Search

The current status of the hydrogen supply infrastructure was investigated to understand progress toward the realization of a hydrogen society. We also tried to help develop a proper strategy for the soft landing of the hydrogen industry by analyzing the roll-out strategy in Korea, one of the first movers into the hydrogen industry. First, the hydrogen supply infrastructure was analyzed. 96% of hydrogen is produced from fossil fuels, with the steam methane reforming method being the most widely used. Hydrogen is usually stored in compressed gas form and transported to refueling stations to consumer via tube trailers or pipelines depending on the delivery distance. Next, the characteristics of the hydrogen infrastructure in countries were examined. Each country tries to produce and supply hydrogen by utilizing existing industrial facilities. The USA and Japan produce hydrogen via natural gas (NG) reforming over 90% and transport the gas using exited pipelines. While the EU produces hydrogen from renewable energy sources, and considering importing the gas from EU members. Finally, we introduced a roll-out strategy for Korea as guidelines for second-mover countries. Korea mainly produces hydrogen as a by-product in existing liquid NG facilities, as well as importing liquefied hydrogen from abroad. Since most hydrogen is transported via pipelines, it is unevenly distributed across the country. Attempts at solving this imbalance in the supply of hydrogen will be by applying hydrogen extractors in local plants or developing electrolysis technologies. The Korean government offers subsidies to encourage the participation of private companies to expand the installation of hydrogen refueling stations. Through the supports, the government try to decrease the price of hydrogen gas to 2500 won/kg until 2050. Our findings provide the current status of hydrogen society development and can be used to suggest guidelines for the development of proper hydrogen-fueling strategies for countries. • The current status of the hydrogen supply infrastructure in countries was investigated. • Each country tries to produce hydrogen by utilizing existing industrial facilities. • Hydrogen is usually stored in compressed gas form. • Hydrogen gas is transported via tube trailers or pipelines. • Roll-out strategy for Korea is introduced as guidelines for second-mover countries. [ABSTRACT FROM AUTHOR]

This research continues our inquiries into the technological and economic potential for hydrogen production in Russia [1]. The significant changes in global political and economic conditions in 2021 are taken into account. In 2022, Europe's energy market reflected a shortage of thermal and electrical energy. The energy policy of the European Union (EU) is analyzed; this policy was approved in 2005 and has been formalized in several editions of the EU's renewable energy directive. Special attention is paid to the trend in European toward renewable energy sources. [ABSTRACT FROM AUTHOR]

The abundance and uneven distribution of renewable energy might cause congestion and curtailment in electric power systems. Transmission expansions can potentially alleviate transmission congestion and reduce renewable energy curtailment. On the other hand, with the substantial cost reduction of electrolyzer technology and the continuing rise of hydrogen demand, converting surplus renewable energy to hydrogen provides synergistic benefits to power and hydrogen systems, but consequently requires joint planning of the two systems. To this end, we propose a joint planning approach for power transmission and hydrogen transportation networks to coordinately optimize the investment and operation of power and hydrogen infrastructure. In our proposed model, detailed truck routing, pipeline, and hydrogen storage are formulated to quantify the flexibility of hydrogen transportation system. A robust joint planning approach is also proposed to address various uncertainties from renewable energy, electric load, and hydrogen demand. Our numerical simulations show that the proposed joint planning model can save the total system cost, reduce renewable energy curtailment, and increase the utilization level of transmission lines. [ABSTRACT FROM AUTHOR]

The renewable energy-based hydrogen production can lead to the integrated electric power and hydrogen system (IPHS) and offer a pathway to a sustainable energy utilization. Hydrogen is mainly transported via hydrogen tube trailers (HTs), making the hydrogen energy system (HES) operation quite different from those of other energy technologies. This paper proposes an optimal IPHS operation strategy which utilizes HT for transportation. The proposed strategy coordinates hydrogen generation, transportation, and storage stages considering constrained operations of electric power system (EPS), transportation system, and variable renewable energy. The proposed solution method is based on the alternating direction method of multipliers (ADMM) in which HES and EPS constraints are managed individually and the respective solutions are coordinated accordingly. The case studies using the modified IEEE-RTS79 have verified the validity of the proposed IPHS model and its solution method and confirmed the necessity of considering HES in enhancing the EPS operation. The synergies between EPS and HES are studied via numerical examples and the impact of the flexibilities in hydrogen generation, transportation and demand are highlighted. [ABSTRACT FROM AUTHOR]

The current work presents a process that separates hydrogen from mixtures with natural gas transported in the natural gas grid. The aim is to achieve hydrogen at fuel cell quality (99.97% (v/v) according to ISO 14687-2:2012). Due to gas grid regulations in Austria the hydrogen content is limited to a maximum of 4% (v/v). In a hybrid approach based on membrane separation and pressure swing adsorption (PSA) the supplied high pressure hydrogen – natural gas mixture (up to 120 bar) is pre-enriched by membrane technology and further upgraded to the required quality by PSA. The majority of the feed gas is kept at grid pressure, which ensures a high energetic efficiency. The remaining components, separated by PSA, are re-compressed and returned to the grid. Beside the technological feasibility, the influence of various process parameters (e.g. stage-cut, permeate conditions, PSA hydrogen recovery) is analysed. Based on the results, the required amount of energy of 0.8–1.5 kWh / m 3 (fuel-cell quality hydrogen at 25.81 bar(a)) is calculated for the so called HylyPure ® process. [ABSTRACT FROM AUTHOR]

