Effects of grain shape and packing pattern on spontaneous imbibition under different boundary conditions: Pore-scale simulation

Liu, Yang; Chen, Mingjie; Sun, Shuyu; Lei, Zhengdong; Zeng, Jianhui; Cai, Jianchao

doi:10.1016/j.jhydrol.2022.127484

Cited by 19 publications

(10 citation statements)

References 55 publications

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“…Zhao et al 72 introduced the interactions between water and solid wall into the LBM to explore the impacts of pore geometry and wettability on the flow dynamics. Liu et al 73 studied how four boundary conditions affect spontaneous imbibition and concluded that the size of the open face in contact with the water positively correlates with the imbibition rate. Zheng et al 74 developed an improved multicomponent LBM to analyze the imbibition behavior in the complex pore structure of shales with accounting for the mixed wettability.…”

Section: Imbibition Mechanisms In Shale Pore Networkmentioning

confidence: 99%

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

et al. 2023

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The breakthrough of shale oil in North America led to a worldwide energy revolution. Shale reservoirs show multiscale properties and a large proportion of nanopores compared to conventional reservoirs, which makes the imbibition mechanisms of fracturing fluids within shale reservoirs exceptionally complicated. For instance, the fracturing fluid shows a distinct imbibition behavior at different scales. Traditional models face significant challenges in imbibition characterization. Understanding the imbibition mechanisms in shale oil formations from a multiscale perspective can help to make full use of the positive effect and enhance oil recovery. We review imbibition mechanisms in shale reservoirs from the nanoscale to the reservoir scale. The imbibition principles in a single nanopore and the improvement of the traditional characterization models are clarified. Then, at the pore scale, we elaborate on the imbibition laws obtained from the microfluidic chip, pore network model, and direct simulations. We also outline the imbibition dynamics at the core scale, the influences of capillary forces and osmotic pressure, and the variations of the pore structure. Finally, the imbibition behavior at the reservoir scale and field examples considering the imbibition effect are introduced. We analyze the existing problems on each scale and discuss the future trends in this area. This work is expected to help readers systematically understand the mechanisms and behavior of fracturing fluid imbibition in shale oil reservoirs at different scales and accelerate the exploitation of shale resources.

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Section: Imbibition Mechanisms In Shale Pore Networkmentioning

confidence: 99%

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

et al. 2023

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“…LBM has been widespread in the simulations of multiphase flow in the porous medium, chemical reactions, and heat transfer process (Chen et al, 2013(Chen et al, , 2015Golparvar et al, 2018;Zhang et al, 2021;Wei et al, 2022). At present, the commonly utilized multiphase models include the Shan-Chen model, the color gradient model (Diao et al, 2021;Liu et al, 2022a), and the phase field model (Wang et al, 2019). These have been described in detail by Liu et al (2016).…”

Section: Introductionmentioning

confidence: 99%

Pore-scale simulation of gas displacement after water flooding using three-phase lattice Boltzmann method

et al. 2023

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Water flooding is a commonly used technique to improve oil recovery, although the amount of oil left in reservoirs after the procedure is still significant. Gas displacement after water flooding is an effective way to recover residual oil, but the occurrence state and flow principles of multiphase fluid after gas injection are still ambiguous. Therefore, the gas displacement process after water flooding should be studied on the pore scale to provide a basis for formulating a reasonable gas injection program. Most of the current pore-scale studies focus on two-phase flow, while simulations that account for the influence of oilgas miscibility and injected water are seldom reported. In this work, the multi-component multi-phase Shan-Chen lattice Boltzmann model is used to simulate the gas displacement after water flooding in a porous medium, and the effects of injected water, viscosity ratio, pore structure, and miscibility are analyzed. It is established that the injected water will cause gas flow path variations and lead to premature gas channeling. Under the impact of capillary pressure, the water retained in the porous medium during the water flooding stage further imbibes into the tiny pores during gas injection and displaces the remaining oil. When miscibility is considered, the oil-gas interface disappears, eliminating the influence of the capillary effect on the fluid flow and enabling the recovery of remaining oil at the corner. This study sheds light on the gas displacement mechanisms after water flooding from the pore-scale perspective and provides a potential avenue for improving oil recovery.

