Publications

Hydrogen technologies are evolving to decarbonise the transport sector. The present work focuses on the technical design of a Hydrogen Refueling Station to supply hydrogen to five buses in the city of Valencia Spain. The study deals with the technical selection of the components from production to consumption setting an efficient standardisation method. Different calculation are used to size the storage systems for 70.8 kg of hydrogen produced by the elecrolyser daily. For the high-pressure storage system massive and cascade methods are proposed being the last one more efficient (1577.53 Nm3 non usable volume compared to 9948.95 Nm3 of the massive method).

This study addresses the challenge of decarbonizing highly energy-intensive Industrial Port Areas (IPA) focusing on emissions from various sources like ship traffic warehouses buildings cargo handling equipment and hardto-abate industry typically hosted in port areas. The analysis and proposal of technological solutions and their optimal integration in the context of IPA is a topic of growing scientific interest with considerable social and economic implications. Representing the main novelties of the work this study introduces (i) the development of a novel IPA energy and green hydrogen hub located in a tropical region (Singapore); (ii) a multi-objective optimization approach to analyse synthesize and optimize the design and operation of the hydrogen and energy hub with the aim of supporting decision-making for decarbonization investments. A sensitivity analysis identifies key parameters affecting optimization results indicating that for large hydrogen demands imported ammonia economically outperforms other green hydrogen carriers. Conversely local hydrogen production via electrolysis becomes economically viable when the capital cost of alkaline electrolyser drops by at least 30 %. Carbon tax influences the choice of green hydrogen but its price variation mainly impacts system operation rather than design. Fuel cells and batteries are not considered economically feasible solutions in any scenario.

To inject green hydrogen (H2) into the existing natural gas (NG) infrastructure is one way to decarbonize the European energy system. However asset readiness is necessary to be successful. Preliminary analysis and experimental results about the compatibility of hydrogen and natural gas mixtures (H2NG) with the actual gas grids make the scientific community confident about the feasibility. Nevertheless specific technical questions need more research. A significant topic of debate is the impact of H2NG mixtures on the performance of state-ofthe-art fiscal measuring devices which are essential for accurate billing. Identifying and addressing any potential degradation in their metrological performance due to H2NG is critical for decision-making. However the literature lacks data about the gas meters’ technologies currently installed in the NG grids such as a comprehensive overview of their readiness at different concentrations while data are fragmented among different sources. This paper addresses these gaps by analyzing the main characteristics and categorizing more than 20000 gas meters installed in THOTH2 project partners’ grids and by summarizing the performance of traditional technologies with H2NG mixtures and pure H2 based on literature review operators experience and manufacturers knowledge. Based on these insights recommendations are given to stakeholders on overcoming the identified barriers to facilitate a smooth transition.

The transition towards clean and economically viable hydrogen production is crucial for ensuring energy sustainability and mitigating climate change. This transition can be effectively facilitated by using renewable energy sources and advanced hydrogen production methods. Methane pyrolysis and water electrolysis emerge as crucial techniques for achieving hydrogen production with minimal carbon intensity. Recognizing the unique opportunity presented by solar energy for both processes this study presents a comparative techno-economic analysis between solar-based molten salt methane pyrolysis (SMSMP) and solar-based solid oxide electrolyzer cell (SSOEC). This study offers a guideline for selecting SMSMP vs SSOEC for cities across theworld. In particular a comprehensive case study including five cities worldwide—San Antonio Edmonton Auckland Seville and Lyon—is conducted utilizing their dynamic solar data and localized prices of methane and electricity to provide a realistic comparison. The results indicate the superior economic feasibility of SMSMP across all case studies. Among different case studies San Antonio and Auckland have the lowest hydrogen costs for SMSMP (2.31 $/kgH2) and SSOEC (5.19 $/kgH2) respectively. It was also concluded that SMSMP is preferred over SSOEC in average to ideal solar conditions given its full dependency on solar thermal energy. However the SSOEC has the potential to achieve better economic feasibility by incorporating clean hydrogen tax incentives and reducing the costs associated with renewable energy infrastructure in the future.

The transition to green energy in the transport sector is becoming a priority in the context of global climate challenges and the European Green Deal. This paper investigates the development of alternative fuelling stations particularly electric vehicle (EV) charging infrastructure and hydrogen stations across EU countries with a focus on Poland. It combines a policy and technology overview with a quantitative scientific analysis offering a multidimensional perspective on green infrastructure deployment. A Pearson correlation analysis reveals significant links between charging station density and both GDP per capita and the share of renewable energy. The study introduces an original Infrastructure Accessibility Index (IAI) to compare infrastructure availability across EU member states and models Poland’s EV charging station demand up to 2030 under multiple growth scenarios. Furthermore the article provides a comprehensive overview of biofuels including first- second- and third-generation technologies and highlights recent advances in hydrogen and renewable electricity integration. Emphasis is placed on life cycle considerations energy source sustainability and economic implications. The findings support policy development toward zero-emission mobility and the decarbonisation of transport systems offering recommendations for infrastructure expansion and energy diversification strategies.

Until recently electrified aircraft propulsion (EAP) technology development has been driven by the dual objectives of reducing greenhouse gas (GHG) emissions and addressing the depletion of fossil fuels. However the increasing severity of climate change posing a significant threat to all life forms has resulted in the global consensus of achieving net-zero GHG emissions by 2050. This major shift has alerted the aviation electrification industry to consider the following: What is the clear path forward for EAP technology development to support the net-zero GHG goals for large commercial transport aviation? The purpose of this paper is to answer this question. After identifying four types of GHG emissions that should be used as metrics to measure the effectiveness of each technology for GHG reduction the paper presents three significant categories of GHG reduction efforts regarding the engine evaluates the potential of EAP technologies within each category as well as combinations of technologies among the different categories using the identified metrics and thus determines the path forward to support the net-zero GHG objective. Specifically the paper underscores the need for the aviation electrification industry to adapt adjust and integrate its EAP technology development into the emerging new engine classes. These innovations and collaborations are crucial to accelerate net-zero GHG efforts effectively.

