Development of a numerical workflow based on <i>μ</i>-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone
dc.bibliographicCitation.firstPage | 727 | eng |
dc.bibliographicCitation.issue | 3 | eng |
dc.bibliographicCitation.lastPage | 739 | eng |
dc.bibliographicCitation.volume | 7 | eng |
dc.contributor.author | Peche, Aaron | |
dc.contributor.author | Halisch, Matthias | |
dc.contributor.author | Bogdan Tatomir, Alexandru | |
dc.contributor.author | Sauter, Martin | |
dc.date.accessioned | 2022-04-20T08:21:37Z | |
dc.date.available | 2022-04-20T08:21:37Z | |
dc.date.issued | 2016 | |
dc.description.abstract | In this case study, we present the implementation of a finite element method (FEM)-based numerical pore-scale model that is able to track and quantify the propagating fluid–fluid interfacial area on highly complex micro-computed tomography (μ-CT)-obtained geometries. Special focus is drawn to the relationship between reservoir-specific capillary pressure (pc), wetting phase saturation (Sw) and interfacial area (awn). The basis of this approach is high-resolution μ-CT images representing the geometrical characteristics of a georeservoir sample. The successfully validated 2-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 modelling domain can be obtained. A numerical workflow based on representative elementary volume (REV)-scale pore-size distributions is introduced. This workflow aims at the successive modification of model and model set-up for simulating, such as a type of 2-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 can be applied to a complex μ-CT-based model domain and the pc–Sw–awn relationship can be computed. | eng |
dc.description.version | publishedVersion | eng |
dc.identifier.uri | https://oa.tib.eu/renate/handle/123456789/8741 | |
dc.identifier.uri | https://doi.org/10.34657/7779 | |
dc.language.iso | eng | eng |
dc.publisher | Göttingen : Copernicus Publ. | eng |
dc.relation.doi | https://doi.org/10.5194/se-7-727-2016 | |
dc.relation.essn | 1869-9529 | |
dc.relation.ispartofseries | Solid earth : SE 7 (2016), Nr. 3 | eng |
dc.rights.license | CC BY 3.0 Unported | eng |
dc.rights.uri | https://creativecommons.org/licenses/by/3.0/ | eng |
dc.subject | Capillarity | eng |
dc.subject | Capillary flow | eng |
dc.subject | Capillary tubes | eng |
dc.subject | Complex networks | eng |
dc.subject | Computerized tomography | eng |
dc.subject | Geometry | eng |
dc.subject | Mechanical permeability | eng |
dc.subject | Navier Stokes equations | eng |
dc.subject | Numerical methods | eng |
dc.subject | Phase transitions | eng |
dc.subject | Pore size | eng |
dc.subject | Porous materials | eng |
dc.subject | Size distribution | eng |
dc.subject | Two phase flow | eng |
dc.subject | Fluid fluid interfaces | eng |
dc.subject | Fluid interfacial area | eng |
dc.subject | Geometrical characteristics | eng |
dc.subject | Geometrical complexity | eng |
dc.subject | Microcomputed tomography | eng |
dc.subject | Representative elementary volume | eng |
dc.subject | Specific interfacial area | eng |
dc.subject | Surface tension force | eng |
dc.subject | Finite element method | eng |
dc.subject | capillary pressure | eng |
dc.subject | computer simulation | eng |
dc.subject | finite element method | eng |
dc.subject | Navier-Stokes equations | eng |
dc.subject | numerical model | eng |
dc.subject | pore space | eng |
dc.subject | porous medium | eng |
dc.subject | sandstone | eng |
dc.subject | saturation | eng |
dc.subject | size distribution | eng |
dc.subject | two phase flow | eng |
dc.subject.ddc | 550 | eng |
dc.title | Development of a numerical workflow based on <i>μ</i>-CT imaging for the determination of capillary pressure–saturation-specific interfacial area relationship in 2-phase flow pore-scale porous-media systems: a case study on Heletz sandstone | eng |
dc.type | article | eng |
dc.type | Text | eng |
dcterms.bibliographicCitation.journalTitle | Solid earth : SE | eng |
tib.accessRights | openAccess | eng |
wgl.contributor | LIAG | eng |
wgl.subject | Geowissenschaften | eng |
wgl.type | Zeitschriftenartikel | eng |
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