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“…Spontaneous imbibition is a process in which the wetting phase spontaneously sucks into porous media to displace the nonwetting phase driven by capillary force. According to the different flow directions of the wetting phase and nonwetting phase, imbibition is usually divided into cocurrent and countercurrent imbibition. − The study of imbibition theory began in the 20th century. Lucas assumed that the fluid flow conforms to Poiseuille flow; considered the viscous resistance, capillary force, and gravity of the fluid; and obtained the equation of capillary imbibition rising height.…”

Section: Introductionmentioning

confidence: 99%

“…During the soaking process, fracturing fluid is imbibed into the reservoir and displaces the oil therein, thereby enhancing oil recovery. In fractured reservoirs, due to the randomness of the fracture morphology, the contact modes and contact areas between the fracturing fluid and rock are different, thus forming different boundary conditions. ,, Generally, the boundary conditions of cores are divided into all-faces-open (AFO), one-end-closed (OEC), two-ends-closed (TEC), two-ends-open (TEO), and one-end-open (OEO). − ,− Among them, the researches on OEC boundary condition has not received much attention. In addition to boundary conditions, the parameters that affect the imbibition characteristics also include core size, porosity, permeability, fluid surface tension, viscosity, and so on.…”

Section: Introductionmentioning

confidence: 99%

“…In fractured reservoirs, due to the randomness of the fracture morphology, the contact modes and contact areas between the fracturing fluid and rock are different, thus forming different boundary conditions. 11,13,18 Generally, the boundary conditions of cores are divided into all-faces-open (AFO), oneend-closed (OEC), two-ends-closed (TEC), two-ends-open (TEO), and one-end-open (OEO). 11−13,19−24 Among them, the researches on OEC boundary condition has not received much attention.…”

Section: Introductionmentioning

confidence: 99%

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Study on Imbibition Characteristics of Glutenite with Different Boundary Conditions Based on NMR Experiments

et al. 2022

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A glutenite reservoir is an important unconventional oil resource. However, there are few experimental studies on the imbibition of glutenite, and the imbibition laws with different boundary conditions are not clear. In addition, the one-end-closed (OEC) boundary condition has not received much attention. In this paper, an analytical balance and a nuclear magnetic resonance (NMR) analyzer are used as experimental instruments to monitor the spontaneous imbibition process of saturated oil glutenite in deuterium water, and the imbibition characteristics of glutenite with five different boundary conditions are studied. The T 2 spectra show that oil is mainly distributed in micropores and mesopores, and the signal amplitudes in the micropores decrease significantly. The micropores correspond to greater capillary force, and they are the main space for imbibition. The imbibed volume measured by the mass method is basically consistent with the area changes of T 2 spectra, and the imbibition curves conform to the Handy model. The imbibition rates with different boundary conditions are different, but their gap is acceptable. Among them, one-end-open (OEO) and two-ends-open (TEO) boundary conditions are slightly higher. Imbibition recovery is related to the exposed areas of the cores, and all-faces-open (AFO) is the boundary condition most conducive to recovery. The normalized recovery model can better scale the three boundary conditions of AFO, OEC, and two-ends-closed (TEC), but there is a certain error in the scaling of TEO and OEO of core end seepage. This research contributes to understanding the effects of boundary conditions on spontaneous imbibition, which is of significance for analyzing the soak mechanism of glutenite reservoirs.

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Effects of grain shape and packing pattern on spontaneous imbibition under different boundary conditions: Pore-scale simulation

Cited by 19 publications

References 55 publications

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

Pore-scale simulation of gas displacement after water flooding using three-phase lattice Boltzmann method

Study on Imbibition Characteristics of Glutenite with Different Boundary Conditions Based on NMR Experiments

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