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

Interfacial tension and wettability alteration during hydrogen and carbon dioxide storage in depleted gas reservoirs DOI Creative Commons
Mohammad Rasool Dehghani,

Seyede Fatemeh Ghazi,

Yousef Kazemzadeh

et al.

Scientific Reports, Journal Year: 2024, Volume and Issue: 14(1)

Published: May 21, 2024

Abstract The storage of CO 2 and hydrogen within depleted gas oil reservoirs holds immense potential for mitigating greenhouse emissions advancing renewable energy initiatives. However, achieving effective necessitates a thorough comprehension the dynamic interplay between interfacial tension wettability alteration under varying conditions. This comprehensive review investigates multifaceted influence several critical parameters on alterations IFT during injection hydrogen. Through meticulous analysis pressure, temperature, treatment duration, pH levels, presence nanoparticles, organic acids, anionic surfactants, rock characteristics, this elucidates intricate mechanisms governing changes in reservoir environments. By synthesizing recent experimental theoretical advancements, aims to provide holistic understanding processes underlying alteration, thereby facilitating optimization efficiency long-term viability as carbon capture or solutions. insights gleaned from offer invaluable guidance researchers, engineers, policymakers engaged harnessing sustainable solutions environmental conservation. synthesis knowledge serves foundational resource future research endeavors aimed at enhancing efficacy reliability reservoirs.

Language: Английский

Citations

11
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
The influence of methyl orange on the CO2-brine wettability of organic-acid-aged calcite samples: Implications for CO2 geo-storage DOI Open Access
Fatemah Alhammad, Mujahid Ali, Nurudeen Yekeen

et al.

ADVANCES IN GEO-ENERGY RESEARCH, Journal Year: 2024, Volume and Issue: 12(2), P. 102 - 112

Published: April 4, 2024

The underground storage of CO2 in a depleted carbonate formation is suitable method for limiting its anthropogenic release and minimize global warming. rock wettability an essential factor controlling the mechanisms trapping containment safety geo-storage formation. contains innate organic acids which alters surface from hydrophilic condition to hydrophobic state, thus reduce capacity. In this study, methyl orange toxic dye that generally released into environment was used as modifier change stearic acid aged calcite (oil wet) water wet. This study uses contact angle technique (sessile drop method) examine effects various concentration (10-100 mg/L) on CO2/brine/stearic-acid system under conditions (i.e., temperatures 25 50 ℃ pressures 5-20 MPa). results indicate advancing receding angles (θa θr) organic-acid contaminated were drastically reduced upon exposure orange, attaining minimum values 62◦ 58◦ respectively, presence 100 mg/L at 20 MPa ℃. Thus, present suggest rather than discharging environment, it could be injected reservoirs order level environmental pollution same time increase capacity formations. Document Type: Original article Cited as: Alhammad, F., Ali, M., Yekeen, N., Kamali, Iglauer, S., Keshavarz, A. influence CO2-brine organic-acid-aged samples: Implications geo-storage. Advances Geo-Energy Research, 2024, 12(2): 102-112. https://doi.org/10.46690/ager.2024.05.03

Language: Английский

Citations

5
The effect of methylene blue on stearic acid-aged quartz/CO2/brine wettability: Implications for CO2 geo-storage DOI Creative Commons
Fatemah Alhammad, Mujahid Ali, Nurudeen Yekeen

et al.

