dc.contributor.advisor | Torsæter, Ole | |
dc.contributor.advisor | Khanamiri, Hamid Hosseinzade | |
dc.contributor.author | Nyland, Mads Skau | |
dc.date.accessioned | 2019-09-11T09:01:54Z | |
dc.date.created | 2018-06-08 | |
dc.date.issued | 2018 | |
dc.identifier | ntnudaim:19004 | |
dc.identifier.uri | http://hdl.handle.net/11250/2615134 | |
dc.description.abstract | Accurate estimation of physical rock properties is a crucial step in the process of designing
a reservoir model for development reasons and to optimize hydrocarbon production.
Absolute permeability is one of those properties. Digital rock physics have evolved
as a promising new technology to complement traditional laboratory experiments on
core plugs. Background and theory on digital rock physics regarding numerical predictions
of absolute permeability through single-phase incompressible fluid flow are
presented.
In this thesis, two-dimensional pore structure images of different geometries are
created with the programming language Python to study fluid flow behavior in different
pore structure geometries. The material simulator GeoDict is used to simulate single-phase
incompressible fluid flow in the different pore geometry images. The work in
this thesis a theoretical approach and the motivation is to look at absolute permeability
behavior as the pore throat radius is decreased relative to the pore radius. The ratio of
pore radius to pore throat radius is defined as the F ratio. Among the pore geometries
studied in this thesis, are: circular, triangular, diamond and ellipsoidal pores.
It is observed that the numerically predicted absolute permeability versus increasing
F ratio for all pore structure geometries follows a power function trendline. In addition,
it is found that triangular pores show the largest variations in predicted permeability
as the F ratio varies. On the other hand, the highest permeability with least variation
is observed for ellipsoidal pores when fluid flows in the direction of the largest ellipsoidal
radius. Interpretation of numerically predicted permeability results are based on
the theoretical approach of this study. For future studies, investigation of permeability
behavior in geometries that are comparable to real rocks can be studied. Thus, the results
are more applicable to fluid flow problems in realistic porous media. In addition,
it is suggested that permeability behavior of more complex pore geometries should be
studied. | en |
dc.language | eng | |
dc.publisher | NTNU | |
dc.subject | Petroleumsfag, Reservoarteknologi og petrofysikk | en |
dc.title | Effect of Geometry on Pore-Scale Simulation of Single-Phase Fluid Flow | en |
dc.type | Master thesis | en |
dc.source.pagenumber | 113 | |
dc.contributor.department | Norges teknisk-naturvitenskapelige universitet, Fakultet for ingeniørvitenskap,Institutt for geovitenskap og petroleum | nb_NO |
dc.date.embargoenddate | 10000-01-01 | |