USD 47.12 million and a profit after taxes (PAT) of USD 28.74 million while Route 2 achieved a DGP of USD 46.53 million and a PAT of USD 28.38 million. The results indicated that Route 2 involving hydrogen production through an indirect gasification reactor with a Selexol solvent unit for carbon dioxide removal demonstrated greater resilience in terms of raw material costs and product selling price.

The transition to low-carbon energy systems requires efficient hydrogen production methods that minimise CO2 emissions. This study presents a techno-economic assessment of hydrogen production via methane pyrolysis utilising a novel liquid metal bubble column reactor (LMBCR) designed for CO2-free hydrogen and solid carbon outputs. Operating at 20 bar and 1100 ◦C the reactor employs a molten nickel-bismuth alloy as both catalyst and heat transfer medium alongside a sodium bromide layer to enhance carbon purity and facilitate separation. Four operational scenarios were modelled comparing various heating and recycling configurations to optimise hydrogen yield and process economics. Results indicate that the levelised cost of hydrogen (LCOH) is highly sensitive to methane and electricity prices CO2 taxation and the value of carbon by-products. Two reactor configurations demonstrate competitive LCOHs of 1.29 $/kgH2 and 1.53 $/kgH2 highlighting methane pyrolysis as a viable low-carbon alternative to steam methane reforming (SMR) with carbon capture and storage (CCS). This analysis underscores the potential of methane pyrolysis for scalable economically viable hydrogen production under specificmarket conditions.

As a clean energy source hydrogen not only helps to reduce the use of fossil fuels but also promotes the transformation of energy structure and sustainable development. This paper firstly introduces the development status of green hydrogen at home and abroad and then focuses on several advanced green hydrogen production technologies. Then the advantages and shortcomings of different green hydrogen production technologies are compared. Among them the future source of hydrogen tends to be electrolysis water hydrogen production. Finally the challenges and application prospects of the development process of green hydrogen technology are discussed and green hydrogen is expected to become an important part of realizing sustainable global energy development.

The current study comprehensively examines the application of wave tidal and undersea current energy sources of Turkiye for green hydrogen fuel production and cost analysis. The estimated potential capacity of each city is derived from official data and acceptable assumptions and is subject to discussion and evaluation in the context of a viable hydrogen economy. According to the findings the potential for green hydrogen generation in Turkiye is projected to be 7.33 million tons using a proton exchange membrane electrolyser (PEMEL). Cities with the highest hydrogen production capacities from marine applications are Mugla Izmir Antalya and Canakkale with 998.10 kt 840.31 kt 605.46 kt and 550.42 kt respectively. The study calculations obviously show that there is a great potential by using excess power in producing hydrogen which will result in an economic value of 3.01 billion US dollars. This study further helps develop a detailed hydrogen map for every city in Turkiye using the identified potential capacities of renewable energy sources and the utilization of electrolysers to make green hydrogen by green power. The potentials and specific capacities for every city are also highlighted. Furthermore the study results are expected to provide clear guidance for government authorities and industries to utilize such a potential of renewable energy for investment and promote clean energy projects by further addressing concerns caused by the usage of carbon-based (fossil fuels dependent) energy options. Moreover green hydrogen production and utilization in every sector will help achieve the national targets for a net zero economy and cope with international targets to achieve the United Nation's sustainable development goals.

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.

Renewable hydrogen production from biomass thermochemical conversion is an emerging technology to reduce fossil fuel consumptions and carbon emissions. Biomass-derived hydrogen can be produced by pyrolysis gasification alkaline thermal treatment etc. However the removal of impurities from biomass thermochemical conversion products to improve hydrogen purity is currently technical bottleneck. It is important to assess and investigate the types and properties of impurities the difficulty of separation and the impact on downstream utilization of hydrogen in the biomass-derived hydrogen production process. The key objectives of this comprehensive review are: (1) to reveal the current status and necessity of developing biomass-derived hydrogen production; (2) to evaluate the types devices and impurities distribution of biomass thermochemical conversion; (3) to explore the formation pathways and removal technologies of typical impurities of tar CO2 sulfides and nitrides in hydrogen production process; and (4) to propose future insights on the separation technologies of typical impurities to promote the gradual substitution of biomass-derived hydrogen for fossil-derived energy.

