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.firstPage727eng
dc.bibliographicCitation.issue3eng
dc.bibliographicCitation.journalTitleSolid earth : SEeng
dc.bibliographicCitation.lastPage739eng
dc.bibliographicCitation.volume7eng
dc.contributor.authorPeche, Aaron
dc.contributor.authorHalisch, Matthias
dc.contributor.authorBogdan Tatomir, Alexandru
dc.contributor.authorSauter, Martin
dc.date.accessioned2022-04-20T08:21:37Z
dc.date.available2022-04-20T08:21:37Z
dc.date.issued2016
dc.description.abstractIn 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.versionpublishedVersioneng
dc.identifier.urihttps://oa.tib.eu/renate/handle/123456789/8741
dc.identifier.urihttps://doi.org/10.34657/7779
dc.language.isoengeng
dc.publisherGöttingen : Copernicus Publ.eng
dc.relation.doihttps://doi.org/10.5194/se-7-727-2016
dc.relation.essn1869-9529
dc.rights.licenseCC BY 3.0 Unportedeng
dc.rights.urihttps://creativecommons.org/licenses/by/3.0/eng
dc.subject.ddc550eng
dc.subject.otherCapillarityeng
dc.subject.otherCapillary floweng
dc.subject.otherCapillary tubeseng
dc.subject.otherComplex networkseng
dc.subject.otherComputerized tomographyeng
dc.subject.otherGeometryeng
dc.subject.otherMechanical permeabilityeng
dc.subject.otherNavier Stokes equationseng
dc.subject.otherNumerical methodseng
dc.subject.otherPhase transitionseng
dc.subject.otherPore sizeeng
dc.subject.otherPorous materialseng
dc.subject.otherSize distributioneng
dc.subject.otherTwo phase floweng
dc.subject.otherFluid fluid interfaceseng
dc.subject.otherFluid interfacial areaeng
dc.subject.otherGeometrical characteristicseng
dc.subject.otherGeometrical complexityeng
dc.subject.otherMicrocomputed tomographyeng
dc.subject.otherRepresentative elementary volumeeng
dc.subject.otherSpecific interfacial areaeng
dc.subject.otherSurface tension forceeng
dc.subject.otherFinite element methodeng
dc.subject.othercapillary pressureeng
dc.subject.othercomputer simulationeng
dc.subject.otherfinite element methodeng
dc.subject.otherNavier-Stokes equationseng
dc.subject.othernumerical modeleng
dc.subject.otherpore spaceeng
dc.subject.otherporous mediumeng
dc.subject.othersandstoneeng
dc.subject.othersaturationeng
dc.subject.othersize distributioneng
dc.subject.othertwo phase floweng
dc.titleDevelopment 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 sandstoneeng
dc.typeArticleeng
dc.typeTexteng
tib.accessRightsopenAccesseng
wgl.contributorLIAGeng
wgl.subjectGeowissenschafteneng
wgl.typeZeitschriftenartikeleng
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