Relative Permeability Measurements: An Inter-Laboratory Comparison

McPhee, Colin; Arthur, K.G.

doi:10.2118/28826-ms

Cited by 26 publications

(13 citation statements)

References 11 publications

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“…In most of the documented cases the endpoint relative permeabilities 1.4 < k r < 2.4 (McPhee 1994;McPhee and Arthur 1994). These cases have in common that the (near) endpoint relative permeabilities k r > 1 in particular, when the non-wetting phase is the majority phase (McPhee 1994;McPhee and Arthur 1994;Karabakal and Bagci 2004) and the wetting phase is present only as thin wetting films covering the rock surface. In oil-wet systems (wetting-index −1) the k r,w (S o,r ) > 1 and in water-wet systems k r,o (S w,c ) > 1.…”

Section: Introductionmentioning

confidence: 99%

“…It is usually assumed that the relative permeabilities 0 ≤ k r ≤ 1. However, there are several reports in the literature that explicitly show endpoint relative permeabilities k r > 1 (Odeh 1959;Dullien 1992;Anderson 1987;McPhee 1994;McPhee and Arthur 1994;Karabakal and Bagci 2004;Honarpour et al 2000;Arps and Roberts 1995;Ehrlich 1993;Mikkelsen and Scheie 1991). The term "endpoint" refers to the relative permeability at the saturation endpoints, S w,c and S o,r .…”

Section: Introductionmentioning

confidence: 99%

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Two-Phase Flow in Porous Media with Slip Boundary Condition

et al. 2008

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Flow in porous media described by Darcy's law extended to two-phase flow using the concept of relative permeabilities k r naturally assumes a maximum value of 0 ≤ k r ≤ 1. Reports in literature and our own experimental data show endpoint relative permeabilities k r > 1. In the porous medium, the flux of the non-wetting phase is in many cases about 2-4 times higher when a small amount of the wetting phase is present. Here, we draw an analogy between k r > 1 and a slip-boundary condition for the pore scale flow. We use a model description assuming flow in capillary tubes with a slip boundary condition. This model predicts that the flux increase due to slip depends on the equivalent capillary radius of the flow channels. Our k r data specifically follows this dependence indicating that slip is a plausible explanation for the observation of k r > 1.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Two-Phase Flow in Porous Media with Slip Boundary Condition

et al. 2008

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“…In 1959, using core plugs from consolidated rock, Odeh (52) observed effective permeabilities to oil at initial water saturation which were up to 2.4 times the permeabilities to brine totally saturating the core plug. More recently, McPhee & Arthur (53) observed a similar phenomenon with core plugs of consolidated Clashach sandstone.…”

Section: Two Phase Flowmentioning

confidence: 67%

“…McPhee & Arthur (53) explored "bump floods" at the end of a relative permeability test, where the flow rate of water through a core plug was increased by a factor of 100 at the end of an oil displacement test. They found that the higher velocity flow of water increased the displacement of oil only slightly, but increased the effective permeability to water by a factor almost of 4.…”

Section: Two Phase Flowmentioning

confidence: 99%

Pre-Darcy Flow: A Missing Piece of the Improved Oil Recovery Puzzle?

Longmuir

2004

SPE/DOE Symposium on Improved Oil Recovery

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractDoes Darcy's Law apply at the very low fluid velocities typical for petroleum reservoirs? There is a body of experimental evidence, primarily from non-petroleum disciplines, demonstrating departures from Darcy's Law at low fluid velocities -Pre-Darcy flow. If Pre-Darcy behavior occurs in oil & gas reservoirs, there could be substantial currently-unrecognized opportunities for increasing the economic recovery of hydrocarbons.

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“…The combination of low aspect ratio and moderate to high contact angles make relative permeabilities for these cores largely insensitive to displacement rate. McPhee and Arthur [30] report a comparative study of four service laboratories using similar methods and cores. The overall trend is for relative permeabilities to increase and residual saturations to decrease with increasing displacement rate.…”

Section: Network Model Predictions For Berea Relative Permeability Datamentioning

confidence: 99%

The Effects of Displacement Rate and Wettability on Imbibition Relative Permeabilities

Nguyen¹,

Sheppard²,

Knackstedt

et al. 2005

SPE Annual Technical Conference and Exhibition

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A new dynamic network model is used to investigate the effects of displacement rate and wettability on imbibition relative permeability. The network geometry and topology is representative of a Berea-type sandstone. In contrast to existing quasi-static network models where snap-off, the major pore-scale trapping mechanism in imbibition, is suppressed by contact angle alone, the dynamic model introduces displacement rate as an additional snap-off inhibiting mechanism. The network model is used to analyse the complex rate dependence of relative permeability and residual saturation displayed by laboratory measured data reported in the literature. TX 75083-3836, U.S.A., fax 01-972-952-9435. SPE 95953

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Relative Permeability Measurements: An Inter-Laboratory Comparison

Cited by 26 publications

References 11 publications

Two-Phase Flow in Porous Media with Slip Boundary Condition

Two-Phase Flow in Porous Media with Slip Boundary Condition

Pre-Darcy Flow: A Missing Piece of the Improved Oil Recovery Puzzle?

The Effects of Displacement Rate and Wettability on Imbibition Relative Permeabilities

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