Bioenergy with carbon capture and storage (BECCS) technology is expected to support net-zero targets by supplying low carbon energy while providing carbon dioxide removal (CDR). BECCS is estimated to deliver 20 to 70 MtCO2 annual negative emissions by 2050 in the UK despite there are currently no BECCS operating facility. This research is modelling and demonstrating the flexibility scalability and attainable immediate application of BECCS. The CDR potential for two out of three BECCS pathways considered by the Intergovernmental Panel on Climate Change (IPCC) scenarios were quantified (i) modular-scale CHP process with post-combustion CCS utilising wheat straw and (ii) hydrogen production in a small-scale gasifier with pre-combustion CCS utilising locally sourced waste wood. Process modelling and lifecycle assessment were used including a whole supply chain analysis. The investigated BECCS pathways could annually remove between − 0.8 and − 1.4 tCO2e tbiomass− 1 depending on operational decisions. Using all the available wheat straw and waste wood in the UK a joint CDR capacity for both systems could reach about 23% of the UK’s CDR minimum target set for BECCS. Policy frameworks prioritising carbon efficiencies can shape those operational decisions and strongly impact on the overall energy and CDR performance of a BECCS system but not necessarily maximising the trade-offs between biomass use energy performance and CDR. A combination of different BECCS pathways will be necessary to reach net-zero targets. Decentralised BECCS deployment could support flexible approaches allowing to maximise positive system trade-offs enable regional biomass utilisation and provide local energy supply to remote areas.

This article describes an example of using the measurement data from photovoltaic systems and wind turbines to perform practical probabilistic calculations around green hydrogen generation. First the power generated in one month by a ground-mounted photovoltaic system with a peak power of 3 MWp is described. Using the Metalog family of probability distributions the probability of generating selected power levels corresponding to the amount of green hydrogen produced is calculated. Identical calculations are performed for the simulation data allowing us to determine the power produced by a wind turbine with a maximum power of 3.45 MW. After interpolating both time series of the power generated by the renewable energy sources to a common sampling time they are summed. For the sum of the power produced by the photovoltaic system and the wind turbine the probability of generating selected power levels corresponding to the amount of green hydrogen produced is again calculated. The presented calculations allow us to determine with probability distribution accuracy the amount of hydrogen generated from the energy sources constituting a mix of photovoltaics and wind. The green hydrogen production model includes the hardware and the geographic context. It can be used to determine the preliminary assumptions related to the production of large amounts of green hydrogen in selected locations. The calculations presented in this article are a practical example of Business Intelligence.

Industrial catalysts are accelerating the global transition toward renewable energy serving as enablers for innovative technologies that enhance efficiency lower costs and improve environmental sustainability. This review explores the pivotal roles of industrial catalysts in hydrogen production biofuel generation and biomass conversion highlighting their transformative impact on renewable energy systems. Precious-metal-based electrocatalysts such as ruthenium (Ru) iridium (Ir) and platinum (Pt) demonstrate high efficiency but face challenges due to their cost and stability. Alternatives like nickel-cobalt oxide (NiCo2O4) and Ti3C2 MXene materials show promise in addressing these limitations enabling costeffective and scalable hydrogen production. Additionally nickel-based catalysts supported on alumina optimize SMR reducing coke formation and improving efficiency. In biofuel production heterogeneous catalysts play a crucial role in converting biomass into valuable fuels. Co-based bimetallic catalysts enhance hydrodeoxygenation (HDO) processes improving the yield of biofuels like dimethylfuran (DMF) and γ-valerolactone (GVL). Innovative materials such as biochar red mud and metal–organic frameworks (MOFs) facilitate sustainable waste-to-fuel conversion and biodiesel production offering environmental and economic benefits. Power-to-X technologies which convert renewable electricity into chemical energy carriers like hydrogen and synthetic fuels rely on advanced catalysts to improve reaction rates selectivity and energy efficiency. Innovations in non-precious metal catalysts nanostructured materials and defect-engineered catalysts provide solutions for sustainable energy systems. These advancements promise to enhance efficiency reduce environmental footprints and ensure the viability of renewable energy technologies.