Gas Science and Engineering, Journal Year: 2024, Volume and Issue: 125, P. 205316 - 205316

Published: April 7, 2024

Carbon dioxide sequestration in geological formations has been proposed as a promising solution to reach net zero carbon emissions but the success of underground CO2 storage sandstone depends on brine/CO2 wettability sandstone. Research evidence showed that natural formation is hydrophobic even presence minute concentration inherent organic acids. This study investigates effect methylene blue (MB) organic-acid contaminated quartz through tilted plate contact angle measurement method. Pure substrates were aged stearic acid/n-decane for one week and subsequently modified with different concentrations MB (ranging from 10 100 mg/L) at temperature 60 °C. Advancing (θa) receding (θr) angles measured under varying conditions (25 °C 50 °C), pressure 20 MPa), salinity (0-0.3 M). The experimental results indicate pure quartz, when acid solution, becomes CO2-wet all temperature, pressure, conditions. However, any physio-thermal condition, surfaces was reversed treated MB, transitioning water-wet state. findings this research demonstrate potential modify wetting behaviour enhance residual trapping

Language: Английский

Citations

4
Effect of Imidazolium-Based Ionic Liquids on the Sandstone Reservoir’s Wettability: Implications for CO2 Geo-Storage DOI
Sivabalan Sakthivel, Safwat Abdel‐Azeim, Vishnu Chandrasekharan Nair

et al.

Energy & Fuels, Journal Year: 2024, Volume and Issue: 38(15), P. 14502 - 14513

Published: July 16, 2024

In the context of CO2 geological storage, understanding interplay interfacial tension (IFT) and wettability dynamics within CO2–brine–rock system plays a huge role in improving their storage capacity ensuring secure containment. Ionic liquids (ILs) emerge as promising surface-active agent that has potency to alter reservoir's more toward water-wet state, thereby increasing oil recovery. However, potential ILs remained unexplored for enhancing storage. Hereby, we assess effect on modification sandstone reservoirs by measuring rock–brine–CO2 contact angles (CA). this context, conducted CA measurements both clean crude oil-aged samples, with without ILs, at broad ranges IL concentrations (0–1000 ppm), temperatures (25–80 °C), pressures (14.7–3000 psi). This approach is designed evaluate saline aquifers oil-depleted reservoirs. Additionally, also explored impact CO2–seawater (SW) IFT. Findings indicate sample maintained nature; however, treatment shifted its strongly state. While oil-wet samples were initially identified be CO2-wet, upon they an intermediate Molecular (MD) simulations undertaken get atomistic insights into rock changes CO2–SW interface. MD revealed alters surface charge, which induces changes. Such charge development result pH modifications induced affect silanol group density. The addition was found reduce charge. adsorbed screens rock–CO2 interactions, maintaining alteration poised significantly improve efficiency, reducing security risks are associated it. finding highlights efficiency can greatly improved preliminarily injecting before flooding minor concentration. It worth highlighting observed SW–CO2 IFT relatively minimal, indicating favorable condition capillary trapping. Furthermore, investigated exhibit exceptional stability, solubility, detectability, scalability, economic viability; thus, preinjection these solutions will make them robust containment reservoir conditions.

Language: Английский

Citations

3
Coal–Fluid Interfacial Tension in the Coal–Water–CO2 System: Implications for CO2 Sequestration in Coal Seams DOI
Chao Cui, Yanbin Yao, Dameng Liu

et al.

Energy & Fuels, Journal Year: 2024, Volume and Issue: 38(12), P. 10801 - 10812

Published: June 1, 2024

CO2 geological sequestration in coal seams is an effective method for reducing emissions and enhancing coal-bed methane extraction. In this context, the coal–fluid interfacial tension (γcoal–fluid) a critical parameter that influences injection, fluid distribution, storage capacity, containment safety. Especially, γcoal–fluid cannot be directly measured, influencing factors (including γcoal−CO2 γcoal–water coal–water–CO2 system) were not reported before. study, we calculated of different rank coals under pressures (3–8 MPa) temperatures (40–70 °C) by using combination Young's equation Neumann's equation. The results show all samples decreases with increasing pressure rank, while it increases temperature. slightly Furthermore, conducted comprehensive investigation into influence mechanism underlying these on quantitatively established assessment model. Based this, also proposed methodology determination threshold pore size caprock (TPSC) evaluation sealing security. TPSC increase burial, more water-wetting corresponds to lower TPSC. This study contributes deeper understanding wetting phenomenon system provides insight monitoring safety reservoirs.

