Fundamental aspects, mechanisms and emerging possibilities of CO2 miscible flooding in enhanced oil recovery: A review

Fuel, Journal Year: 2022, Volume and Issue: 330, P. 125633 - 125633

Published: Aug. 26, 2022

Language: Английский

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Assessment of wettability and rock-fluid interfacial tension of caprock: Implications for hydrogen and carbon dioxide geo-storage

International Journal of Hydrogen Energy, Journal Year: 2022, Volume and Issue: 47(30), P. 14104 - 14120

Published: March 11, 2022

Underground hydrogen (H2) storage (UHS) and carbon dioxide (CO2) geo-storage (CGS) are prominent methods of meeting global energy needs enabling a low-carbon economy. The pore-scale distribution, reservoir-scale capacity, containment security H2 CO2 significantly influenced by interfacial properties, including the equilibrium contact angle (θE) solid-liquid solid-gas tensions (γSL γSG). However, due to technical constraints experimentally determining these parameters, they often calculated based on advancing receding values. There is scarcity θE, γSL, γSG data, particularly related structural sealing potential caprock, which unavailable in literature. Young's equation Neumann's state were combined this study theoretically compute three parameters (θE, γSG) at reservoir conditions for potential. Pure mica, organic-aged alumina nano-aged mica substrates investigated explore rock wetting phenomena caprock. results reveal that θE increases while decreases with increasing pressure, organic acid concentration, alkyl chain length. temperatures gas, vice versa CO2. In addition, γSL decrease, whereas nanofluid concentration from 0.05 0.25 wt%. Conversely, increase, 0.75 wettability (a proxy caprock) was generally less than similar physio-thermal conditions. data reported crucial predicting caprock alterations resulting capacity UHS CGS.

Language: Английский

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A review of the supercritical CO2 fluid applications for improved oil and gas production and associated carbon storage

Journal of CO2 Utilization, Journal Year: 2023, Volume and Issue: 72, P. 102479 - 102479

Published: April 22, 2023

Supercritical fluids find use in various areas oil and gas production operations due to their unique properties. CO2 (sc-CO2) with its reduced viscosity, increased diffusivity, liquid like density, is attractive for enhanced hydrocarbon recovery, shale fracturing drilling (especially underbalanced condition). Apart from recovery injection also desirable associated storage through trapping mechanisms. CO2-EOR/EGR processes are affected by coupled geochemical, petrophysical geomechanical alterations interaction of sc-CO2 reservoir rock/fluids Along diffusion/dispersion the fluid filled pore spaces. CO2-monitoring combined lifecycle analysis can help ensure safety optimize CO2-EOR/storage project, considering environment. However, many technical, financial policy challenges need be overcome realize success project achieve carbon neutrality. This review paper discusses such challenges, current mitigation practice, gaps future direction research. holistic would gain insights into sc-CO2-EOR/storage mechanisms, selection criteria, limitations, optimizations while applying method unconventional reservoirs heterogeneity varying

Language: Английский

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Carbon capture and sequestration technology for environmental remediation: A CO2 utilization approach through EOR

Geoenergy Science and Engineering, Journal Year: 2023, Volume and Issue: 234, P. 212619 - 212619

Published: Dec. 28, 2023

Language: Английский

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Adsorption behavior and mechanism analysis of siloxane thickener for CO2 fracturing fluid on shallow shale soil

Journal of Molecular Liquids, Journal Year: 2023, Volume and Issue: 376, P. 121394 - 121394

Published: Feb. 6, 2023

Language: Английский

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Effects of Various Solvents on Adsorption of Organics for Porous and Nonporous Quartz/CO₂/Brine Systems: Implications for CO₂ Geo-Storage

