Influence of two-phase displacement characteristics on the storage efficiency and security of geological carbon storage

Zhao, Yan; Xi, Ruru; Liu, Yang; Liu, Siyuan; Geng, Zhenkun; Zhang, Qian; Huang, Xinyao; Chen, Xiao

doi:10.1016/j.geoen.2023.211773

Cited by 4 publications

(2 citation statements)

References 64 publications

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“…15,16 In regard to the CO 2 geological sequestration, supercritical carbon dioxide injected to formation brine with viscosity ratio log 10 M between approximately −1.6 and −0.7 causes unstable displacement characterized by fingering flow, which increases the high probability of CO 2 migration and leakage. 17,18 The CO 2 −water flow instability plays an important role in the inefficient storage of CO 2 . 19,20 Therefore, improving the invasion front of the two-phase interface by distinguishing the displacement patterns and influencing factors is crucial.…”

Section: Introductionmentioning

confidence: 99%

“…For an instance of waterflooding, the typical microscopic displacement efficiency is 70% or less, while the oil recovery factor is about 30–40% in conventional oil reservoirs and less than 10% in tight formations . When the water displaces the oil of higher viscosity on the areal formation, the fingering phenomenon associated with the destabilization of the water–oil interface leads to the probability of the premature breakthrough, accompanied by a large amount of crude oil being bypassed and engulfed, which significantly reduce the recovery efficiency. , In regard to the CO 2 geological sequestration, supercritical carbon dioxide injected to formation brine with viscosity ratio log 10 M between approximately −1.6 and −0.7 causes unstable displacement characterized by fingering flow, which increases the high probability of CO 2 migration and leakage. , The CO 2 –water flow instability plays an important role in the inefficient storage of CO 2 . , Therefore, improving the invasion front of the two-phase interface by distinguishing the displacement patterns and influencing factors is crucial …”

Section: Introductionmentioning

confidence: 99%

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Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Chen,

Liu,

Wang

et al. 2023

Energy Fuels

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Immiscible fluid−fluid displacement in porous media is an important phenomenon that impacts the field of underground energy and environmental engineering, such as enhanced oil/gas recovery, geological CO 2 sequestration, and transport and remediation of groundwater pollutants. In enhanced oil recovery, the occurrence of the fingering instability of the two-phase flow interface causes a significant reduction in the oil recovery factor for waterflooding. In geological CO 2 sequestration, the efficiency of CO 2 capillary/residual trapping is limited by the noncompact displacement pattern, presenting only part of brine displaced by scCO 2 . Although extensive studies have investigated viscous and capillary fingering in porous media, how viscous and capillary forces affect the crossover is not well understood. Quantifying and characterizing the transition of immiscible fluid−fluid displacement patterns are therefore important. In this article, comprehensive investigation of capillary number and viscosity ratio effects on displacement patterns and efficiency was established by a series of displacement microfluidic experiments in a homogeneous pore network. Three pairs of nonwetting−wetting immiscible fluids with viscosity ratios M ranging from 1/1000 to 1000 were used to perform the displacement experiments. The drainage experiments of water displacing silicone oil were conducted under five flow rate conditions with capillary number log 10 Ca ranging from −7.19 to −3.45, while the imbibition experiments of silicone oil displacing water displayed at four flow rates with log 10 Ca varying from −7.25 to −2.52. The relationship between displacement efficiency S inv and fractal dimension D f as a function of M and Ca was established to quantitatively determine the transition of displacement patterns (capillary fingering, viscous fingering, stable displacement, and ordered dendritic). The results indicated that D f increased with S inv under unfavorable conditions (M < 1) and decreased as S inv for M > 1, and lower invading fluid saturations were observed in the crossover zone between capillary fingering and viscous fingering for M = 1/20 and 1/200. Based on the pore-scale analysis of pore-filling events and microscopic observation, the theoretical model of the transitions for invasion modes were proposed to determine the critical capillary corresponding to viscosity ratio and contact angle. This study extends the classic log 10 M−log 10 Ca phase diagram and quantifies the dynamic effects of capillary force and viscous force on the immiscible fluid−fluid displacement process.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Chen,

Liu,

Wang

et al. 2023

Energy Fuels

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Core‐flooding experiments of various concentrations of CO₂/N₂ mixture in different rocks: II. Effect of rock properties on residual water

Li,

et al. 2024

Greenhouse Gases

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During CO2 storage in deep saline aquifers, the presence of residual water has an important influence on the storage efficiency and safety. In this study, natural rock cores taken from deep reservoirs in the Ordos Basin and Fukang, Xinjiang are used as research objects. Nine groups of core‐flooding experiments are performed under different CO2/N2 gas mixture ratios to study the influence of rock properties (mineral composition, permeability, porosity and pore structure) on the residual water. Furthermore, the geophysical and chemical properties of rock cores are analyzed by X‐ray diffraction, electron microscopy, field emission scanning electron microscopy and piezoelectric mercury method. The results show that residual water saturation is a quantitative power function of drainage time. The residual water saturation is positively correlated with the total amount of quartz and feldspar and increases with increasing permeability. Moreover, both the average and median pore throat radius show a strong inverse correlation with irreducible residual water saturation; as these radius increase, the residual water saturation decreases. In contrast, the porosity and maximum pore throat radius display a weaker correlation with irreducible residual water saturation. This study is of great value for engineering practices such as the site selection of CO2 storage projects in saline aquifer and improvement of CO2 storage efficiency. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Uncovering the impact of morphology of porous media and capillary number on immiscible oil recovery using computational fluid dynamics

Ghodsi,

Rasaei

2025

Geoenergy Science and Engineering

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Influence of two-phase displacement characteristics on the storage efficiency and security of geological carbon storage

Cited by 4 publications

References 64 publications

Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Core‐flooding experiments of various concentrations of CO₂/N₂ mixture in different rocks: II. Effect of rock properties on residual water

Uncovering the impact of morphology of porous media and capillary number on immiscible oil recovery using computational fluid dynamics

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Influence of two-phase displacement characteristics on the storage efficiency and security of geological carbon storage

Cited by 4 publications

References 64 publications

Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Effects of Capillary and Viscous Forces on Two-Phase Fluid Displacement in the Microfluidic Model

Core‐flooding experiments of various concentrations of CO2/N2 mixture in different rocks: II. Effect of rock properties on residual water

Uncovering the impact of morphology of porous media and capillary number on immiscible oil recovery using computational fluid dynamics

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Core‐flooding experiments of various concentrations of CO₂/N₂ mixture in different rocks: II. Effect of rock properties on residual water