The global energy sector is undergoing a transition towards sustainable sources with hydrogen emerging as a promising alternative due to its high energy content and clean-burning properties. The integration of hydrogen into the energy landscape represents a significant advancement towards a cleaner greener future. This paper introduces an innovative decision support system (DSS) that combines multi-criteria decision-making (MCDM) and decision tree methodologies to optimize hydrogen production decisions in emerging economies using Saudi Arabia as a case study. The proposed DSS developed using MATLAB Web App Designer tools evaluates various scenarios related to demand and supply cost and profit margins policy implications and environmental impacts with the goal of balancing economic viability and ecological responsibility. The study's findings highlight the potential of this DSS to guide policymakers and industry stakeholders in making informed scalable and flexible hydrogen production decisions that align with sustainable development goals. The novel DSS framework integrates two key influencing factors technical and logistical by considering components such as data management modeling analysis and decision-making. The analysis component employs statistical and economic methods to model and assess the costs and benefits of eleven strategic scenarios while the decision-making component uses these results to determine the most effective strategies for implementing hydrogen production to minimize risks and uncertainties.

Renewable hydrogen obtained from renewable energy sources especially when produced through water electrolysis is gaining attention as a promising energy vector to deal with the challenges of climate change and the intermittent nature of renewable energy sources. In this context this work analyzes a pilot plant that uses this technology installed in the Itumbiara Hydropower Plant located between the states of Goiás and Minas Gerais Brazil from technical and economic perspectives. The plant utilizes an alkaline electrolyzer synergistically powered by solar photovoltaic and hydro sources. Cost data for 2019 when the equipment was purchased and 2020–2023 when the plant began continuous operation are considered. The economic analysis includes annualized capital maintenance and variable costs which determines the levelized cost of hydrogen (LCOH). The results obtained for the pilot plant’s LCOH were USD 13.00 per kilogram of H2 with an efficiency loss of 2.65% for the two-year period. Sensitivity analysis identified the capacity factor (CF) as the main determinant of the LCOH. Even though the analysis specifically applies to the Itumbiara Hydropower Plant the CF can be extrapolated to larger plants as it directly influences hydrogen production regardless of plant size or capacity

Green hydrogen derived from renewable resources is increasingly recognized as a basis for future low-carbon energy systems. This study presents a comprehensive techno-environmental comparison of two thermochemical conversion pathways utilizing biomethane: steam methane reforming (SMR) and chemical looping reforming (CLR). Through integrated process simulations compositional analyses energy modeling and cost evaluation we examine the comparative advantages of each route in terms of hydrogen yield carbon separation efficiency process energy intensity and economic performance. The results demonstrate that CLR achieves a significantly higher hydrogen concentration in the raw syngas stream (62.44%) than SMR (43.14%) with reduced levels of residual methane and carbon monoxide. The energy requirements for hydrogen production are lower in the CLR system averaging 1.2 MJ/kg compared to 3.2 MJ/kg for SMR. Furthermore CLR offers a lower hydrogen production cost (USD 4.3/kg) compared to SMR (USD 6.4/kg) primarily due to improved thermal integration and the absence of solvent-based CO2 capture. These insights highlight the potential of CLR as a next-generation reforming strategy for producing green hydrogen. To advance its technology readiness it is proposed to develop a pilot-scale CLR facility to validate system performance under operational conditions and support the pathway to commercial implementation.