A liquid air energy storage (LAES) system is a promising Carnot battery configuration capable of efficiently recovering waste heat and cold energy carriers. Among these liquid hydrogen (LH₂) regasification presents a significant opportunity due to its high exergy content and its regasification temperature which aligns well with the liquid air liquefaction process. While most existing studies focus on integrating LAES with liquid natural gas (LNG) regasification or improving hydrogen liquefaction via liquid air regasification this work takes a novel approach by enhancing liquid air liquefaction through the utilization of waste cold from LH₂ regasification. Additionally this study explores an economic innovation the valorization of clean dry air discharged by LAES which has not been extensively examined in prior literature. A novel LAES configuration is proposed and subjected to a techno-economic analysis comparing its performance with a stand-alone LAES system. Results show that the proposed integration increases round-trip efficiency by 15 % reduces the levelized cost of storage by 60 % and achieves a payback period of under 10 years. These findings provide valuable insights for both academia and industry advancing the development of more efficient and economically viable LAES systems.

Promoting the development of China’s hydrogen energy industry is crucial for achieving green energy transition. However existing research lacks systematic studies on the spatial layout of the hydrogen industry chain. This study constructed a comprehensive theoretical framework encompassing hardware infrastructure software systems and soft power. Using multi-source heterogeneous data GIS analysis and NVivo text coding methods the current regional layout and challenges of China’s hydrogen infrastructure industry chain were systematically evaluated. The findings determined that economically developed eastern regions lead in infrastructure and soft power while central and western regions leverage their resource and manufacturing advantages. Major challenges include regional imbalances in hardware infrastructure uneven distribution of soft power and misalignment between software systems and actual needs. Analysis of the “14th Five-Year Plan” of various regions elucidated deep insights into the diversity of local hydrogen energy development strategies identifying five types of hydrogen cities: resource-advantaged market-oriented regionally collaborative innovation-driven and policy-supported. Accordingly strategies to enhance industry chain synergy clarify city roles and optimize regional ecosystems were proposed. It is recommended to integrate hydrogen infrastructure with urban planning and incorporate environmental impact assessments into spatial optimization decisions. This study provides a systematic analytical framework and progressive policy recommendations for the efficient and green layout of China’s hydrogen infrastructure offering important implications for the sustainable development of the hydrogen industry and other rapidly developing economies.

The steel industry is one of the major sources of greenhouse gas emissions with significant energy demand. Currently 73% of the world’s steel is manufactured through the coal-coke-based blast furnace-basic oxygen furnace route (BF-BOF) emitting about two tonnes of CO2 per tonne of steel produced. This review reports the major technologies recent developments challenges and technoeconomic comparison of steelmaking technol ogies emphasising the integration of hydrogen in emerging and established ironmaking and steelmaking pro cesses. Significant trials are underway especially in Germany to replace coal injected in the tuyeres of the blast furnace with hydrogen. However it is not clear that this approach can be extended beyond 30% replacement of coke because of the associated technical challenges. Direct smelting and fluidised bed technologies can emit 20%–30% less CO2 without carbon capture and storage utilisation. The implications of hydrogen energy in these technologies as a substitute for natural gas and coal are yet to be fully explored. A hydrogen-based direct reduction of iron ore (DRI) and steel scrap melting in an electric arc furnace (EAF) appeared to be the most mature technological routes to date capable of reducing CO2 emission by 95% but rely on the availability of rich iron concentrates as feed materials. Shaft furnace technologies are the common DRI-making process with a share of over 72% of the total production. The technology has been developed with natural gas as the main fuel and reductant. However it is now being adapted to operate predominantly on hydrogen to produce a low-carbon DRI product. Plasma and electrolysis-based iron and steelmaking are some of the other potential technologies for the application of hydrogen with a CO2 reduction potential of over 95%. However these technologies are in the preliminary stage of development with a technology readiness level of below 6. There are many technological challenges for the application of hydrogen in steel manufacturing such as challenges in distributing heat due to the endothermic H2 reduction process balancing carbon content in the product steel (particularly using zerocarbon DRI) removal of gangue materials and sourcing of cost-competitive renewable hydrogen and highquality iron ore (65>Fe). As iron ore quality degrades worldwide several companies are considering melting DRI before steelmaking possibly using submerged arc technology to eliminate gangue materials. Hence sig nificant laboratory and pilot-scale demonstrations are required to test process parameters and product qualities. Our analysis anticipates that hydrogen will play an instrumental role in decarbonising steel industries by 2035.

The growing emphasis on renewable energy highlights hydrogen’s potential as a clean energy carrier. However traditional hydrogen production methods contribute significantly to carbon emissions. This review examines the integration of carbon capture and storage (CCS) technologies with hydrogen production processes focusing on their ability to mitigate carbon emissions. It evaluates various hydrogen production techniques including steam methane reforming electrolysis and biomass gasification and discusses how CCS can enhance environmental sustainability. Key challenges such as economic technical and regulatory obstacles are analyzed. Case studies and future trends offer insights into the feasibility of CCS–hydrogen integration providing pathways for reducing greenhouse gases and facilitating a clean energy transition.

The number of species and elementary reactions needed for describing the oxidation of fuels increases with the size of the molecule and in turn the complexity of detailed mechanisms. Although the kinetics for conventional fuels (H2 CH4 C3H8...) are somewhat well-established chemical integration in detonation applications remains a major challenge. Significant efforts have been made to develop reduction techniques that aim to keep the predictive capabilities of detailed mechanisms intact while minimizing the number of species and reactions required. However as their starting point of development is based on homogeneous reactors or ZND profiles reduced mechanisms comprising a few species and reactions are not predictive. The methodology presented here relies on defining virtual chemical species such that the thermodynamic equilibrium of the ZND structure is properly recovered thereby circumventing the need to account for minor intermediate species. A classical asymptotic expression relating the ignition delay time with the reaction rate constant is then used to fit the Arrhenius coefficients targeting computations carried out with detailed kinetics. The methodology was extended to develop a three-step mechanism in which the Arrhenius coefficients were optimized to accurately reproduce the one-dimensional laminar ZND structure and the D−κ curves for slightly-curved quasi-steady detonation waves. Two-dimensional simulations performed with the three-step mechanism successfully reproduce the spectrum of length scales present in soot foils computed with detailed kinetics (i.e. cell regularity and size). Results attest for the robustness of the proposed methodology/approximation and its flexibility to be adapted to different configurations.

