Hydrogen Supply Research Articles

Towards building clean hydrogen supply chain network in Iran for future domestic demand and exports. Part I: Prioritization of scenarios

The first part of the current study highlights the importance of developing a clean hydrogen supply chain (CHSC) in Iran to enhance energy security and contribute to global efforts towards sustainable energy transition. Depending on whether the focus is on domestic consumption or export of hydrogen, the study provides valuable insights into the prioritization of CHSC development pathways via multi-criteria decision-making tools (AHP, AHOP-TOPSIS, and AHP-VIKOR). The results show that for domestic hydrogen consumption (internal scenario), the best path of the supply chain includes blue hydrogen from steam methane reforming coupled with carbon capture and storage, H2-carriers (ammonia and methanol), natural gas grid for transportation and distribution, and industry sector as the end user. In the external scenario, however, the best path of the CHSC consists of green hydrogen production based on solar energy, and the other parts of the path include liquid hydrogen as the storage method, ship as the distribution and transportation, and industrial sector as the end user. By identifying the most suitable methods and technologies for each stage of the supply chain, this paper offers a comprehensive analysis that can guide decision-making in CHSC development.

Investigation of monovalent Li and divalent Ni doping in Co3O4 for enhanced hydroelectric cell performance

The hydroelectric cell (HEC) produces green power at room temperature using non-photocatalytic water splitting. To achieve this goal, pure Ni (Nickel) and lithium (Li) substituted in cobalt oxide (Co3O4), a mesoporous oxygen-deficient material, is introduced. The substance splits water into H3O+/OH− ions by an electrolytic chain reaction, resulting in a 1.06 V potential difference between the electrodes. LCO-based HEC produced 39 mW of peak output (Pout) at 1.06 V. EPR spectroscopy and EIS curve have confirmed the presence of oxygen defects and ionic diffusion in Li-doped cobalt oxide materials. Similar to solar cells, an LCO-based HEC offers a low-cost, water-based method of producing green energy with the extra benefit of being able to function in the dark. The process also produces hydrogen gas (green hydrogen technology), which creates prospects for the manufacture of hydrogen, diversifying hydrogen supply chain options and developing new routes for industrial decarbonization, globally.

Using a design exploration model to assess the global techno-economic feasibility of far offshore green hydrogen production towards 2050

With space constraints onshore, strong renewable resources available far offshore and growing green hydrogen demand, far offshore green hydrogen production may be an attractive option. To assess this potential, a mixed integer quadratically constraint programming (MIQCP) optimization model was developed to find the cost per kilogram of far offshore green hydrogen in specific scenarios. The design of the far offshore green hydrogen supply chain was optimized with this model for six high potential scenarios in varying locations and the results were analyzed. It was found that far offshore green hydrogen costs are in the same order of magnitude as the costs of its alternatives. Far offshore green hydrogen may be considered marginally competitive with these alternatives from 2035 onwards in the analyzed scenarios when taking into account the considerable advantages of far offshore production, such as avoidance of scarce land usage in crowded areas and certain geopolitical considerations.

Techno-economic analysis and comparison of hydrogen supply using offshore wind power sources on the coast of the Korean peninsula

In response to the rapidly changing industry caused by climate change, the Korean government has set a goal of supplying 3 million tons of green hydrogen by 2050. This study aims to determine the leveled cost of hydrogen (LCOH) resulting from floating offshore wind power generation. Initially, we created a numerical model to represent the power curve for large-capacity offshore wind power generation. Additionally, we accounted for the variability in electrolytic cell efficiency by modeling predictions based on real PEMEC parameters using the Aspen Custom Model. The power-hydrogen quantity was then predicted using Aspen Plus. A comparison is also made regarding the transportation of gaseous hydrogen and liquid hydrogen. Gaseous hydrogen is produced through pipelines, while liquid hydrogen is produced using a modified Claude cycle and transported via trucks. Finally, a Techno-economic analysis was conducted, considering the net present value (NPV) derived from capital expenditure (CAPEX) and operating expenditure (OPEX) throughout the entire process. The analysis of LCOH indicated that the most economically viable option for the region with the lowest LCOH per kg is the supply of liquid hydrogen, priced at $11.04/kgH2. Our sensitivity analysis also reveals that while liquid hydrogen is more cost-effective at up to 250 MW, gaseous hydrogen becomes cheaper as its scale exceeds 500 MW because of its greater sensitivity to production volume.

