Laboratory Determination of Relative Permeability

Richardson, J.G.; Kerver, J.K.; Hafford, J.A.; Osoba, J.S.

doi:10.2118/952187-g

Cited by 115 publications

(94 citation statements)

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“…This behavior of gas relative permeability is in good agreement with experimental observations of two-phase [8,21,53,57,60,74] and threephase flow [46, 54-56, 62, 64], both in drainage and imbibition. We demonstrate this agreement in Section 4.…”

Section: Analysis Along the Ow Edgesupporting

confidence: 90%

Relative Permeabilities for Strictly Hyperbolic Models of Three-Phase Flow in Porous Media

Juanes¹,

Patzek²

2004

Transport in Porous Media

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Traditional mathematical models of multiphase flow in porous media use a straightforward extension of Darcy's equation, and the key element of these models is the appropriate formulation of the relative permeability functions. It is well known that for one-dimensional flow of three immiscible incompressible fluids, when capillarity is neglected, most relative permeability models used today give rise to regions in the saturation space with elliptic behavior (the so-called elliptic regions). We believe that this behavior is not physical, but rather the result of an incorrect (or incomplete) mathematical model. In this paper we identify necessary conditions that must be satisfied by the relative permeability functions, so that the system of equations 1 R. Juanes and T. W. Patzek: Strictly hyperbolic models of three-phase flow 2 describing three-phase flow is strictly hyperbolic everywhere in the saturation triangle. These conditions seem to be in good agreement with pore-scale physics and experimental data.

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Section: Analysis Along the Ow Edgesupporting

confidence: 90%

Relative Permeabilities for Strictly Hyperbolic Models of Three-Phase Flow in Porous Media

Juanes¹,

Patzek²

2004

Transport in Porous Media

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“…Effect capillary pressure is a result of the specimen pores retained the saturated water until the injected CO 2 pressure exceeded the pore-water holding pressure. This phenomenon is what Richardson et al [15] and Dana and Skoczylas [4] suggested as capillary end effect or capillary pressure effect, which occur on two-phase displacement flow in sandstone. In the third stage, the differential pressure slowly decreased since the injected CO 2 was able to penetrate the bottom of the rock specimen.…”

Section: Constant Flow Pump Permeability Techniquementioning

confidence: 60%

Measurement of specific storage of rock for supercritical carbon dioxide using constant flow pump and constant head permeability techniques

Arsyad

Mitani

Ikemi

2016

Innov. Infrastruct. Solut.

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Advanced laboratory system of rock permeability test associated with constant flow pump, and constant head permeability techniques were developed to measure permeability and specific storage of rock for supercritical CO 2 . The laboratory system was designed to be capable in reproducing similar physical condition of deep aquifer within high pressure and high temperature where CO 2 tends to be in supercritical state. To analyze the result of permeability tests, mathematical models of constant flow pump and constant head permeability techniques were modified to deal with two-phase flow drainage displacement of CO 2 -water in rock. For the examination of its applicability, experimental tests and numerical analysis were undertaken. The accuracy of the obtained specific storage was validated by employing a ratio of the specific storage of the rock specimen to the storage capacity of the pump used in the permeability test. It was found that the specific storage of low permeability sandstone for storing supercritical CO 2 is 1.63 9 10 -4 1/Pa, while large permeability sandstone has the specific storage for supercritical CO 2 at 1.12 9 10 -7 1/Pa. This finding suggested that advanced experimental system of constant flow pump and constant head permeability technique can be used as repeatable, accurate and standardized laboratory test in measuring specific storage of sedimentary rock for CO 2 in supercritical state.

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“…There are many experimental procedures used routinely in the industry to measure multiphase flow functions (Braun and Blackwell 1981;Johnson et al 1959;Richardson et al 1952;Osoba et al 1951;Jones and Roszelle 1978); however, rock samples used are typically a few cm across, while the flow functions need to be input into reservoir simulation models with grid-block sizes of 10-100s m to predict flow at the km scale. In such cases, implementing an upscaling approach is required to capture the effects of sub-scale heterogeneities and the right balance of fluid forces into Darcy-scale simulations.…”

Section: Importance Of Upscalingmentioning

confidence: 99%

Large-scale Invasion Percolation with Trapping for Upscaling Capillary-Controlled Darcy-scale Flow

Nooruddin

Blunt

2017

Transp Porous Med

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We apply steady-state capillary-controlled upscaling in heterogeneous environments. A phase may fail to form a connected path across a given domain at capillary equilibrium. Moreover, even if a continuous saturation path exists, some regions of the domain may produce disconnected clusters that do not contribute to the overall connectivity of the system. In such cases, conventional upscaling processes might not be accurate since identification and removal of these isolated clusters are extremely important to the global connectivity of the system and the stability of the numerical solvers. In this study, we address the impact of percolation during capillary-controlled displacements in heterogeneous porous media and present a comprehensive investigation using random absolute permeability fields, for water-wet, oil-wet and mixed-wet systems, where J-function scaling is used to relate capillary pressure, porosity and absolute permeabilities in each grid cell. Important information is revealed about the average connectivity of the phases and trapping at the Darcy scale due to capillary forces. We show that in oil-wet and mixed-wet media, large-scale trapping of oil controlled by variations in local capillary pressure may be more significant than the local trapping, controlled by pore-scale displacement.

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Laboratory Determination of Relative Permeability

Cited by 115 publications

References 0 publications

Relative Permeabilities for Strictly Hyperbolic Models of Three-Phase Flow in Porous Media

Relative Permeabilities for Strictly Hyperbolic Models of Three-Phase Flow in Porous Media

Measurement of specific storage of rock for supercritical carbon dioxide using constant flow pump and constant head permeability techniques

Large-scale Invasion Percolation with Trapping for Upscaling Capillary-Controlled Darcy-scale Flow

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