Influence of Chitosan Salt on Capillary Pressure and Interfacial Tensions of CO2/Brine and H2/Brine Systems DOI
Ahmed Al‐Yaseri, Nurudeen Yekeen, Mahmoud A. Abdulhamid

et al.

Energy & Fuels, Journal Year: 2024, Volume and Issue: unknown

Published: Dec. 4, 2024

There is increasing interest in attainment of a CO2-free global economy and net zero carbon emissions by 2050 to mitigate the negative impact warming unfavorable climate change. However, success large-scale underground H2 CO2 storage depends on rock wetting behavior dynamics gas/brine interfacial tension (IFT), which significantly influences capillary pressure. Previous studies have demonstrated that wettability can be altered into hydrophilic state using surface-active chemicals such as surfactants, nanoparticles, methyl orange, blue. these also showed higher propensity reduce IFT, for residual structural trapping potential host rock. Herein, limestone modification capacity polymeric surfactant (chitosan salt) its impacts CO2/brine H2/brine IFT were evaluated pendant drop technique pressure measurement. Results shifted right presence chitosan salt solutions, indicating reduction needed push water pore spaces This effect increased with concentrations solution from 100 1000 ppm. Specifically, at 200 psi, saturation seawater-saturated cores about 50 70% whereas deionized water-saturated 25 40% ppm concentration. The CO2/water interface H2/water no significant effects tension. Moreover, adsorption DI seawater molecules was salt, suggesting promotes adhesion H2O but discourages Our results generally modify hydrophobic rocks, turning them wet while mitigating could increase Hence, geo-storage rocks promising strategy derisking optimizing formations.

Language: Английский

Converting underground natural gas storage for hydrogen: A review of advantages, challenges and economics DOI
Peng Deng, Zhangxin Chen, Xiaolong Peng

et al.

Renewable and Sustainable Energy Reviews, Journal Year: 2025, Volume and Issue: 213, P. 115438 - 115438

Published: Feb. 8, 2025

Language: Английский

Citations

3
Molecular Insights into Geochemical Reactions of Iron-Bearing Minerals: Implications for Hydrogen Geo-Storage DOI
Hyeonseok Lee, Ruyi Zheng, Liangliang Huang

et al.

ACS Sustainable Chemistry & Engineering, Journal Year: 2025, Volume and Issue: unknown

Published: March 12, 2025

Language: Английский

Citations

0
An Experimental and Modelling Study of H2S Scavenging in Calcite/Iron-Bearing Formations DOI
Khosro Jarrahian, K. S. Sorbie,

Farhana Jaafar Azzudin

et al.

SPE International Conference on Oilfield Chemistry, Journal Year: 2025, Volume and Issue: unknown

Published: April 2, 2025

Abstract H2S capture is an important area of research maximizing the level trapping and subsequently permanently retaining in subsurface. One objectives current field development program to investigate geochemical interaction with iron minerals carbonate how mineralize efficiently reservoir. The main objective this develop a static geochemistry model experiments these ideas. Dynamic pack floods testing was conducted by packing mixture calcite (siderite or hematite) borosilicate chromatography column, subsequent flooding H2S-containing 1% Na+ (10000ppm Distilled Water) through column at ambient conditions. An unreactive lithium tracer used determine pore volume porosity packs, which analyzed inductively coupled plasma-optical emission spectroscopy (ICP-OES). In addition, outlet samples packs were collected zinc quenching solution enabling total sulphide concentrations be back-calculated measured [H2S] each stage. FeS precipitated Environmental Scanning Electron Microscopy/Energy Dispersive X-Ray (ESEM-EDX). Moreover, dynamic pH effluent pH-meter as well scavenging capacity quantified. A also developed governing H2S/FeCO3/CaCO3/FeS system. results showed that pure pack, not scavenged due absence agent (Iron minerals) inlet same [H2S]. ESEM/EDX no detected, just some precipitate NaCl precipitation from solution. However, calcite/iron mineral less than injected because reaction siderite/hematite resulting mineralisation packs. dissolves (rock dissolution), then free Fe2+ reacts precipitated. Again, detected tracers Sulphur formation Furthermore, it shown work hematite (Fe2O3) higher siderite (FeCO3). Also, mixing ratio minerals, greater scavenged. final (pHf~8) dissolution leading liberation Ca2+ few Fe2+. second round 1%Na+, [Ca2+]/[Fe2+] generated in-situ first flooding. reaches amount Ca2+/Fe2+ while solution, more are generated.

Language: Английский

Citations

0
Reservoir Simulation-Informed Cost-Benefit Analysis for Structural Assessment: A Case Study of Hydrogen Geostorage in the Ahuroa Gas Field, Aotearoa New Zealand DOI
David Dempsey,

Matt Parker,

Jinjiang Liu

et al.