Characterized on hydrogen properties and mechanism of Al–Sn–Bi composite powder in salt solutions

Using low-melting point elements to promote the Al/H2O reaction has garnered considerable attention because it is an economical approach to hydrogen supply. Herein, .Al–Sn–Bi composite powder was prepared through milling. The Al–Sn–Bi composite powder and the hydrolysate were investigated using X-ray diffraction (XRD) and scanning electron microscope (SEM). The results show that the hydrolysis products is primarily AlOOH. The properties of the Al/H2O reaction were systematically characterized in salt solutions. Results show that the presence of Sn and Bi is beneficial to achieve short introduction times and large Al/H2O reaction rates. The hydrogen generation rate of the Al–Sn–Bi composite is 4566 mL min−1 g−1 and 3600 mL min−1·g−1 with NaCl and Na2SO4 solutions, respectively and the hydrogen production efficiency can reach 100% in 1 min. Additionally, the mechanism of Sn and Bi promoting Al/H2O reaction was characterized by density functional theory (DFT) calculations. The DFT calculations show that Sn and Bi replace 1/8 ML, 1/4 ML and 1/2 ML surface atoms of Al (111), the surface chemical potential increases with increasing doping concentration, and the electrode potential decreases with increasing doping concentration. The presence of Sn and Bi increases the surface chemical potential and reduces the electrode potential, this is conducive to the microcell reaction and promotes the Al/H2O reaction.

Multinetwork constrained planning of hydrogen-power supplying facilities under double-layer coupling mechanisms

The proliferation of hydrogen fuel cell vehicles calls for effective planning of hydrogen supply facilities. This paper focuses on renewable energy-based distributed hydrogen supply networks (DHSNs), with on-site production and vehicle-based transport. To explore the energy synergism effect, we propose multinetwork constrained planning of hydrogen-power supplying facilities. Considering the double-layer coupling mechanism (DCM), multiple DHSN equipment planning is coordinated with the generation planning of the power distributed networks (PDN). Firstly, the DCM is proposed considering structured multi-component equipment, inter-layer hydrogen couplings, and cross-network power couplings. Secondly, to formulate the DCM, we develop a structured deployment model for DHSN equipment to enhance system integrality and non-redundancy. Specially, to release more flexibilities, inter-layer transport is modeled by proposing a spatiotemporal extended vehicle routing problem model incorporating multiple loading stations with trip coordination. Thirdly, a planning method is proposed to coordinate the planning of hydrogen-power supply facilities in coupled networks, incorporating the double-layer coupling constraints, station operation constraints, and PDN constraints. Test systems are employed to verify the effectiveness of the proposed method.

Process modelling for the production of hydrogen-based direct reduced iron in shaft furnaces using different ore grades

This process modelling study explored the behaviour of hydrogen-based direct reduced iron (DRI) manufacturing in a shaft furnace. Various performance parameters such as metallisation ratio (MR), consumption of hydrogen per tonne of DRI, production of by-products, reactor energy demand and total energy demands for the process have been analysed with respect to temperature, ore grade (gangue content), and reactant conditions. The HSC Chemistry (H: enthalpy, S: entropy and C: heat capacity) SIM (simulation) module was employed for the modelling coupled with the Gibbs energy minimisation calculation. The shaft furnace was divided into three zones to model the three-step reduction of iron ore in a counterflow arrangement. Results show that temperature and hydrogen supply have a significant effect on the metallisation of DRI. Increasing temperature and hydrogen flow rate were predicted to increase the MR or reducibility. A full metallisation can be achieved with hydrogen supply of 130, 110, 100 and 90 kg/tDRI at 700, 800, 900 and 1000°C, respectively, using the best-grade ore (Fe 69 wt.%, gangue 5.2 wt.%). However, the hydrogen consumption in full metallisation was calculated to be 54 kg/tDRI (tonne of DRI). At full MR, the reactor energy consumption (supplementary electrical energy) was calculated to be 0.56 to 0.59 MWh/t Fefeed using the reactor temperature from 700 to 1000°C. Ore grade or gangue content has a significant impact on reactor energy demand. For example, at 900°C, the top-grade ore was calculated to consume 0.69 MWh/tDRI compared to 0.88 MWh/tDRI using the lowest grade ore. A certain percentage of CO (i.e. 15%) blended with hydrogen was predicted to be beneficial for metallisation, hydrogen consumption, and overall energy demand. However, increasing CO would increase CO2 emissions significantly.

