eprintid: 13901
rev_number: 2
eprint_status: archive
userid: 1
dir: disk0/00/01/39/01
datestamp: 2023-11-10 03:28:28
lastmod: 2023-11-10 03:28:28
status_changed: 2023-11-10 01:52:16
type: article
metadata_visibility: show
creators_name: Soleimani, H.
creators_name: Ali, H.
creators_name: Yahya, N.
creators_name: Guan, B.H.
creators_name: Sabet, M.
creators_name: Lee, K.C.
creators_name: Dehzangi, A.
creators_name: Kakooei, S.
title: Transport modelling of multi-phase fluid flow in porous media for enhanced oil recovery
ispublished: pub
keywords: Capillarity; Capillary tubes; Computational fluid dynamics; Enhanced recovery; Mass transfer; Nanoparticles; Petroleum transportation; Porous materials; Two phase flow; Wetting, Capillary pressure curves; Constitutive relations; Enhanced oil recovery; Fluid flow in porous media; Inter-phase mass transfer; Multi-phase fluid flow; Spatial heterogeneity; Wettability alteration, Transport properties
note: cited By 3
abstract: This article studies the combined effect of spatial heterogeneity and capillary pressure on the saturation of two fluids during the injection of immiscible nanoparticles. Various literature review exhibited that the nanoparticles are helpful in enhancing the oil recovery by varying several mechanisms, like wettability alteration, interfacial tension, disjoining pressure and mobility control. Multiphase modelling of fluids in porous media comprise balance equation formulation, and constitutive relations for both interphase mass transfer and pressure saturation curves. A classical equation of advection-dispersion is normally used to simulate the fluid flow in porous media, but this equation is unable to simulate nanoparticles flow due to the adsorption effect which happens. Several modifications on computational fluid dynamics (CFD) have been made to increase the number of unknown variables. The simulation results indicated the successful transportation of nanoparticles in two phase fluid flow in porous medium which helps in decreasing the wettability of rocks and hence increasing the oil recovery. The saturation, permeability and capillary pressure curves show that the wettability of the rocks increases with the increasing saturation of wetting phase (brine). © 2020 Trans Tech Publications Ltd, Switzerland.
date: 2020
publisher: Trans Tech Publications Ltd
official_url: https://www.scopus.com/inward/record.uri?eid=2-s2.0-85083992779&doi=10.4028%2fwww.scientific.net%2fDDF.400.38&partnerID=40&md5=aafc681d27f7a6bb3df10b20936e17f2
id_number: 10.4028/www.scientific.net/DDF.400.38
full_text_status: none
publication: Defect and Diffusion Forum
volume: 400
pagerange: 38-44
refereed: TRUE
issn: 10120386
citation:   Soleimani, H. and Ali, H. and Yahya, N. and Guan, B.H. and Sabet, M. and Lee, K.C. and Dehzangi, A. and Kakooei, S.  (2020) Transport modelling of multi-phase fluid flow in porous media for enhanced oil recovery.  Defect and Diffusion Forum, 400.  pp. 38-44.  ISSN 10120386