Published: Oct. 11, 2024

Abstract As hydrogen production increases around the world, subsurface porous media such as depleted gas reservoirs are being considered for buffer storage of large volumes renewable gas. In Aotearoa New Zealand, Ahuroa reservoir in Taranaki region is a possible site to be converted into underground (UHS). However, from structural perspective, this incompletely characterized, with differing model interpretations arising because only 2D seismic data and well intercepts available. study, based on exiting data, two geological models (curved fault tear model) were built. The same scenario was evaluated both study impact geometric uncertainty UHS performance. To migration scenarios reservoir-fault system, we use workflow that integrates Leapfrog Energy modeling PFLOTRAN-OGS simulation. Our describes cyclic injection hydrogen/methane mixtures water-wet reservoirs, quantifying operational performance respect undetermined geometry transmissibility. Simulation results indicate less cushion required but more ultimately unrecoverable distant beyond spill point. Economically, cost additional trades off against loss, which order several tens millions dollars. findings highlight value robust modelling seek build an economic case further acquisition reduce uncertainty.

Language: Английский

Citations

0
Investigation of Gas Behaviors in Caprock for Understanding Gas Leakage During Underground Hydrogen Storage DOI
Qiuhao Chang, David Dempsey, Liangliang Huang

et al.

Published: Oct. 11, 2024

Abstract Given their efficient gas seals, depleted hydrocarbon reservoirs are one of the most promising underground porous media for large-scale storage hydrogen. However, H2 has a smaller molecular mass/size which could contribute to higher rate diffusion through caprock, leading losses during process. Hence, understanding behaviors H2in pores caprock is prerequisite application hydrogen in reservoir. In this study, adsorption and self-diffusion cushion gases CH4/N2 were studied quartz nanopores under geological condition 343 K 15 MPa via dynamics simulations. The results show that onto pore wall occurred all three gases. Using competitive analyses, we find likely prefers adsorb CH4 rather than N2. with only 1 nm width, space an status. larger width such as 5 or 10 nm, part would be free condition. Due weight, compared N2, largest nanopores. Moreover, effect on was observed. As decreased, decreased. goal study provide deeper insight into behavior explore mechanisms leakage caprock.

Language: Английский

Citations

0
Simulations of Interfacial Tension for H2/H2S/Water and CH4/H2S/Water Systems at the Temperature of 298 K and Pressure up to 30 MPa DOI
Qiuhao Chang, David Dempsey, Liangliang Huang

et al.

Published: Oct. 11, 2024

Abstract In 2020, hydrogen production reached around 90 million metric tons (Mt) and this is expected to keep increasing year by toward the global net-zero target. Traditional large-scale storage methods such as cryogenic tank salt caverns may eventually be unable meet local requirements. It has been suggested that depleted hydrocarbon reservoirs with a large volume can accommodate larger-scale production. However, stored gas co-exist residual H2S in reservoir or produced geochemical reactions injected microorganism activity. As mixture composition affect interfacial tension (IFT) between pore water, dynamics fate of H2 may, part, determined effects under conditions. study, tensions H2/H2S/water CH4/H2S/water systems were function concentration at 298 K different pressures. The results show gas-water IFT concentrations decreased pressure increased from 10 14.5 MPa. For pressures higher than MPa, effect on IFTs was relatively smaller. Furthermore, lower temperature those 343 same condition. addition, our simulation even low 10% would also when using two other types cushion gas: CO2 N2. contribution study provide expressions for water various mixtures involving CH4, H2, species conditions reservoirs.

Language: Английский

Citations

0
Influence of Chitosan Salt on Capillary Pressure and Interfacial Tensions of CO2/Brine and H2/Brine Systems DOI
Ahmed Al‐Yaseri, Nurudeen Yekeen, Mahmoud A. Abdulhamid

et al.

Energy & Fuels, Journal Year: 2024, Volume and Issue: unknown

Published: Dec. 4, 2024

There is increasing interest in attainment of a CO2-free global economy and net zero carbon emissions by 2050 to mitigate the negative impact warming unfavorable climate change. However, success large-scale underground H2 CO2 storage depends on rock wetting behavior dynamics gas/brine interfacial tension (IFT), which significantly influences capillary pressure. Previous studies have demonstrated that wettability can be altered into hydrophilic state using surface-active chemicals such as surfactants, nanoparticles, methyl orange, blue. these also showed higher propensity reduce IFT, for residual structural trapping potential host rock. Herein, limestone modification capacity polymeric surfactant (chitosan salt) its impacts CO2/brine H2/brine IFT were evaluated pendant drop technique pressure measurement. Results shifted right presence chitosan salt solutions, indicating reduction needed push water pore spaces This effect increased with concentrations solution from 100 1000 ppm. Specifically, at 200 psi, saturation seawater-saturated cores about 50 70% whereas deionized water-saturated 25 40% ppm concentration. The CO2/water interface H2/water no significant effects tension. Moreover, adsorption DI seawater molecules was salt, suggesting promotes adhesion H2O but discourages Our results generally modify hydrophobic rocks, turning them wet while mitigating could increase Hence, geo-storage rocks promising strategy derisking optimizing formations.

Language: Английский

Citations

0