Germany's Way from Russian Natural Gas to Green Hydrogen: Network Data, Procedures, and Topologies for Feasible Transition Paths to a Green Hydrogen Transport Infrastructure in Germany, GreenHyDE [gri:n'haɪ̯də] –

Hydrogen—and thus hydrogen transport—will play an important role in the German and European transition to climate neutrality. A German hydrogen transport network is currently being planned, but its appropriate structure and size highly depend on the spatial distribution of hydrogen demand and supply and their development over time. Moreover, the security of supply with both, hydrogen and natural gas, needs to be guaranteed during the transition period, as repurposing of the existing natural gas transmission system is a highly advantageous option for the building of hydrogen networks. Therefore, the integrated analysis of natural gas and hydrogen networks is a necessary and urgent, though complex, field of research. For this purpose, the article presents the database for the existing German natural gas transmission system (which in parts will be repurposed for hydrogen transport) and procedures for the development and evaluation of network topologies for both gases. The results for the German case show feasible development steps for the design of green hydrogen transport networks and the transition from natural gas in different scenarios. Open access to data and tools for technoeconomic assessment is provided.

A New Transportation Route Planning Method for Wind-Based Hydrogen Supply Chains

A New Transportation Route Planning Method for Wind-Based Hydrogen Supply Chains

Modeling and Control of Ejector-Based Hydrogen Circulation System for Proton Exchange Membrane Fuel Cell Systems

Ejector-based proton exchange membrane fuel cells (PEMFCs) are of great interest due to their simplicity and feasibility. Thus, proton exchange membrane fuel cells are considered the most suitable technology for in-vehicle systems, industrial applications, etc. Despite the passive characteristics of the ejector, active control of the hydrogen supply system is needed to ensure sufficient hydrogen, maintain the stack pressure, and ensure effective entrainment. In this research, a novel semi-empirical model is proposed to accurately predict the entrainment performance of the ejector with an 80 kW fuel cell system. According to the precise semi-empirical model, the hydrogen supply system and the anode channel are modeled. Then, a fuzzy logic controller (FLC) is developed to supply sufficient and adequate gas flow and maintain the rapid dynamic response. Compared to the conventional proportional–integral–derivative controller, the fuzzy logic controller could reduce the anode pressure variability by 5% during a stepped case and 2% during a dynamic case.

Financial dynamics, green transition and hydrogen economy in Europe

The introduction of the Next Generation funding scheme provides an opportunity for the EU-25 to make significant financial progress towards a radical and fully sustainable Green economy. This study examines the financial implications of a complete transition to hydrogen energy. In this paper, we propose the Hydrogen Production Safe Supply and Storage energy model by analyzing the conversion of electricity from offshore wind farms to hydrogen, which serves as both an energy storage and fuel for a variety of sectors, including transportation, households, industries, and governments. We analyze the financial impact of the Green transition across the EU-25 economies, based on a panel auto-regressive distributed lag model and the simulation procedure proposed by Jordan and Philips (2018). In addition to electricity production and consumption, the variables used include greenhouse gas emissions, real output per capita, and total environmental tax revenue. According to the study's financial insights, increased renewable electricity production results in a significant reduction in household energy consumption, as well as an increase in consumption in the transportation, industrial, and public sectors. These findings underscore the economic implications of transitioning to renewable energy and highlight the financial imperatives, such as targeted state aid, the immediate expansion of the hydrogen supply network, further research on safe mobile hydrogen containment, and an extensive upgrade of the regional hydrogen supply network within the EU-25.