Hydrogen, of which the application is limited due to the difficulties in finding the ideal transportation material, has been considered the alternative for petroleum as the main energy source. With its large surface area and other extraordinary physical properties, carbon nano-scroll (CNS) has been the focus of many researchers as the promising candidate for hydrogen storage and transportation. In this work, the transportation characteristics of hydrogen atoms through CNS have been investigated by MD simulations. We found that, by pumping the hydrogen atoms from the reservoir, more hydrogen atoms are likely to attach to the inner layer of CNS instead of leaking into the air. And the average velocity of the hydrogen atoms moving inside the CNS tube is decreasing throughout the simulation. Moreover, the CNS is observed to be slightly tilted and deformed due to the strain energy induced by the interaction between hydrogen and carbon atoms. In addition, effect of the pumping speed on the transportation properties has been studied as well. We conclude that, with greater pumping speed, the hydrogen atoms are more likely to escape into the air. Furthermore, the bigger the diameter of the CNS, the greater number of hydrogen atoms are to be absorbed and leaked as well. Lastly, the effect of the CNS length on the transportation properties has also been studied. We found that, towards the end of the simulations, cases with longer CNS exhibit higher hydrogen leak. And the average velocities of the hydrogen atoms moving in the CNS tube in these cases are also greater. [ABSTRACT FROM AUTHOR]

This article presents a comprehensive approach for estimating the development of global production and supply costs of low-carbon hydrogen from renewable energy sources (onshore wind, offshore wind and solar photovoltaics) and natural gas (natural gas reforming with carbon capture and storage and natural gas pyrolysis) until 2050. The analysis also assesses the costs associated with the transportation of hydrogen by ship or pipeline. The combination of production and transportation costs yields a ranking of cost-optimal supply sources for individual countries. Estimation results suggest that natural gas reforming with carbon capture and storage will be the most cost-efficient low-carbon hydrogen production pathway in the medium term (2020–2030). Production of hydrogen from renewable energy sources could become competitive in the long run (2030–2050) if capital costs decrease significantly. Until 2050, minimum production costs for hydrogen from renewable energy sources could fall to $1.5/kg under central assumptions and to below $1/kg under optimistic assumptions in some regions. The cost-optimal long-term hydrogen supply depends on regional characteristics, such as renewable energy potentials and gas prices. Imports of hydrogen from renewable energy sources are cost-effective where domestic production potential is small and/or cost-intensive. Additionally, good import conditions exist for countries which are connected to prospective low-cost exporters via existing natural gas pipelines that can be retrofitted to transport hydrogen. Due to the high cost of seaborne transport, hydrogen trade will most likely develop regionally along pipeline networks. • Comprehensive assessment of future global low-carbon H2 production and supply costs. • H2 from natural gas is more cost effective than from RES the medium-term (2030). • H2 from RES is potentially cost competitive in the long-term (2050). • H2 trade will most likely be pipeline-based and thus concentrated regionally. • The optimal long-term H2 supply mix varies significantly between countries/regions. [ABSTRACT FROM AUTHOR]

• Sizing algorithm of a hydrogen system in the electricity and transportation markets. • Simulation of water electrolysis, hydrogen mass transfer and fuel cell operation. • Evaluation of the investment prospects of hydrogen systems operating in the markets. • Acceptable hydrogen fuel price calculated to range between 3.6 and 15 €/kgH 2. • A fuel cell system for grid support should be at least 70% cheaper to be viable. The power capacity of renewable energy sources is constantly increasing through the installation of new units, primarily comprising the most mature technologies such as wind and solar energy converters, as well as through the implementation of innovative technologies that are currently at an infant stage of development. The aim of this study was to investigate the prospects of implementing hydrogen technologies in the electricity network as an electricity production unit or/and utilise the produced hydrogen as transportation fuel. Three main scenarios were identified to be the most appropriate for this: (1) Support of the electrical grid via a fuel cell; (2) participation of a hydrogen production and fuel cell system in the electricity and transportation markets; and (3) participation in the transportation market. The results indicated that a fuel cell generator providing ancillary services is not economically viable in the investigated case study, while implementing a hydrogen production unit with a hydrogen fuel selling price between 4 and 114 €/kgH 2 , depending on the electrolyser's power input, will yield positive results. For the third scenario, the hydrogen fuel price ranged between 3.6 and 15.0 €/kgH 2. This research shows that hydrogen technologies can be used in the electricity and transportation markets from a technical point of view. However, from an economic point of view, a hydrogen system used only for a single application does not seem to be financially appealing. This suggests that reducing the investment cost and/or limiting operating costs is mandatory to support this type of investment. [ABSTRACT FROM AUTHOR]