The paper discusses potential hazards at hydrogen refueling stations for transportation vehicles: cars and trucks. The main hazard analyzed here is an uncontrolled gas release due to a failure in one of the structures in the station: storage tanks of different pressure levels or a dispenser. This may lead to a hydrogen cloud occurring near the source of the release or at a given distance. The range of the cloud was analyzed in connection to the amount of the released gas and the wind velocity. The results of the calculations were compared for chosen structures in the station. Then potential fires and explosions were investigated. The hazard zones were calculated with respect to heat fluxes generated in the fires and the overpressure generated in explosions. The maximum ranges of these zones vary from about 14 to 30 m and from about 9 to 14 m for a fires and an explosions of hydrogen respectively. Finally human death probabilities are presented as functions of the distance from the sources of the uncontrolled hydrogen releases. These are shown for different amounts and pressures of the released gas. In addition the risk of human death is determined along with the area where it reaches the highest value in the whole station. The risk of human death in this area is 1.63 × 10−5 [1/year]. The area is approximately 8 square meters.

This paper describes the performance of explosion free in fire self-venting (TPRD-less) composite tanks of Type IV in fires of realistic intensity HRR/A=1 MW/m2 in conditions of first responders’ intervention. This breakthrough safety technology does not require the use of thermally activated pressure relief devices (TPRD). It provides microleaks-no-burst (LNB) performance of high-pressure hydrogen storage tanks in a fire. Two fire intervention strategies are investigated one is the removal of a vehicle with LNB tank from the fire and another is the extinction of the fire. The removal from the fire scenario is investigated for one carbon-carbon and one carbon-basalt double-composite wall tank prototype. The fire extinction scenario is studied for four carbon-basalt prototypes. All six prototypes of 7.5 L volume and nominal working pressure of 70 MPa demonstrated safe release of hydrogen through microchannels of the composite wall after melting a liner. The technology allows fire brigades to apply standard intervention strategies and tactics at the fire scene with hydrogen vehicles if LNB tanks are used in the vehicle.

The European Union aims to deploy a high share of renewable energy sources in Europe’s power system by 2050. Large-scale intermittent wind and solar power production requires flexibility to ensure an adequate supply–demand balance. Green hydrogen (GH) can increase power systems’ flexibility and decrease renewable energy production’s curtailment. However investing in GH is costly and dependent on electricity prices which are important for operational costs in electrolysis. Moreover the use of GH for power system flexibility might not be economically viable if there is no hydrogen demand from the hydrogen market. If so questions would arise as to what would be the incentives to introduce GH as a source of flexibility in the power system and how would electrolyzer costs hydrogen demand and other factors affect the economic viability of GH usage for power system flexibility. The paper implements a European power system model formulated as a stochastic program to address these questions. The authors use the model to compare various instances with hydrogen in the power system to a no-hydrogen instance. The results indicate that by 2050 deployment of approximately 140 GW of GH will pay off investments and make the technology economically viable. We find that the price of hydrogen is estimated to be around €30/MWh.

The weather-dependent nature of renewable energy production has led to periodic overproduction making hydrogen production a practical solution for storing excess energy. In addition to conventional storage methods such as physical tanks or chemical bonding using the existing natural gas network as a storage medium has also proven to be effective. Households can play a role in this process as well. The purpose of these experiments is to evaluate the parameters of a household heating device currently in use but not initially designed for hydrogen operation. The appliance used in the tests has a closed combustion chamber with a natural draft induced by a density difference which is a common type. The tests were conducted at nominal load with a mix of 0–40 V/V% hydrogen and natural gas; no flashbacks or other issues occurred. As the hydrogen ratio increased from 0 to 40 V/V% the input heat decreased from 3.9 kW to 3.4 kW. The NOx concentration in the flue gas dropped from 26.2 ppm to 14.2 ppm and the CO2 content decreased from 4.5 V/V% to 3.4 V/V%. However the CO con centration slightly increased from 40.0 ppm to 44.1 ppm. Despite these changes efficiency remained stable fluctuating between 86.9% and 87.0%. The internal flame cone height was 3.27 mm when using natural gas but reduced sharply to just 0.38 mm when using 62 V/V% hydrogen. In addition to the fact that the article examines a group of devices that has been rarely investigated but is also widely distributed it also provides valuable experience for other experiments since the experiments were carried out with a higher hydrogen ratio compared to previous works.

A wireless near-field hydrogen gas sensor is proposed which detects the leaking hydrogen near its source to achieve fast response and high reliability. The proposed sensor can detect leaking hydrogen in 100ms with nearly no delay due to hydrogen diffusion in space. The overall response time is shortened by orders of magnitude compared to conventional sensors according to simulation results. Over 1 year of maintenance interval is empowered by wireless design based on Bluetooth low energy protocol.

This study aims to explore the techno-economic potential of harnessing waste heat from a Small Modular Reactor (SMR) to fuel Direct Air Carbon Capture (DACC) and High Temperature Steam Electrolysis (HTSE) technologies. The proposed system’s material flows and energy demands are modelled via the ASPEN Plus v12.1 where results are utilised to provide estimates of the Levelised Cost of DACC (LCOD) and Levelised Cost of Hydrogen (LCOH). The majority of thermal energy and electrical utilities are assumed to be supplied directly by the SMR. A sensitivity analysis is then performed to investigate the effects of core operational parameters of the system. Key results indicate levelised costs of 4.66 $/kgH2 at energy demands of 34.37 kWh/kgH2 and 0.02 kWh/kgH2 thermal for HTSE hydrogen production and 124.15 $/tCO2 at energy demands of 31.67 kWh/tCO2 and 126.33 kWh/tCO2 thermal for carbon capture; parameters with most impact on levelised costs are air intake and steam feed for LCOD and LCOH respectively. Both levelised costs i.e. LCOD and LCOH would decrease with the production scale. The study implies that an integrated system of DACC and HTSE provided the best cost-benefit results however the cost-benefit analysis is heavily subjective to geography politics and grid demand.