Multi-option analytical modeling of levelized costs across various hydrogen supply chain nodes

Hydrogen is envisioned to become a fundamental energy vector for the decarbonization of energy systems. Two key factors that will define the success of hydrogen are its sustainability and competitiveness with alternative solutions. One of the many challenges for the proliferation of hydrogen is the creation of a sustainable supply chain. In this study, a methodology aimed at assessing the economic feasibility of holistic hydrogen supply chains is developed. Based on the designed methodology, a tool which calculates the levelized cost of hydrogen for the different stages of its supply chain: production, transmission & distribution, storage and conversion is proposed. Each stage is evaluated individually, combining relevant technical and economic notions such as learning curves and scaling factors. Subsequently, the findings from each stage are combined to assess the entire supply chain as a whole. The tool is then applied to evaluate case studies of various supply chains, including large-scale remote and small-scale distributed green hydrogen supply chains, as well as conventional steam methane reforming coupled with carbon capture and storage technologies. The results show that both green hydrogen supply chains and conventional methods can achieve a competitive LCOH of around €4/kg in 2030. However, the key contribution of this study is the development of the tool, which provides a foundation for a comprehensive evaluation of hydrogen supply chains that can be continuously improved through the inputs of additional users and further research on one or more of the interconnected stages.

Multi-period hydrogen supply chain planning for advancing hydrogen transition roadmaps

The global commitment to the Paris Agreement has triggered the development of national hydrogen strategies and roadmaps in numerous countries. For seamless execution of a hydrogen strategy, the model employed in roadmap optimization must consider intricate operational details. This study offers a comprehensive multi-period model for hydrogen supply chain (HSC) expansion planning, spanning production to distribution. The model optimizes facility timing, location, type, and capacity while considering efficient operational strategies. Hydrogen, sourced diversely, anchors the supply chain, supported by precise calculations for road-based transport and pipelines. Storage facilities adapt to supply sources and transportation methods, addressing supply-demand fluctuations and transport interruptions. Hydrogen refueling stations (HRS) are optimized for efficient urban distribution. Analyzing South Korea's HSC in this model reveals a shift towards green hydrogen in later stages, initially relying on refineries and imports. Investments transition from pipelines to liquid (LH2) and gaseous (GH2) hydrogen trucks in the early phases, eventually incorporating NH3 tanker trucks. The model predicts a decreasing levelized cost of hydrogen (LCOH), reaching $3.89/kg through HSC expansion planning. The model predicts a decreasing LCOH, reaching $3.89/kg through strategic HSC expansion. Transportation costs, playing a significant role in the final LCOH, are crucial for South Korea to achieve its target of 3000 KRW/kg. These results offer valuable insights for nations advancing hydrogen initiatives, providing a detailed cost breakdown model to guide policy planning and achieve HSC and LCOH objectives effectively. Also, the study showcases Korea's adeptness in transitioning to a hydrogen-based economy.

High‐Density Rare‐Earth Single‐Atom‐Triggered Unconventional Transition of Adsorption Configuration on La1Pd Monatomic Alloy Metallene for Sustainable Electrocatalytic Alkynol Semi‐Hydrogenation

AbstractElectrocatalytic alkynol semi‐hydrogenation for the high‐value chemicals alkenol with mild conditions and carbon‐free emission is a potentially green and sustainable alternative to conventional thermocatalytic routes, which generally involves the design of electrocatalysts with high activity and high selectivity. Here, the rare‐earth single‐atom (Ln = La, Nd, Pr) coordinated Pd metallene (Ln1Pdene) is reported for electrocatalytic 2‐methyl‐3‐butyn‐2‐ol (MBY) semi‐hydrogenation reaction (MBY ESHR) to synthesis of 2‐methyl‐3‐buten‐2‐ol (MBE). Typically, in alkaline medium containing 0.1 m MBY, MBY conversion and MBE selectivity of La1Pdene are as high as ≈97% and ≈95%, respectively, with excellent electrocatalytic stability. Meanwhile, in situ infrared spectra reveal the conversion of MBY to MBE during the dynamic electrocatalytic process. Theoretical calculations reveal that the interaction between La single‐atom and Pd host triggers an unconventional transformation of the intermediate MBE* adsorption configuration during electrocatalytic hydrogenation, achieving the optimal desorption energy between La1Pd and target product and optimizing the reaction energy barriers to inhibit the over‐hydrogenation of MBE. Moreover, La single‐atom as the adsorption active site of the hydrogen supplier H2O effectively reduces the competition adsorption between the reactants MBY and H2O, rendering La single‐atom and Pd host as the synergistic co‐catalytic active sites to promote the electrocatalytic MBY semi‐hydrogenation reaction.

