dc.identifier.uri |
http://dx.doi.org/10.15488/775 |
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dc.identifier.uri |
http://www.repo.uni-hannover.de/handle/123456789/799 |
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dc.contributor.author |
Peche, Aaron
|
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dc.contributor.author |
Halisch, Matthias
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|
dc.contributor.author |
Bogdan Tatomir, Alexandru
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dc.contributor.author |
Sauter, Martin
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dc.date.accessioned |
2016-11-30T08:54:06Z |
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dc.date.available |
2016-11-30T08:54:06Z |
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dc.date.issued |
2016 |
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dc.identifier.citation |
Peche, Aaron; Halisch, M.; Bogdan Tatomir, A.; Sauter, M.: Development of a numerical workflow based on μ-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. In: Solid Earth 7 (2016), Nr. 3, S. 727-739. DOI: http://dx.doi.org/10.5194/se-7-727-2016 |
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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.language.iso |
eng |
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dc.publisher |
Göttingen : Copernicus GmbH |
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dc.relation.ispartofseries |
Solid Earth 7 (2016), Nr. 3 |
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dc.rights |
CC BY 3.0 Unported |
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dc.rights.uri |
http://creativecommons.org/licenses/by/3.0/ |
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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.ddc |
550 | Geowissenschaften
|
ger |
dc.title |
Development of a numerical workflow based on μ-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 |
|
dc.type |
Text |
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dc.relation.issn |
1869-9510 |
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dc.relation.doi |
http://dx.doi.org/10.5194/se-7-727-2016 |
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dc.bibliographicCitation.issue |
3 |
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dc.bibliographicCitation.volume |
7 |
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dc.bibliographicCitation.firstPage |
727 |
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dc.bibliographicCitation.lastPage |
739 |
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dc.description.version |
publishedVersion |
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tib.accessRights |
frei zug�nglich |
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