Liquid hydrogen storage is an important way of hydrogen storage and transportation which greatly improves the storage and transportation efficiency due to the high energy density but at the same time brings new safety hazards. In this study the liquid hydrogen leakage in the storage area of a hydrogen production station is numerically simulated. The effects of ambient wind direction wind speed leakage mass flow rate and the mass fraction of gas phase at the leakage port on the diffusion behavior of the liquid hydrogen leakage were investigated. The results show that the ambient wind direction directly determines the direction of liquid hydrogen leakage diffusion. The wind speed significantly affects the diffusion distance. When the wind speed is 6 m/s the diffusion distance of the flammable hydrogen cloud reaches 40.08 m which is 2.63 times that under windless conditions. The liquid hydrogen leakage mass flow rate and the mass fraction of the gas phase have a greater effect on the volume of the flammable hydrogen cloud. As the leakage mass flow rate increased from 5.15 kg/s to 10 kg/s the flammable hydrogen cloud volume increased from 5734.31 m3 to 10305.5 m3 . The installation of a barrier wall in front of the leakage port can limit the horizontal diffusion of the flammable hydrogen cloud elevate the diffusion height and effectively reduce the volume of the flammable hydrogen cloud. This study can provide theoretical support for the construction and operation of hydrogen production stations.

Following the introduction of the EU’s Hydrogen Strategy in 2020 as part of the European Green Deal some EU member states have deployed a very active hydrogen diplomacy. Germany The Netherlands and Belgium have been the most active ones establishing no less than 40 bilateral hydrogen trade partnerships with 30 potential export countries in the last three years. However concerns have been voiced about whether such hydrogen trade relationships can be economically feasible geopolitically wise environmentally sustainable and socially just. This article therefore evaluates these partnerships considering three risk dimensions: economic political and sustainability (covering both environmental and justice) risks. The analysis reveals that the selection of partner countries entails significant trade-offs. Four groups of partner countries can be identified based on their respective risk profile: “Last Resorts” “Volatile Ventures” “Strategic Gambits” and “Trusted Friends”. Strikingly less than one-third of the agreements are concluded with countries that fall within the “Trusted Friends” category which have the lowest overall risk profile. These findings show the need for policy makers to think much more strategically about which partnerships to pursue and to confront tough choices about which risks and trade-offs they are willing to accept.

This manuscript contributes to understanding the role of hydrogen in different materials emphasizing polymers and composite materials to increase hydrogen storage capacity in those materials. Hydrogen storage is critical in advancing and optimizing sustainable energy solutions that are essential for improving their performance. Capillary arrays which offer increased surface area and optimized storage geometries present a promising avenue for enhancing hydrogen uptake. This work evaluates various polymers and glass for their mechanical properties and strength with 700 bar inner pressure loads within capillary tubes. A theoretical mathematical approach was employed to quantify the impact of material properties on storage capacity. Our results demonstrate that certain polymers (e.g. Zylon AS Dyneema SK99) and glass types (S-2 Glass) exhibit superior hydrogen storage potential due to their enhanced strength and low density. These findings suggest that integrating the proposed materials into capillary array systems can significantly improve hydrogen storage efficiency (15–37 wt.% and 37–40 g/L) making them viable candidates for next-generation energy storage systems. This study provides valuable insights into material selection and structural design strategies for high-capacity hydrogen storage technologies.

Following a desktop study undertaken in 2021 to identify hazard scenarios associated with the use of liquid and compressed hydrogen on commercial shipping Shell has started a programme of large-scale experiments on the consequences of a release of liquid hydrogen. This work will compliment on-going research Shell has sponsored within several joint industry projects but will also address immediate concerns that the maritime industry has for the transportation of liquid hydrogen (LH2). This paper will describe the first phase of experiments involving the release of LH2 onto various substrates as well as dispersion across an instrumented test pad. These results will be used to address the following uncertainties in risk assessments within the hydrogen economy such as (1) Quantify the impact of low wind speed and high humidity on the buoyancy of both a passive and momentum jet dispersion cloud (2) Gather additional data on liquid hydrogen jet fires (3) Understand the likelihood for the formation of a sustained pool of hydrogen (4) Characterise materials especially passive fire protective coatings that are exposed to LH2. Not only will these experiments generate validation data to provide confidence in the Shell consequence tool FRED but they will also be used by Shell to support updates and new regulations developed by the International Maritime Organisation as it seeks to reduce CO2 intensity in the maritime industry.

The global energy landscape is rapidly shifting toward cleaner lower-carbon electricity generation necessitating a transition to alternate energy sources. Hydrogen particularly green hydrogen looks to be a significant solution for facilitating this transformation as it is produced by water electrolysis with renewable energy sources such as solar irradiations wind speed and biomass residuals. Traditional energy systems are costly and produce energy slowly due to unpredictability in resource supply. To address this challenge this work provides a novel technique that integrates a multi-renewable energy system using multi objective optimization algorithm to meets the machine learning-based forecasted load model. Several forecasting models including Autoregressive Integrated Moving Average(ARIMA) Random Forest and Long Short-Term Memory Recurrent Neural Network (LSTMRNN) are assessed for develop the statistical metrics values such as RMSE MAE and MAPE. The selected Non-Sorting Moth Flame Optimization (NSMFO) algorithm demonstrates technological prowess in efficiently achieving global optimization particularly when handling multiple objective functions. This integrated method shows enormous promise in technological economic and environmental terms emphasizing its ability to promote energy sustainability targets.

A unique hydrogen leak detection strategy is the use of powerless indicator wraps for fittings and other pneumatic elements within a hydrogen facility. One transduction mechanism of such indicators is a color change that is induced by a reaction between a pigment and released hydrogen. This is an effective way to detect hydrogen leaks and to identify their source before they become a safety event however this technology requires visual (manual) inspection to identify a color change or leak. One improvement in this strategy would be to improve the communication of the visual response to an end-user. Element One (E1) has previously developed and introduced DetecTape® a self-fusing silicone non-reversible hydrogen leak detecting tape for application to potential leak sites in hydrogen piping valves and fittings and it has been successfully commercialized with excellent feedback. Element One’s sensors can be fabricated using either pigments or thin films which both change color and conductivity. Neither change requires an external power source. The conductivity change may be communicated as a wireless transmission such as passive radio frequency identification devices (RFID) to an appropriate receiving system where it may be remotely monitored to achieve higher levels of safety and reliability at low cost. Element One will report on its recent progress in the commercial development of remotely monitored hydrogen leak detection using several wireless protocols including passive RFID.

