Fast simulation of two-phase flow in three-dimensional digital images of heterogeneous porous media using multiresolution curvelet transformation

Aljasmi, Abdullah; Sahimi, Muhammad

doi:10.1016/j.advwatres.2021.103882

Cited by 2 publications

(3 citation statements)

References 52 publications

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“…In conjunction, two-phase flow simulations at the pore scale have also been carried out extensively (Zhao et al 2019) with the aim of reproducing both microscopic and macroscopic observations. These have been performed using various representations of porous structures like pore networks (Gjennestad, Winkler & Hansen 2020;Maalal et al 2021), X-ray or scanning-electron-microscopy-based images (Aljasmi & Sahimi 2021;Shams et al 2021). Computations have been carried out in many different configurations using lattice-Boltzmann (Taghilou & Rahimian 2014;Shi & Tang 2018;Gu, Liu & Wu 2021) and other techniques, either based on two-fluid systems taking explicitly into account the interfaces with a volume of fluid method or continuous two-fluid approaches using level-set (Ambekar, Mondal & Buwa 2021;Jettestuen, Friis & Helland 2021) or Cahn-Hilliard models (Yang & Kim 2021) with improved algorithms making use of machine learning (see, for instance, Silva et al (2021)).…”

Section: Introductionmentioning

confidence: 99%

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A macroscopic model for immiscible two-phase flow in porous media

Lasseux

Valdés‐Parada

2022

J. Fluid Mech.

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This work provides the derivation of a closed macroscopic model for immiscible two-phase, incompressible, Newtonian and isothermal creeping steady flow in a rigid and homogeneous porous medium without considering three-phase contact. The mass and momentum upscaled equations are obtained from the pore-scale Stokes equations, adopting a two-domain approach where the two fluid phases are separated by an interface. The average mass equations result from using the classical volume averaging method. A Green's formula and the adjoint Green's function velocity pair problems are used to obtain the pore-scale velocity solutions that are averaged to obtain the upscaled momentum balance equations. The macroscopic model is based on the assumptions of scale separation and the existence of a periodic representative elementary volume allowing a local description as usually postulated for upscaling. The macroscopic momentum equation in each phase includes the generalized Darcy-like dominant and viscous coupling terms and, importantly, an additional compensation term that accounts for surface tension effects to momentum transfer that is, otherwise, incompletely captured by the Darcy terms. This interfacial term, as well as the dominant and viscous coupling permeability tensors, can be predicted from the solutions of two associated closure problems that coincide with those reported in the literature. The relevance of the compensation term and the upscaled model validity are assessed by comparisons with direct numerical simulations in a model two-dimensional periodic structure. Upscaled model predictions are found to be in excellent agreement with direct numerical simulations.

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Section: Introductionmentioning

confidence: 99%

“…These have been performed using various representations of porous structures like pore networks (Gjennestad, Winkler & Hansen 2020; Maalal et al. 2021), X-ray or scanning-electron-microscopy-based images (Aljasmi & Sahimi 2021; Shams et al. 2021).…”

Section: Introductionmentioning

confidence: 99%

A macroscopic model for immiscible two-phase flow in porous media

Lasseux

Valdés‐Parada

2022

J. Fluid Mech.

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“…Pore network modeling (PNM) is a micro, multiphase flow -method based on physical reality [21]. In the field of hydrocarbon resources development, various forms of pore network models have been widely used in the simulation and prediction of single or multiphase flow parameters in porous rock media, such as capillary force [22], relative permeability [23], residual oil saturation [24], reservoir recovery [25], etc. PNM is also a simulation tool based on the actual physical existence of multiphase flow in porous media [26].…”

Section: Introductionmentioning

confidence: 99%

Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

et al. 2021

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Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens.

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Fast simulation of two-phase flow in three-dimensional digital images of heterogeneous porous media using multiresolution curvelet transformation

Cited by 2 publications

References 52 publications

A macroscopic model for immiscible two-phase flow in porous media

A macroscopic model for immiscible two-phase flow in porous media

Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

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