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

Nanofluid-assisted enhanced sealing security for efficient geological hydrogen storage in Saudi Arabian basalt DOI Creative Commons
Muhammad Ali, Nurudeen Yekeen, Sarmad Al‐Anssari

et al.

Journal of Energy Storage, Journal Year: 2024, Volume and Issue: 97, P. 112768 - 112768

Published: July 1, 2024

The modification of hydrophobic rock surfaces to the water-wet state via nanofluid treatment has shown promise in enhancing their geological storage capabilities and efficiency carbon dioxide (CO2) hydrogen (H2) containment. Despite this, specific influence silica (SiO2) nanoparticles on interactions between H2, brine, within basaltic formations remains underexplored. present study focuses effect SiO2 wettability Saudi Arabian basalt (SAB) under downhole conditions (323 K pressures ranging from 1 20 MPa) by using tilted plate technique measure contact angles H2/brine surfaces. findings reveal that SAB's hydrophobicity intensifies presence organic acids, with significant increases both advancing (θa) receding (θr) upon exposure acid at 323 MPa. Contrastingly, application these results a marked shift towards hydrophilicity, θa θr decreasing substantially, thus indicating an optimal nanoparticle concentration (0.1 wt% SiO2) for effecting transition H2-wet states. This change aligns known pressure-dependent behavior angles. Moreover, organically-aged 0.1 nanofluids MPa enhances H2 column height significantly, −424 m 4340 m, suggesting reduced risk migration across caprock thereby structural/residual trapping containment security Arabia. article highlights crucial role improving efficacy basalt, offering new insight optimization solutions hydrogen, critical component sustainable energy future.

Language: Английский

Citations

8
Inversion and optimization of CO2+O2in situ leaching of blasting-stimulated sandstone-type uranium deposits DOI
Qinghe Niu, Jie Wang,

Jiabin He

et al.

Physics of Fluids, Journal Year: 2025, Volume and Issue: 37(3)

Published: March 1, 2025

Using blasting to induce fracture networks within rock mass is one of the effective reservoir stimulation methods for low-permeability sandstone-type uranium deposits. Nonetheless, there remains a deficiency suitable theoretical investigate impact CO2+O2in situ leaching on blasting-stimulated In this work, reaction-flow numerical model based fractures was first established; second, simulations blasting-induced in six injection and two extraction well groups were performed. Finally, entire process simulated under various parameters predict effect CO2+O2 Results show that trend increasing then decreasing between peak pressure recovery rate, reaching its maximum at 1000 MPa. The deposits influenced by matrix permeability, O2 concentration, HCO3− average grade. grade are positively correlated with providing sufficient seepage space required material composition leaching. However, rate negatively because it reduces reaction time agent important ranking factors affecting concentration period 900 days > permeability concentration. This study serves as reference selecting optimizing technology during field tests.

Language: Английский

Citations

0
Effects of methyl orange on the H2/brine wettability of carbonate rocks: Implications for H2 geo-storage DOI Creative Commons
Fatemah Alhammad, Mujahid Ali, Nurudeen Yekeen

et al.

Journal of Energy Storage, Journal Year: 2024, Volume and Issue: 102, P. 114076 - 114076

Published: Oct. 16, 2024

Language: Английский

Citations

3
Effect of Methyl Orange and Methylene Blue on the Wettability of Organic Acid Aged Sandstone and Carbonate Formations: Implication for CO2 and H2 Geo-Storage. DOI

Alhammad Fatemah,

Ali. Mujahid,

Iglauer Stefan

et al.

Published: Oct. 11, 2024

Abstract Underground storage of carbon dioxide (CO2) and hydrogen (H2) in geological formations has been considered an effective method for the energy transition towards a low-carbon industry. The wettability rock is significant parameter underground gas storage, determining both capacity containment safety. This study focuses on using two chemicals, methyl orange (MO) methylene blue (MB), as wetting agents at different concentrations (10 to 100 mg/L) change improve CO2 H2. To achieve this, contact angle measurement technique was utilised measure advancing (θa) receding (θr) angles under reservoir conditions, with constant pressure 13 MPa system 20 system, temperatures 25°C 50°C, brine salinity 0.3 M NaCl. mimic surfaces calcite quartz samples were treated stearic acid before being exposed agent chemicals. Although these are hydrophobic, modifying their even very trace concentration MO or MB significantly alters from hydrophobic hydrophilic. demonstrates that presence organic acids can affect H2 rock. However, injecting diluted amount into sandstone carbonate increase capacity.

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