Charting a path to low-carbon leadership: unlocking up to 90% emissions reductions in greenfield LNG

The liquefied natural gas (LNG) industry stands at the cusp of a transformation driven by the climate imperative. Focussing on the Middle Arm Industrial Precinct, this paper shows how carbon dioxide (CO2) emissions are being reduced in a proposed world-class LNG project by assessing, screening and selecting known technologies using a Marginal Abatement philosophy linked to key emissions drivers. (1) We propose a new breed of electrified LNG facilities that could deliver an up to 90% reduction in CO2 intensity. (2) We show that through developing strategic partnerships in upstream renewable power, hydrogen supply, and enabled downstream carbon capture and storage (CCS), the significant low carbon energy requirements of an LNG facility can be delivered. (3) We discuss a Marginal Abatement assessment strategy which ensures a pathway to viable lowest cost opportunities selected in an ‘Avoid & Mitigate’ first approach. This proposed strategy ensures that CO2 emission reduction opportunities are assessed and selected consistently to determine both a lifecycle cost ($) and volume (tons CO2e) of emission reduction. These innovative strategies collectively articulate a roadmap for a low carbon future for LNG and other heavy industrial industries, underlining Australia’s potential to become a leading provider of low-carbon natural resources.

Hydrogen carriers – transporting hydrogen from producers to export power markets

As a global energy transition community there is a lot of talk about producing hydrogen in Australia, South America, the Middle East and now the USA, and transporting that as an energy source to markets such as Japan, Korea, Singapore and Europe. How will we do this, what are the carriers available, and what are the advantages and challenges of each? This is a practical assessment of the situation highlighting where we need to focus our efforts as a global community and Australia’s role in enabling hydrogen supply chains of the future to succeed.

Australia–Japan energy partnerships for regional security and decarbonisation

Australia and Japan stand at a pivotal juncture in their energy futures, with shared imperatives of ensuring energy security, affordability, and sustainability. As key players in the global energy landscape, their collaboration holds the potential to shape the trajectory of the Indo-Pacific’s energy transition, as outlined in Japan’s ‘New Plan for a Free and Open Indo-Pacific’ (FOIP). A central aspect of this collaboration involves securing liquefied natural gas (LNG) supplies from Australia to Japan and the region while simultaneously decarbonising the supply chain through carbon capture and storage (CCS) and advancing hydrogen technologies. Both nations recognise the significance of natural gas in ensuring regional energy security and affordability. Japan, heavily reliant on energy imports, particularly LNG, is motivated by past crises and geopolitical tensions to diversify its energy sources. The partnership between Australia and Japan not only addresses Japan’s energy needs but also influences the power dynamics within the Indo-Pacific. Challenges such as regulatory uncertainties and policy shifts dampen confidence for Japanese investors in Australia’s energy sector. Despite this, CCS technology offers a promising pathway to reduce emissions from natural gas production, with infrastructure facilitating low-emission hydrogen production. Policy coherence and streamlined regulations are essential to fostering innovation and scaling up these technologies. Collaboration on CCS and hydrogen commercialisation presents opportunities for both nations to lead the energy transition. Japan’s ambitious plans to increase its domestic hydrogen supply highlight the potential for joint efforts.