Energy & Fuels, Journal Year: 2022, Volume and Issue: 36(18), P. 11089 - 11099

Published: Aug. 26, 2022

The underground geo-storage of carbon dioxide (CO2) is an essential component the capture and sequestration value chain. success CO2 containment depends on wetting state rock, which controls mechanism fluid flow distribution. presence organic acids in storage formation introduces a considerable effect wettability rock/CO2/brine system under various temperature pressure conditions. Despite previous studies this topic, impact substrate pores, rock surface roughness, solvents used to prepare acid solution temperatures pressures has not yet been elucidated. In present study, contact angles non-porous quartz porous Fontainebleau are measured CO2/brine systems at 0.1–20 MPa 298 323 K. addition, stearic order assess their influence adsorption organics for quartz/CO2/brine systems. results clearly indicate that n-decane most effective solvent solubilizing attain full by due its polar compatibility with acid. Generally, aged exhibits higher than pressures, unaged surfaces demonstrate water wettability, wide range advancing receding less 90°. However, when increased 15 20 system, those pure quartz. These suggest roughness merely amplifies inherent chemistry original if conditions hydrophobic.

Language: Английский

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Mechanical strength and porosity changes of bituminous coal induced by supercritical CO2 interactions: Influence of saturation pressure

Geoenergy Science and Engineering, Journal Year: 2023, Volume and Issue: 225, P. 211691 - 211691

Published: March 16, 2023

Language: Английский

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A comprehensive review on CO2 thickeners for CO2 mobility control in enhanced oil recovery: Recent advances and future outlook

Journal of Industrial and Engineering Chemistry, Journal Year: 2023, Volume and Issue: 126, P. 69 - 91

Published: June 16, 2023

Language: Английский

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Gas channeling control with an in-situ smart surfactant gel during water-alternating-CO2 enhanced oil recovery

Petroleum Science, Journal Year: 2023, Volume and Issue: 20(5), P. 2835 - 2851

Published: March 7, 2023

Undesirable gas channeling always occurs along the high-permeability layers in heterogeneous oil reservoirs during water-alternating-CO2 (WAG) flooding, and conventional polymer gels used for blocking "channeling" paths usually suffer from either low injectivity or poor gelation control. Herein, we first time developed an in-situ high-pressure CO2-triggered gel system based on a smart surfactant, N-erucamidopropyl-N,N-dimethylamine (UC22AMPM), which was introduced into aqueous slugs to control WAG processes. The water-like, low-viscosity UC22AMPM brine solution can be thickened by CO2 owing formation of wormlike micelles (WLMs), as well their growth shear-induced structure buildup under shear flow. thickening power further potentiated generation denser WLMs resulting surfactant concentration augmentation certain range heating, impaired via pressurization above critical pressure because its soaring solvent power. Core flooding tests using cores demonstrated that alleviated plugging high-capacity channels due upon reaction with pre- post-injected flow, thereupon driving chase fluids unrecovered low-permeability areas producing 8.0% higher recovery factor than mode. This enabled high satisfactory control, attributable initial viscosity combined properties one component gelation, respectively. work could provide guide towards designing reducing spillover reinforcing sequestration effect enhanced

Language: Английский

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A comprehensive review direct methods to overcome the limitations of gas injection during the EOR process

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

Published: March 29, 2024

Abstract Among the Enhanced Oil Recovery (EOR) methods, gas-based EOR methods are very popular all over world. The gas injection has a high ability to increase microscopic sweep efficiency and can production well. However, it should be noted that in addition advantages of these they have disadvantages such as damage due asphaltene deposition, unfavorable mobility ratio, reduced macroscopic displacement. In this paper, process its challenges were investigated. Then overcoming To inhibit deposition during injection, use nanoparticles was proposed, which examined two categories: liquid-soluble gas-soluble, limitations each examined. Various used overcome problem ratio their discussed. Gas-phase modification potential reduce direct significantly recovery efficiency. first part, introduction enhanced oil mechanisms mentioned. next included third step, gas-phase control investigate, emphasizing thickeners, thickening mechanisms, field applications methods. last investigate effect on reducing minimum miscible pressure main subsets: 1- indirectly prevent surface tension 2- inhibitor Reduce MMP phase crude

Language: Английский

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