Language: Английский

Citations

1
Pore Structure Alteration of Shale with Exposure to Different Fluids: The Longmaxi Formation Shale in the Sichuan Basin, China DOI Open Access
Shuwen Zhang,

Ziyi Shen,

Yan He

et al.

Minerals, Journal Year: 2023, Volume and Issue: 13(11), P. 1387 - 1387

Published: Oct. 30, 2023

The interaction between shale and various fluids is crucial as it modifies pore structures, which govern the effective development of gas geological storage carbon dioxide in formations. In this study, samples from Longmaxi Formation Sichuan Basin China were exposed to different fluids, including 6 MPa CO2, 12 CO2+brine, at 45 °C for 100 days. Various methods, X-ray diffraction (XRD), fluorescence (XRF), field-emission scanning electron microscopy (FESEM), low-pressure adsorption (N2) test, adopted evaluate chemical structural changes during exposure process. After being treated with supercritical CO2+brine subcritical underwent significant its major element composition. content Ca, Al, K saturated decreased 13.00% 10.34%, 3.65% 3.36%, 1.56% 1.37%, respectively. Meanwhile, Si Na same increased slightly after saturation. amount quartz dolomite increased, while levels clay calcite decreased. surface sample became rougher small bumps cracks appeared saturation shown by FESEM analysis results. Furthermore, both total volume size followed a similar pattern alterations specific areas. highest level variation occurred that was indicating pressure CO2 phase state have influence on shale’s structure. addition, distribution sizes showed bias towards larger across all diameters; suggests reaction resulted decrease number micropores. This also highlights impact varying fluid primarily focused micropores macropores. results study provided experimental evidence further test mechanisms permeability organic-rich self-sourced shale.

Language: Английский

Citations

3
Novel Environmentally Friendly Nanomaterials for Drag Reduction of the Emulsified Acid System DOI Creative Commons
Ala AL-Dogail, Rahul Gajbhiye, Theis I. Sølling

et al.

ACS Omega, Journal Year: 2023, Volume and Issue: 8(46), P. 44057 - 44075

Published: Nov. 8, 2023

Matrix acidizing is a technique that widely used in the petroleum industry to remove scales and create channels rock. Removal of creation (wormhole) enhance productivity. Conventional fluids, such as hydrochloric acid (HCl) for carbonate mixture hydrofluoric (HF) HCl acid, are matrix process. However, these fluids have some drawbacks, including strong strength, corrosion at high temperatures, quick reactions with scale particles. Emulsified systems (EASs) address drawbacks. EASs can deeper narrower wormholes by reducing reaction rate due external oil phase. much higher viscosity compared conventional fluids. The leads drag restricts pumping rates consumes energy. This study aims utilize environmentally friendly available nanomaterials drag-reducing agents (DRAs) EAS. this carbon nanodots (CNDs). CNDs unique properties diverse applications different industries. size usually smaller than 10 nm. characterized their biocompatibility chemical stability. investigates use DRAs Several experiments been conducted investigate DRA developed EAS was initially tested conductivity drop-test analysis ensure formation an inverted emulsion. Thereafter, thermal stability range temperatures rheological were evaluated meet criteria field operation. Then flow before after adding efficacy reduction EASs. results revealed be reducers EAS, where reduces two concentrations (15 20%). It presence inhibitors well other additives showing its compatibility formulation. observed investigated study. conductivity, stability, rheology sample taken experiment consistent, ensuring work DRA. robust terms mixing procedures thermally stable. which will reduce pipes, increasing saving

Language: Английский

Citations

1
Critical Review on Wettability, Optimal Wettability, and Artificial Wettability Alteration in Rock-brine-CO2 systems for Geologic Carbon Sequestration DOI
Abouzar Mirzaei‐Paiaman, Ryosuke Okuno

Gas Science and Engineering, Journal Year: 2024, Volume and Issue: unknown, P. 205499 - 205499

Published: Nov. 1, 2024

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