Publication:
Synchrotron-based pore-network modeling of two-phase flow in Nubian Sandstone and implications for capillary trapping of carbon dioxide

cris.virtual.department#PLACEHOLDER_PARENT_METADATA_VALUE#
cris.virtual.departmentHydromechanik
cris.virtual.department#PLACEHOLDER_PARENT_METADATA_VALUE#
cris.virtual.department#PLACEHOLDER_PARENT_METADATA_VALUE#
cris.virtual.departmentbrowseHydromechanik
cris.virtual.departmentbrowseHydromechanik
cris.virtual.departmentbrowseHydromechanik
cris.virtualsource.department#PLACEHOLDER_PARENT_METADATA_VALUE#
cris.virtualsource.department#PLACEHOLDER_PARENT_METADATA_VALUE#
cris.virtualsource.department5eebaccd-371f-40cd-8f12-101831ee8137
cris.virtualsource.department#PLACEHOLDER_PARENT_METADATA_VALUE#
dc.contributor.authorHefny, Mahmoud
dc.contributor.authorQin, Chao Zhong
dc.contributor.authorSaar, Martin O.
dc.contributor.authorEbigbo, Anozie
dc.date.issued2020-12-01
dc.description.abstractDepleted oil fields in the Gulf of Suez (Egypt) can serve as geothermal reservoirs for power generation using a CO₂-Plume Geothermal (CPG) system, while geologically sequestering CO₂. This entails the injection of a substantial amount of CO₂ into the highly permeable brine-saturated Nubian Sandstone. Numerical models of two-phase flow processes are indispensable for predicting the CO₂-plume migration at a representative geological scale. Such models require reliable constitutive relationships, including relative permeability and capillary pressure curves. In this study, quasi-static pore-network modelling has been used to simulate the equilibrium positions of fluid–fluid interfaces, and thus determine the capillary pressure and relative permeability curves. Three-dimensional images with a voxel size of 0.65 μm3 of a Nubian Sandstone rock sample have been obtained using Synchrotron Radiation X-ray Tomographic Microscopy. From the images, topological properties of pores/throats were constructed. Using a pore-network model, we performed a sequential primary drainage, main imbibition cycle of quasi-static invasion in order to quantify (1) the CO₂ and brine relative permeability curves, (2) the effect of initial wetting-phase saturation (i.e. the saturation at the point of reversal from drainage to imbibition) on the residual-trapping potential, and (3) study the relative permeability-saturation hysteresis. The results improve our understanding of the potential magnitude of capillary trapping in Nubian Sandstone, essential for future field-scale simulations.
dc.description.versionNA
dc.identifier.arxivarXiv:2004.06792
dc.identifier.doi10.1016/j.ijggc.2020.103164
dc.identifier.issn1750-5836
dc.identifier.scopus2-s2.0-85092443322
dc.identifier.urihttps://openhsu.ub.hsu-hh.de/handle/10.24405/14442
dc.language.isoen
dc.relation.journalInternational Journal of Greenhouse Gas Control
dc.relation.orgunitHydromechanik
dc.rights.accessRightsmetadata only access
dc.subjectCarbon capture and storage
dc.subjectCO₂-plume geothermal
dc.subjectNubian Sandstone (Egypt)
dc.subjectPore-network modelling
dc.subjectResidual trapping
dc.subjectPhysics - Geophysics
dc.titleSynchrotron-based pore-network modeling of two-phase flow in Nubian Sandstone and implications for capillary trapping of carbon dioxide
dc.typeResearch article
dspace.entity.typePublication
hsu.peerReviewed
hsu.uniBibliography
oaire.citation.volume30
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