Hydrogen fuel cell electric vehicles (HFCEVs) provide significant environmental benefits. Integrating dual-motor coupling powertrains (DMCPs) further enhances efficiency and dynamic performance. This article proposes an energy management strategy (EMS) for the hydrogen fuel cell/battery/super-capacitor system in an HFCEV with DMCP. Model predictive control (MPC) is adopted as the framework to optimize economic performance defined in this study as the hydrogen consumption cost and fuel cell degradation cost. To improve the prediction horizon and accuracy the torque split ratio for two varying permanent magnet synchronous motors (PMSMs) and the corresponding mode switching rules of the vehicle are initially established. Subsequently a combination of Dynamic Programming (DP) and MPC is selected as the framework utilizing a Dung Beetle Optimizer (DBO)-optimized Bidirectional Long Short-Term Memory (BiLSTM) network to refine the predictive model. Finally comparisons with other predictive models and commonly used control strategies demonstrate that the proposed EMS notably improves economic performance.

The HyDeploy2 project seeks to address a key issue for UK energy customers: how to reduce the carbon they emit in heating their homes. The UK has a world class gas grid delivering heat conveniently and safely to more than 83% of homes. Emissions can be reduced by lowering the carbon content of gas through blending with hydrogen. This delivers carbon savings without customers requiring disruptive and expensive changes in their homes. It also provides the platform for deeper carbon savings by enabling wider adoption of hydrogen across the energy system.

This study investigates the implications of hydrogen demand and trade between Europe and North Africa emphasizing how renewable energy system (RES) capacity limitations impact both regions. Growing hydrogen demand for decarbonization has fueled interest in North Africa’s potential to export green hydrogen to Europe. Using the eTIMES-EUNA model this study examines how demand trade and RES development challenges shape the energy landscapes of both regions. The findings indicate that hydrogen demand amplifies renewable electricity requirements in both regions with Europe particularly benefiting from importing hydrogen to alleviate additional RES capacity installation. Hydrogen trade reduces overall costs by 1 % yet it shifts a considerable financial burden onto North Africa demanding a rapid RES capacity expansion at a rate significantly higher than the current pace. Slower RES development in North Africa could hinder the region’s ability to meet both domestic and export targets thereby complicating Europe’s hydrogen sourcing strategies which are also challenged by social acceptance issues that limit RES deployment. These constraints in Europe necessitate adjustments to the technological mix and place additional pressure on North Africa to increase production. Furthermore the varying implications and stakes at the national level highlight the need for further analysis as individual countries may prioritize their own interests potentially leading to conflicts with neighboring nations under different development schemes. Consequently the results underscore the importance of coordinated financial and policy support to ensure equitable trade that aligns with both regions’ sustainability goals.

Hydrogen production and carbon dioxide removal are considered two of the critical pieces to achieve ultimate sustainability target. This study proposes and investigates a new variation of potassium hydroxide thermochemical cycle in order to combine hydrogen production and carbon dioxide removal synergistically. An alkali metal redox thermochemical cycle developed where the potassium hydroxide is considered by using a nonequilibrium reaction. Also the multigeneration options are explored by using two stage steam Rankine cycle multi-effect distillation desalination Li-Br absorption chiller which are integrated with potassium hydroxide thermochemical cycle for hydrogen production carbon capture power generation water desalination and cooling purposes. A comparative assessment under different scenarios is carried out. The energy and exergy efficiencies of the hydrogen production thermochemical cycle are 44.2% and 67.66% when the hydrogen generation reaction is carried out at 180°C and the separation reactor temperature set at 400°C. Among the multigeneration scenarios a trigeneration option of hydrogen power and water indicates the highest energy efficiency as 66.02%.

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This study proposes four kinds of hybrid source–grid–storage systems consisting of pho‐ tovoltaic and wind energy and a power grid including different batteries and hydrogen storage systems for Sanjiao town. HOMER‐PRO was applied for the optimal design and techno‐economic analysis of each case aiming to explore reproducible energy supply solutions for China’s industrial clusters. The results show that the proposed system is a fully feasible and reliable solution for in‐ dustry‐based towns like Sanjiao in their pursuit of carbon neutrality. In addition the source‐side price sensitivity analysis found that the hydrogen storage solution was cost‐competitive only when the capital costs on the storage and source sides were reduced by about 70%. However the hydro‐ gen storage system had the lowest carbon emissions about 14% lower than the battery ones. It was also found that power generation cost reduction had a more prominent effect on the whole system’s NPC and LCOE reduction. This suggests that policy support needs to continue to push for genera‐ tion‐side innovation and scaling up while research on different energy storage types should be en‐ couraged to serve the needs of different source–grid–load–storage systems.

The analysis of Carbon Footprint (CF) for technology of hydrogen production from cleaned coke oven gas was performed. On the basis of real data and simulation calculations of the production process of hydrogen from coke gas emission indicators of carbon dioxide (CF) were calculated. These indicators are associated with net production of electricity and thermal energy and direct emission of carbon dioxide throughout a whole product life cycle. Product life cycle includes: coal extraction and its transportation to a coking plant the process of coking coal purification and reforming of coke oven gas carbon capture and storage. The values were related to 1 Mg of coking blend and to 1 Mg of the hydrogen produced. The calculation is based on the configuration of hydrogen production from coke oven gas for coking technology available on a commercial scale that uses a technology of coke dry quenching (CDQ). The calculations were made using ChemCAD v.6.0.2 simulator for a steady state of technological process. The analysis of carbon footprint was conducted in accordance with the Life Cycle Assessment (LCA).

The need to drastically reduce greenhouse gas emissions is driving the development of existing and new technologies to produce and use hydrogen. Anion exchange membrane electrolysis is one of these rapidly developing technologies and presents promising characteristics for efficient hydrogen production. However the environmental performance and the material criticality of anion exchange membrane electrolysis must be assessed. In this work prospective life cycle assessment and criticality assessment are applied first to identify environmental and material criticality hotspots within the production of anion exchange membrane electrolysis units and second to benchmark hydrogen production against proton exchange membrane electrolysis. From an environmental point of view the catalyst spraying process heavily dominates the ozone depletion impact category while the production of the membrane represents a hotspot in terms of the photochemical ozone formation potential. For the other categories the environmental impacts are distributed across different components. The comparison of hydrogen production via anion exchange membrane electrolysis and proton exchange membrane electrolysis shows that both technologies involve a similar life-cycle environmental profile due to similar efficiencies and the leading role of electricity generation for the operation of electrolysis. Despite the fact that for proton exchange membrane electrolysis much less material is required due to a higher lifetime anion exchange membrane electrolysis shows significantly lower raw material criticality since it does not rely on platinum-group metals. Overall a promising environmental and material criticality performance of anion exchange membrane electrolysis for hydrogen production is concluded subject to the expected technical progress for this technology.

