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Economically feasible and optimized process development for the commercialization of liquid hydrogen (LH 2) is vital because the cooling system of a H 2 liquefaction setup requires considerable energy. Liquefied natural gas (LNG) cold energy can be used for H 2 liquefaction to facilitate efficient production of LH 2. In this study, we evaluated three scenarios of a novel H 2 liquefaction process at a scale of 300 tons/day utilizing LNG cold energy. Subsequently, a comparative study of the energy analysis, economic evaluation, and environmental evaluation was conducted. Among the three scenarios, the scenario that used LNG cold energy directly had the lowest minimum selling price (MSP) and environmental impact. The discounted cash flow rate of return for this project was 12.98%. Our results demonstrated that the use of LNG cold energy can improve the economic and environmental feasibility of H 2 liquefaction. [Display omitted] • H 2 is an environmentally safe and sustainable fuel that can replace fossil fuels. • Liquid H 2 overcomes the storage and transport limitations of gaseous hydrogen. • Using liquefied natural gas (LNG) cold energy produces liquid H 2 efficiently. • Using LNG cold energy can improve the feasibility of hydrogen liquefaction. [ABSTRACT FROM AUTHOR]

Hydrogen is a prominent clean fuel option for combatting global warming and producing low-emission, ecologically friendly electricity. Consequently, the proton exchange membrane water electrolysis (PEMWE) hydrogen refueling station has undergone thorough economic and environmental analysis. This work intends to fill the gap by presenting the influence of various operating circumstances and design parameters on the economic and environmental aspects of PEMWE based on various behaviors and features (I–V curve) under various scenarios. Profitability analysis (PA) is performed in terms of the net present value (NPV), discounted payback period (DPBP), benefit-cost ratio (BCR), and internal rate of return (IRR) from cumulative discounted cash flow diagrams (CFD). Also, sensitivity analysis (SA) is conducted to assess the impact of different economic factors, while simultaneously establishing CO 2 footprint guidelines for optimal operating and design conditions. The findings highlight that enhancing economic feasibility and reducing environmental concerns are simultaneously achievable by increasing cathode pressure, operating temperature, and decreasing membrane thickness. At membrane thicknesses over 100 μm, the project becomes unprofitable and inefficient at 1.85 V. PEMWE becomes more valuable and sustainable with a current density of 12,000 A/m2 or higher, but it releases more CO 2 emissions. Hence, utilizing excess renewable electricity in PEMWE addresses environmental concerns and enhances the overall ecological sustainability of hydrogen production. [ABSTRACT FROM AUTHOR]

A large-scale hydrogen supply chain is an alternative for the transportation of energy generated from a renewable energy source. Utilizing this technology would drastically improve the generation of clean energy. Therefore, an analysis method to estimate the economic and environmental benefits of the introduction of a hydrogen supply chain using an existing pipeline is developed. The proposed method first estimates the energy and exergy flows in the system to calculate the overall efficiency of these quantities. Afterward, the payback period is estimated based on the overall energy efficiency using the discounted cash flow (DCF) method. The overall efficiency of the system, based on the energy analysis presented, would seem to be the final delivered electrical, fuel and useable heat energy delivered to end use divided by the input solar and wind energy. Furthermore, the environmental effects due to the introduction of the systems are evaluated considering the reduction of global warming and air pollution gases, such as CO 2 and PM2.5. The proposed analysis method was applied considering a natural gas pipeline that connects Qinghai and Shanghai. As a result, conversion ratios of 24.9% for electricity and 17.5% for heat were achieved, with the overall efficiency of the system of 42.4% based on the electricity obtained from photovoltaics. 3.02 Gt of CO 2 , 104 kt of SO x , and 134 kt of NO x , which represent 3.3%, 0.5%, and 0.6% of the annual discharge in China, respectively, and 8.66 kt of PM2.5 would be reduced every year. Furthermore, a reduction of 953 Mt in coal consumption is expected. The payback period of the proposed system using the DCF method is 4.17 and 2.28 years for the two alternatives evaluated in this work. The cash flow of the DCF is influenced by installation cost and operation cost of equipment. • Introductory method of a hydrogen supply chain using gas pipeline was shown. • Economic and environmental benefits were clarified from the energy flow. • Potentiality of a large-scale clean energy using hydrogen was suggested. • Gas pipeline currently installed between Qinghai and Shanghai was analyzed. [ABSTRACT FROM AUTHOR]

This study aims to assess the potential risks of setting up a hydrogen infrastructure in the Netherlands. An integrated risk assessment framework, capable of analyzing projects, identifying risks and comparing projects, is used to identify and analyze the main risks in the upcoming Dutch hydrogen infrastructure project. A time multiplier is added to the framework to develop parameters. The impact of the different risk categories provided by the integrated framework is calculated using the discounted cash flow (DCF) model. Despite resource risks having the highest impact, scope risks are shown to be the most prominent in the hydrogen infrastructure project. To present the DCF model results, a risk assessment matrix is constructed. Compared to the conventional Risk Assessment Matrix (RAM) used to present project risks, this matrix presents additional information in terms of the internal rate of return and risk specifics. [ABSTRACT FROM AUTHOR]

The energy transition for a net-zero future will require deep decarbonisation that hydrogen is uniquely positioned to facilitate. This technoeconomic study considers renewable hydrogen production, transmission and storage for energy networks using the National Electricity Market (NEM) region of Eastern Australia as a case study. Plausible growth projections are developed to meet domestic demands for gas out to 2040 based on industry commitments and scalable technology deployment. Analysis using the discounted cash flow technique is performed to determine possible levelised cost figures for key processes out to 2050. Variables include geographic limitations, growth rates and capacity factors to minimise abatement costs compared to business-as-usual natural gas forecasts. The study provides an optimistic outlook considering renewable power-to-X opportunities for blending, replacement and gas-to-power to show viable pathways for the gas transition to green hydrogen. Blending is achievable with modest (3%) green premiums this decade, and substitution for natural gas combustion in the long-term is likely to represent an abatement cost of AUD 18/tCO2-e including transmission and storage. [ABSTRACT FROM AUTHOR]

• Techno-economic evaluation of H 2 production by APR and SR of glycerol is performed. • Sensitivity analysis, profitability analysis, and risk analysis were accomplished. • TCOP for APR plant is 3.55 $/kgH 2 regarding the equipment purchased costs. • TCOP for SR plant is 3.65 $/kgH 2 regarding the equipment purchased costs. • TCOP mostly influenced by compressor cost, glycerol price, and discount rate. In this paper, a comparative techno-economic evaluation of hydrogen production by glycerol reforming in aqueous and gaseous phases are presented. To accomplish the techno-economic evaluation, firstly the process modeling and design are presented. Based on the equipment purchased costs, with 80 kg/h hydrogen production, the total cost of hydrogen production is estimated 3.65 and 3.55 $/kgH 2 for steam reforming and aqueous phase reforming plants, respectively. Regarding the installation factor in the equipment costs, the total cost of hydrogen production is estimated 7.49 and 7.45 $/kgH 2 for steam reforming and aqueous phase reforming plants, respectively. To investigate the impact of independent parameters and profitability of the proposed plants, sensitivity analysis, cumulative discounted cash flow diagram, net present value, and discounted payback period are introduced. Additionally, to quantify the uncertainties in proposed plants, Monte-Carlo simulation method with ±50% variation of the key influential parameters is applied. Lastly, it is shown that the aqueous phase reforming process is the optimum choice based on the techno-economic evaluation. [ABSTRACT FROM AUTHOR]