Cushion Gas Consideration for Underground Hydrogen Storage

Due to the increasing world population and environmental considerations, there has been a tremendous interest in alternative energy sources. Hydrogen plays a major role as an energy carrier due to its environmentally benign nature. The combustion of hydrogen releases water vapor while it also has a vast industrial application in aerospace, pharmaceutical, and metallurgical industries. Although promising, hydrogen faces storage challenges. Underground hydrogen storage (UHS) presents a promising method of safely storing hydrogen. The selection of the appropriate cushion gas for UHS is a critical aspect of ensuring the safety, efficiency, and reliability of the storage system. Cushion gas plays a pivotal role in maintaining the necessary pressure within the storage reservoir, thereby enabling consistent injection and withdrawal rates of hydrogen. One of the key functions of the cushion gas is to act as a buffer, ensuring that the storage pressure remains within the desired range despite fluctuations in hydrogen demand or supply. This is achieved by alternately expanding and compressing the cushion gas during the injection and withdrawal cycles, thereby effectively regulating the overall pressure dynamics within the storage facility. Furthermore, the choice of cushion gas can have significant implications on the performance and long-term stability of the UHS system. Factors such as compatibility with hydrogen, cost-effectiveness, availability, and environmental impact must be carefully considered when selecting the most suitable cushion gas. The present study provides a comprehensive review of different types of cushion gases commonly used in UHS, including nitrogen, methane, and carbon dioxide. By examining the advantages, limitations, and practical considerations associated with each option, the study aims to offer valuable insights into optimizing the performance and reliability of UHS systems. Ultimately, the successful implementation of UHS hinges not only on technological innovation but also on strategic decisions regarding cushion gas selection and management. By addressing these challenges proactively, stakeholders can unlock the full potential of hydrogen as a clean and sustainable energy carrier, thereby contributing to the global transition towards a low-carbon future.

Innovative Design of Solid-State Hydrogen Storage and Proton Exchange Membrane Fuel Cell Coupling System with Enhanced Cold Start Control Strategy

This paper presents an innovative thermally coupled system architecture with a parallel coolant-heated metal hydride tank (MHT) designed to satisfy the hydrogen supply requirements of proton exchange membrane fuel cell s(PEMFCs). This design solves a problem by revolutionising the cold start capability of PEMFCs at low temperatures. During the design process, LaNi5 was selected as the hydrogen storage material, with thermodynamic and kinetic properties matching the PEMFC operating conditions. Afterwards, the MHT and thermal management subsystem were customised to integrate with the 70 kW PEMFC system to ensure optimal performance. Given the limitations of conventional high-pressure gaseous hydrogen storage for cold starting, this paper provides insights into the challenges faced by the PEMFC-MH system and proposes an innovative cold start methodology that combines internal self-heating and externally assisted preheating techniques, aiming to optimise cold start time, energy consumption, and hydrogen utilisation. The results show that the PEMFC-MH system utilises the heat generated during hydrogen absorption by the MHT to preheat the PEMFC stack, and the cold start time is only 101 s, which is 59.3% shorter compared to that of the conventional method. Meanwhile, the cold start energy consumption is reduced by 62.4%, achieving a significant improvement in energy efficiency. In conclusion, this paper presents a PEMFC-MH system design that achieves significant progress in terms of time saving, energy consumption, and hydrogen utilisation.

How government policies promote transportation utilization in the national-level hydrogen supply chain: A case of China

Pipeline transportation is a low-cost option for delivering large volumes of hydrogen (H2), however, the high initial capital cost remains a major impediment to expanding pipeline delivery infrastructure. To quantitatively evaluate the impact of the H2 pipeline on the hydrogen supply chain (HSC), this paper develops an evaluation system for the development potential of the H2 pipeline and simulation models for H2 resource allocation. Furthermore, the HSC system in the southwest of China is used to validate the proposed method. The results demonstrate that the levelized cost range of a given 150–550 km H2 pipeline is 2.76–10.12 CNY/kg, which has price advantages over other transportation modes. Compared with the hydrogen supply chain resource allocation (HSCR) model, putting the H2 pipeline into use can optimize the layout and utilization of different transportation modes. It shows that the proportion of H2 transportation volume distribution in H2 pipelines has increased from 0 % to 73.44 %, while the proportion of HLT has first increased from 18.86 % to 54.27 %, and then decreased to 17.95 %. And then under different policy scenarios, the consideration of pipeline reduces the sensitivity of the H2 blending ratio of natural gas (NG) and NG demand to HSC. The impacts of policies on regional H2 development and regional policy implications are revealed. This approach provides a tool for policymakers to quantify the impacts of policy.