Hydrogen is seen as a key element for the transition from a fossil fuel based economy to a renewable sustainable economy. Hydrogen can be used either directly as an energy carrier or as a feedstock for the reduction of CO2 to synthetic hydrocarbons. Hydrogen can be produced by electrolysis decomposing water in oxygen and hydrogen. This paper presents an overview of the three major electrolysis technologies: acidic (PEM) alkaline (AEL) and solid oxide electrolysis (SOEC). An updated list of existing electrolysers and commercial providers is provided. Most interestingly the specific prices of commercial devices are also given when available. Despite tremendous development of the PEM technology in the past decades the largest and most efficient electrolysers are still alkaline. Thus this technology is expected to play a key role in the transition to the hydrogen society. A detailed description of the components in an alkaline electrolyser and an analytical model of the process are provided. The analytical model allows investigating the influence of the different operating parameters on the efficiency. Specifically the effect of temperature on the electrolyte conductivity—and thus on the efficiency—is analyzed. It is found that in the typical range of operating temperatures for alkaline electrolysers of 65˚C - 220˚C the efficiency varies by up to 3.5 percentage points increasing from 80% to 83.5% at 65˚C and 220˚C respectively.

Autonomous underwater vehicles (AUVs) are programmable robotic vehicles that can drift drive or glide through the ocean without real-time control by human operators. AUVs that also can follow a planned trajectory with a chosen depth profile are used for geophysical surveys subsea pipeline inspection marine archaeology and more. Most AUVs are followed by a mother ship that adds significantly to the cost of an AUV mission. One pathway to reduce this need is to develop long-endurance AUVs by improving navigation autonomy and energy storage. Long-endurance AUVs can open up for more challenging mission types than what is possible today. Fuel cell systems are a key technology for increasing the endurance of AUVs beyond the capability of batteries. However several challenges exist for underwater operation of fuel cell systems. These are related to storage or generation of hydrogen and oxygen buoyancy and trim and the demanding environment of the ambient seawater. Protecting the fuel cell inside a sealed container brings along more challenges related to condensation cooling and accumulation of inert gases or reactants. This paper elaborates on these technical challenges and describes the solutions that the Norwegian Defence Research Establishment (FFI) has chosen in its development of a fuel cell system for long-endurance AUVs. The reported solutions enabled a 24 h demonstration of FFI's fuel cell system under water. The remaining work towards a prototype sea trial is outlined.

Hydrogen demand estimation for various transport modes supports policy and decision-making for the transition towards a sustainable low-carbon future transport system. It is one of the major factors that determine infrastructure construction production and distribution cost optimisation. Researchers have developed various methods for modelling hydrogen demand and its geographical distribution each based on different sets of predictor variables. This paper systematically reviews these methods and examines the key variables used in hydrogen demand estimation including the number of vehicles travel distance penetration rate and fuel economy. It emphasises the role of spatial analysis in uncovering the geographical distribution of hydrogen demand providing insights for strategic infrastructure planning. Furthermore the discussion underscores the significance of minimising uncertainty by incorporating multiple scenarios into the model thereby accommodating the dynamic nature of hydrogen adoption in transport. The necessity for multi-temporal estimation which accounts for the changing nature of hydrogen demand over time is also highlighted. In addition this paper advocates for a holistic approach to hydrogen demand estimation integrating spatiotemporal analysis. Future research could enhance the reliability of hydrogen demand models by addressing uncertainty through advanced modelling techniques to improve accuracy and spatial-temporal resolution.

Electric bus transit is crucial in reducing greenhouse gas (GHG) emissions decreasing fossil fuel reliance and combating climate change. However the transition to electric-powered buses demands a comprehensive plan for optimal resource allocation technology choice infrastructure deployment and component sizing. This study develops system configuration optimization models for battery electric buses (BEBs) and hydrogen fuel cell buses (HFCBs) minimizing all related costs (i.e. capital and operational costs). These models optimize component sizing of the charging/refueling stations fleet configuration and energy/fuel management system in three operational schemes: BEBs opportunity charging BEBs overnight charging and electrolysis-powered HFCBs overnight refueling. The results indicate that the BEB opportunity system is the most economically viable choice. Meanwhile HFCB requires a higher cost (134.5%) and produces more emissions (215.7%) than the BEB overnight charging system. A sensitivity analysis indicates that a significant reduction in the HFCB unit and electricity costs is required to compete economically with BEB systems.

This brochure provides a detailed overview of the EU’s funding mechanisms and an inspiring look at real projects managed by CINEA. These examples illustrate how diverse stakeholders from industry leaders to research institutions are translating hydrogen ambitions into impactful on-the-ground solutions that address both technological and societal needs.

For low-carbon hydrogen to become a viable decarbonization solution the creation of a robust and effective market is essential. This paper examines the applicability of market reforms from the renewable energy natural gas and liquefied natural gas (LNG) sectors with a focus on pricing mechanisms business models and infrastructure access to facilitate hydrogen market development. Applying the Structure-Conduct-PerformanceRegulation (SCP-R) framework and informed by stakeholder insights we identify critical enablers for advancing the hydrogen market formation. Our analysis highlights the importance of innovative pricing strategies and regulatory measures incentivizing investment and managing risks. Establishing a market reference price for low-carbon hydrogen — akin to benchmarks in the natural gas and LNG sectors—is critical for ensuring transparency predictability and regional adaptability in trade. Additionally customized business models are also needed to mitigate volume risks for producers. Government interventions such as offtake agreements and the development of hydrogen hubs are indispensable for fostering competition and driving decarbonization.

Under the background of energy interconnection and low-carbon electricity integrated energy systems (IES) play an important role in energy conservation and emission reduction. To further promote the low-carbon transition of energy this paper proposes a distributed robust optimal control strategy for IESs based on energy trading. Firstly an IES model that includes an electric hydrogen module and gas hydrogen doping combined heat and power is established and ladder-type carbon trading is introduced to reduce carbon emissions. Secondly for the energy trading issues between photovoltaic (PV) prosumers and IES a bi-level model is constructed using Stackelberg game method where the IES acts as the leader and the PV prosumers as the followers. Noteworthy a distributed robust optimization method is used to address the uncertainty of renewable energy and load. Additionally the Nash bargaining method ensures an equitable balance of benefits among the various IESs and encourages them to participate in market transactions. On this basis an intermediary transaction mode is proposed to address cheating behaviors in trading. Finally the simulation results demonstrate that the proposed strategy not only effectively promotes cooperative operation among multiple IESs but also significantly reduces the system’s operating costs and carbon emissions.

