Pore-Scale Simulations of Simultaneous Steady-State Two-Phase Flow Dynamics Using a Lattice Boltzmann Model: Interfacial Area, Capillary Pressure and Relative Permeability

A two-dimensional lattice-Boltzmann model with a hexagonal lattice is developed to simulate a boiling two-phase flow microscopically. Liquid-gas phase transition and bubble dynamics, including bubble formation, growth and deformation, are modeled by using an interparticle potential based on the van der Waals equation of state. Thermohydrodynamics is incorporated into the model by adding extra velocities to define temperature. The lattice-Boltzmann model is solved by a finite difference scheme so that numerical stability can be ensured at large discontinuity across the liquid-gas phase boundary and the narrow phase interface thickness can be attained. It is shown from numerical simulations that the model has the ability to reproduce phase transition, bubble dynamics and thermohydrodynamics while assuring numerical instability and narrow phase interface.

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Improved well-balanced free-energy lattice Boltzmann model for two-phase flow with high Reynolds number and large viscosity ratio

Physics of Fluids ◽

10.1063/5.0072221 ◽

2022 ◽

Vol 34 (1) ◽

pp. 012110

Author(s):

Chunhua Zhang ◽

Zhaoli Guo ◽

Lian-Ping Wang

Keyword(s):

Reynolds Number ◽

Free Energy ◽

Lattice Boltzmann ◽

High Reynolds Number ◽

Viscosity Ratio ◽

Lattice Boltzmann Model ◽

Phase Flow ◽

Two Phase ◽

High Reynolds ◽

Boltzmann Model

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Development of a numerical workflow based on μ-CT-imaging for the determination of capillary pressure-saturation-specific interfacial area relationship in two-phase flow pore-scale porous media systems: A case study on Heletz sandstone

10.5194/se-2016-39 ◽

2016 ◽

Author(s):

Aaron Peche ◽

Matthias Halisch ◽

Alexandru Bogdan Tatomir

Keyword(s):

High Resolution ◽

Pore Size ◽

Capillary Pressure ◽

Two Phase Flow ◽

Interfacial Area ◽

Scale Model ◽

Phase Flow ◽

Pore Scale ◽

Two Phase

Abstract. In this case study, we present the implementation of a FEM-based numerical pore-scale model that enables to track and quantify the propagating fluid-fluid interfacial area on highly complex μ-CT obtained geometries. Special focus is drawn to the reservoir specific capillary pressure (pc)- wetting phase saturation (Sw)- interfacial area (awn)- relationship. The basis of this approach are high resolution μ-CT images representing the geometrical characteristics of a georeservoir sample. The successfully validated two-phase flow model is based on the Navier-Stokes equations, including the surface tension force in order to consider capillary effects for the computation of flow and the phase field method for the emulation of a sharp fluid-fluid interface. In combination with specialized software packages, a complex high resolution modeling domain could be obtained. A numerical workflow based on REV-scale pore size distributions is introduced. This workflow aims at the successive modification of model and model setup for simulating such a type of two-phase problem on asymmetric μ-CT-based model domains. The geometrical complexity is gradually increased starting from idealized pore geometries until complex μ-CT-based pore network domains, whereas all domains represent geostatistics of the REV-scale core sample pore size distribution. Finally, the model could be applied on a complex μ-CT-based model domain and the pc-Sw-awn relationship could be computed.

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