Klinkenberg-Corrected Permeability Measurements in Tight Gas Sands: Steady-State Versus Unsteady-State Techniques

Rushing, Jay Alan; Newsham, Kent; Lasswell, Patrick; Cox, J.C.; Blasingame, Thomas Alwin

doi:10.2118/89867-ms

Cited by 85 publications

(49 citation statements)

References 11 publications

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“…We focus on the determination of the apparent permeability, k, at a given pressure P m , keeping in mind that k l and b could be determined from repeated identical experiments at different values of P m as documented elsewhere. [8][9][10][11] …”

Section: Methodsmentioning

confidence: 99%

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A new quasi-steady method to measure gas permeability of weakly permeable porous media

Jannot

Lasseux

2012

Review of Scientific Instruments

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A new quasi-steady method for the determination of the apparent gas permeability of porous materials is presented in this paper along with the corresponding interpretative physical model derived from the unsteady flow equations. This method is mainly dedicated to the measurement of very low permeability of thin porous media, although thicker but more permeable samples may also be analyzed. The method relies on quasi-steady flow resulting from a (quasi) constant pressure maintained at the inlet face of the sample. Gas flow-rate, as low as 3 × 10(-10) m(3)/s, is determined from the record of pressure increase in a reservoir connected to the outlet face of the sample. An estimate of the characteristic time, t(c), to reach quasi-steady flow after imposing a constant pressure at the inlet is derived. It is validated by direct numerical simulations of the complete unsteady flow, clearly defining the required experimental duration for the method to apply. Experimental results obtained on rather permeable and thick rock samples are reported showing an excellent agreement of the measured permeability with that determined independently on the same sample whereas the experimental value of t(c) is also in very good agreement with the predicted one. The method is further employed on a composite material sheet allowing the identification of an apparent gas permeability of about 10(-23) m(2).

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Section: Methodsmentioning

confidence: 99%

“…The intrinsic permeability k l and Klinkenberg coefficient b may then be determined from several experiments performed under stationary conditions but at different values of P m using the analogue of Eq. (1), [8][9][10][11] namely,…”

Section: Introductionmentioning

confidence: 99%

A new quasi-steady method to measure gas permeability of weakly permeable porous media

Jannot

Lasseux

2012

Review of Scientific Instruments

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“…The laminar character of the gas flow is verified by determining the Reynolds number. About ten permeability measurements at various pore-pressure gradients were conducted for each sample to correct for the Klinkenberg effect using the graphical method described by many authors (Riepe et al, 1983;Rushing et al, 2004;Zinsner and Pellerin, 2007).…”

Section: Absolute Permeability Testing Proceduresmentioning

confidence: 99%

Influence of fault rock foliation on fault zone permeability: The case of deeply buried arkosic sandstones (Grès d'Annot, southeastern France)

Cavailhès¹,

Sizun²,

Labaume³

et al. 2013

Bulletin

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We describe the structure, microstructure, and petrophysical properties of fault rocks from two normal fault zones formed in low-porosity turbiditic arkosic sandstones, in deep diagenesis conditions similar to those of deeply buried reservoirs. These fault rocks are characterized by a foliated fabric and quartz-calcite sealed veins, which formation resulted from the combination of the (1) pressure solution of quartz, (2) intense fracturing sealed by quartz and calcite cements, and (3) neoformation of synkinematic white micas derived from the alteration of feldspars and chlorite. Fluid inclusion microthermometry in quartz and calcite cements demonstrates fault activity at temperatures of 195°C to 268°C. Permeability measurements on plugs oriented parallel with the principal axes of the finite strain ellipsoid show that the Y axis (parallel with the foliation and veins) is the direction of highest permeability in the foliated sandstone (10 -2 md for Y against 10 -3 md for X, Z, and the protolith, measured at a confining pressure of 20 bars). Microstructural observations document the localization of the preferential fluid path between the phyllosilicate particles forming the foliation. Hence, the direction of highest permeability in these fault rocks would be parallel with the fault and subhorizontal, that is, perpendicular to the slickenlines representing the local slip direction on the fault surface. We suggest

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“…Several steady state or non-steady state techniques are being used (cf. Carles et al, 2007;Rushing et al, 2004). Permeability and threshold pressures are determined from the incremental influent/ effluent volumes and/or the pressure decay.…”

Section: Permeability and Threshold Pressure Experimentsmentioning

confidence: 99%

Transport properties of unconventional gas systems

Amann-Hildenbrand

Ghanizadeh

Krooß

2012

Marine and Petroleum Geology

161

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Klinkenberg-Corrected Permeability Measurements in Tight Gas Sands: Steady-State Versus Unsteady-State Techniques

Cited by 85 publications

References 11 publications

A new quasi-steady method to measure gas permeability of weakly permeable porous media

A new quasi-steady method to measure gas permeability of weakly permeable porous media

Influence of fault rock foliation on fault zone permeability: The case of deeply buried arkosic sandstones (Grès d'Annot, southeastern France)

Transport properties of unconventional gas systems

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