Hydrogen is emerging as a promising future energy medium in a wide range of industries. For mobile applica tions it is commonly stored in a gaseous state within high-pressure composite overwrapped pressure vessels (COPVs). The current state of the art pressure vessel technology known as Type V eliminates the internal polymer gas barrier used in Type IV vessels and instead relies on carbon fibre laminate to provide structural properties and prevent gas leakage. Achieving this functionality at high pressure poses several engineering challenges that have thus far prohibited commercial application. Additionally the traditional manufacturing process for COPVs filament winding has several constraints that limit the design space. Automated fibre placement (AFP) a highly flexible robotic composites manufacturing technique has the potential to replace filament winding for composite pressure vessel manufacturing and provide pathways for further vessel optimi sation. A combination of both AFP and Type V technology could provide an avenue for a new generation of highperformance composite pressure vessels. This critical review presents key work on industry-standard Type IV vessels alongside the current state of Type V CPV technology including manufacturing developments challenges cost relevance to commercial standards and future fabrication solutions using AFP. Additionally a novel Type V CPV design concept for a two-piece AFP produced vessel is presented.

This study presents a comprehensive techno-economic and environmental evaluation of hydrogen production from organic waste feedstocks in Bangladesh utilizing an integrated approach through advanced modelling tools. The research combines H2A (Hydrogen Production Cost Analysis) HDSAM (Hydrogen Delivery Scenario Analysis Model) and H2FAST (Hydrogen Financial Assessment Tool) to assess the feasibility of large-scale hydrogen production distribution and storage. H2A is employed to analyze hydrogen production costs considering various feedstocks and production methods while HDSAM evaluates the delivery pathways and logistics of liquid and gaseous hydrogen. H2FAST is used to perform detailed financial modelling focusing on investment risks profitability and financial metrics of hydrogen projects. This integrated methodology provides a comprehensive analysis of the hydrogen value chain addressing key factors such as production costs logistics and financial feasibility. Main results of the study indicate that hydrogen production costs can range from $2.16/kg to $2.18/kg depending on feedstock efficiency and plant utilization. Financial assessments show that larger-scale hydrogen stations (4000 kg/day) benefit from economies of scale with hydrogen costs dropping to approximately $8.51/kg compared to $12.75/kg for smaller stations (400 kg/day). The study concludes incorporates region-specific data for Bangladesh addressing local challenges such as infrastructure limitations financial constraints and energy demands offering a tailored analysis that can inform future hydrogen projects in Bangladesh and similar developing economies.

Transformation of energy supply systems into green intensifies the use of renewable energy sources. Renewables cannot continuously supply energy. Therefore energy storage systems are very important in the whole system of generation and distribution. Anyway energy storage systems have many issues in terms of sustainability. This paper classified energy storage and analyzed issues in their sustainability solutions. In addition it determines the key performance indicators that define the sustainability of energy storage systems. This analysis determined many sustainability problems presented by the information for each key performance indicator. The least negative impact is shown for the performance of mechanical energy storage and sensible/latent heat storage. The production of green hydrogen green ammonia and biogas showed some negative impact. The worst sustainability is related to energy storage technologies or electrochemical energy storage technologies.

Aviation is one of the most important industries in the current global scenario but it has a significant impact on climate change due to the large quantities of carbon dioxide emitted daily from the use of fossil kerosene-based fuels (jet fuels). Although technological advancements in aircraft design have enhanced efficiency and reduced emissions over the years the rapid growth of the aviation industry presents challenges in meeting the environmental targets outlined in the “Flightpath 2050” report. This highlights the urgent need for effective decarbonisation strategies. Hydrogen propulsion via fuel cells or combustion offers a promising solution with the combustion route currently being more practical for a wider range of aircraft due to the limited power density of fuel cells. In this context this paper designs and models a nitrogen–hydrogen heat exchanger architecture for use in an innovative hydrogen-propelled aircraft fuel system where the layout was recently proposed by the same authors to advance sustainable aviation. This system stores hydrogen in liquid form and injects it into the combustion chamber as a gas making the cryogenic heat exchanger essential for its operation. In particular the heat exchanger enables the vaporisation and superheating of liquid hydrogen by recovering heat from turbine exhaust gases and utilising nitrogen as a carrier fluid. A pipe-in-pipe design is employed for this purpose which to the authors’ knowledge is not yet available on the market. Specifically the paper first introduces the proposed heat exchanger architecture then evaluates its feasibility with a detailed thermodynamic model and finally presents the calculation results. By addressing challenges in hydrogen storage and usage this work contributes to advancing sustainable aviation technologies and reducing the environmental footprint of air travel.

With the growing global focus on hydrogen as a key solution for achieving decarbonization understanding the most cost-effective and environmentally sustainable production methods is crucial. The objective of this study is to evaluate the economic and environmental performance of different renewable energy sources for hydrogen production while also considering the impact of geographic location system sizing and technological efficiency. This study compares the production of green hydrogen powered by onshorewind offshore-wind and solar PV with that of yellow hydrogen (grid-based hydrogen) in terms of cost and environmental impact for a large sample of publicly announced green hydrogen projects in Europe. Using geographic renewable energy data project-specific details and prevailing technological standards we derive each country’s weighted average cost of capital (WACC) to calculate market-based levelized cost of hydrogen. We find onshore-wind projects to have the lowest average levelized cost of green hydrogen followed by offshore-wind and then by solar PV . The costs for yellow hydrogen depend on the price of electricity. Excluding 2022 yellow hydrogen had lower mean costs than solar PV but higher costs than both types of wind. The environmental impact assessment finds significant decarbonization potential for green hydrogen particularly in regions with substantial renewable resources and carbon-intensive energy mixes. The study aggregates the project data at the country level then clusters the analyzed countries based on economic and environmental metrics to derive specific hydrogen strategies. It concludes that substantial governmental support is essential for the large-scale integration of green hydrogen into the energy system to achieve meaningful decarbonization.

This paper investigates the temperature control problem in hydrogen fuel cells based on the improved sliding mode control method specifically within the context of multirotor drone applications. The study focuses on constructing a control-oriented nonlinear thermal model which serves as a foundation for the subsequent development of a practical temperature regulation approach. Initially a novel sliding mode control strategy is proposed which significantly enhances the precision and stability of temperature control by reducing the impact of sensor errors and environmental disturbances. Subsequently the effectiveness and robustness of this control method under various dynamic loads and environmental conditions are demonstrated. The simulation results demonstrate that the improved sliding mode controller is effective in managing and regulating the fuel cell temperature ensuring optimal performance and stability.

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

The marine industry being the backbone of world trade is under tremendous pressure to reduce its environmental impact mainly driven by reliance on fossil fuels and significant greenhouse gas emissions. This paper looks at hydrogen as a transformative energy vector for maritime logistics. It delves into the methods of hydrogen production innovative propulsion technologies and the environmental advantages of adopting hydrogen. The analysis extends to the economic feasibility of this transition and undertakes a comparative evaluation with other alternative fuels to emphasize the distinct strengths and weaknesses of hydrogen. Furthermore based on case studies and pilot projects this study elaborates on how hydrogen can be used in real-world maritime contexts concluding that the combination of ammonia and green hydrogen in hybrid propulsion systems presents increased flexibility with ammonia serving as the primary fuel while hydrogen enhances efficiency and powers auxiliary systems. This approach represents a promising solution for reducing the shipping sector’s carbon footprint enabling the industry to achieve greater sustainability while maintaining the efficiency and scalability essential for global trade. Overall this work bridges the gap between theoretical concepts and actionable solutions therefore offering valuable insights into decarbonization in the maritime sector and achieving global sustainability goals.

Solid oxide electrolysis (SOEL) has emerged as a promising technology for efficient hydrogen production. Its main advantages lie in the high operating temperatures which enhance thermodynamic efficiency and in the ability to supply part of the required energy in the form of heat. Nevertheless improving the long-term durability of stack materials remains a key challenge. Thermal energy can be supplied by dedicated integration with different industrial processes where the main challenge lies in the elevated stack operating temperature (700–900 ◦C). This review provides a comprehensive analysis of the integration of solid oxide electrolysis cells (SOECs) into different industrial applications. Main processes cover methanol production methane production Power-to-Hydrogen systems or the use of reversible solid oxide electrolysis cell (rSOEC) stacks that can operate in both electrolysis and fuel cell mode. The potential of co-electrolysis to increase process flexibility and broaden application areas is also analyzed. The aim is to provide a comprehensive analysis of the integration strategies identify the main technical and economic challenges and highlight recent developments and future trends in the field. A detailed comparison assessment of the different processes is being discussed in terms of electrical and thermal efficiencies and operating parameters as well as Key Performance Indicators (KPIs) for each process. Technical-economic challenges that are currently a barrier to their implementation in industry are also analyzed.

The increasing need for environmentally friendly energy sources has contributed to the development of innovative technologies that also resolve environmental issues. Hydrogen can be produced in a number of ways including using fossil fuels biomass and renewable energy sources like wind and sun. Using renewable energy for water-based production is the most sustainable method of producing hydrogen. However since fresh water is scarce the main way to address this issue is to use wastewater. Although wastewater is frequently seen as an issue it could additionally be seen as a valuable source of energy as it has the potential to produce bio-hydrogen. The current review emphasizes the key conclusion of studies examining the viability of the generation of hydrogen from wastewater by applying a variety of technologies in order to investigate each method’s potential which effectively removes pollutants from wastewater addressing both environmental challenges of wastewater treatment as well as clean energy production. Hydrogen production from wastewater using sustainable lowenergy methods enhances energy recovery in treatment plants and promotes a circular economy. This lowcarbon hydrogen supports global decarbonization and simultaneously achieving pollutant degradation with advanced systems offers dual benefits over traditional wastewater treatment methods. The essential details of 7 emerging technologies their working mechanisms affecting parameters work advances advantages and disadvantages and their future prospects are taken into consideration in 2 distinct classes- light-independent and light-dependent technologies.

Presented is an evaluation of the carbon footprint and costs associated with hydrogen production via the aluminum-water reaction (AWR) identifying an optimized scenario that achieves 1.45 kgCO2 equiv per kg of hydrogen produced. U.S.-based data are used to compare results with conventional production methods and to assess hydrogen use in fuel-cell passenger vehicles. In the optimized scenario major contributors include the use of recycled aluminum (0.38 kgCO2 equiv) aluminum processing (0.45 kgCO2 equiv) and alloy activator recovery (0.57 kgCO2 equiv). A cost analysis estimates hydrogen production at $9.2/kg when using scrap aluminum alloy recovery and recycling thermal energy aligning with current green hydrogen prices. Reselling reaction byproducts such as boehmite could generate revenue 5.6 times greater than input costs enhancing economic feasibility. The cradle-to-grave assessment suggests that aluminum fuel as an energy carrier for hydrogen distribution and fuel cell vehicle applications offers a low-emission and economically viable pathway for clean energy deployment.

The rapid growth in natural gas consumption by gas-fired generators and the emergence of power-to-hydrogen (P2H) technology have increased the interdependency of natural gas and power systems presenting new challenges to energy system operators due to the heterogeneous uncertainties associated with power loads renewable energy sources (RESs) and gas loads. These uncertainties can easily spread from one infrastructure to another increasing the risk of cascading outages. Given the erratic nature of RESs P2H technology provides a valuable solution for large-scale energy storage systems crucial for the transition to economic clean and secure energy systems. This paper proposes a new approach for the co-optimized operation of gas and electric power systems aiming to reduce combined operating costs by 10–15% without jeopardizing gas and energy supplies to customers. A mixed integer non-linear programming (MINLP) model is developed for the optimal day-ahead operation of these integrated systems with a case study involving the IEEE 24-bus power system and a 20-node natural gas system. Simulation results demonstrate the model’s effectiveness in minimizing total costs by up to 20% and significantly reducing renewable energy curtailment by over 50%. The proposed approach supports UN Sustainable Development Goals by ensuring sustainable energy (SDG 7) fostering innovation and resilient infrastructure (SDG 9) enhancing energy efficiency for resilient cities (SDG 11) promoting responsible consumption (SDG 12) contributing to climate action (SDG 13) and strengthening partnerships (SDG 17). It promotes clean energy technological innovation resilient infrastructure efficient resource use and climate action supporting the transition to sustainable energy systems.