Apparent permeability of gas shales – Superposition of fluid-dynamic and poro-elastic effects. (1st July 2017)

• Record Type: Journal Article
• Authors: Fink, Reinhard; Krooss, Bernhard M.; Gensterblum, Yves; Amann-Hildenbrand, Alexandra
• Is Part Of: Fuel. Volume 199(2017)
• Page Start: 532
• Page End: 550
• Publication Date: 2017-07-01
• Subjects: Apparent permeability -- Gas transport -- Klinkenberg effect -- Stress -- Unconventional reservoir -- Shale gas; Fuel -- Periodicals; Coal -- Periodicals; Coal; Fuel; Periodicals; 662.6
• DOI: 10.1016/j.fuel.2017.02.086
• Languages: English
• ISSNs: 0016-2361

Abstract

Highlights: Experimental measurements of apparent gas permeability on gas shales. Pitfalls in the evaluation of high pressure apparent gas permeability data. Terzaghi's principle is not valid for permeability of gas shales. A permeability minimum occurs in the Pp range from 2 to 10 MPa. Poro-elastic and fluid-dynamic effects are superposed (0 to >20 MPa Pp ). Abstract: The permeability of low-permeable gas shales is affected by both, fluid-dynamic (slip flow) and poro-elastic effects over a large pore pressure range. To analyse and separate the influence of these superposed effects, an apparent permeability model has been set up. The model's poro-elastic and fluid-dynamic parameters were adjusted simultaneously to match own experimental data for an intact Bossier Shale ("matrix") sample, a fractured Haynesville Shale sample and previously published literature data. The effective stress-permeability relationship can only be described by a modified effective stress law: σ ′ = P c - χ P p Here the fitted permeability effective stress coefficients χ, were consistently ≤1, indicating that pore pressure has a lesser influence on effective stress than confining pressure. Fluid-dynamic gas slippage effects were found to be significant up to pore pressures of 20 MPa in low permeable (<10 μD) matrix samples. Pitfalls in the separation of fluid-dynamic and poro-elastic effects are wrong a priori assumptions. These are neglecting gas slippage above a certain pore pressure and assuming effective stress conditions to be constant in the Klinkenberg evaluation. Ignoring gas slippage in the evaluation of stress effects results in underestimation of χ values whereas undetected stress effects (by wrong a priori χ values) lead to incorrect predictions of the fluid-dynamic effects with increasing pore pressures. The predictions of the apparent permeability model were validated and checked for consistency and plausibility by (1) visualization in a k(Pp, Pc ) diagram, (2) preparation of Klinkenberg plots over large pore pressure ranges (>10 MPa) and (3) analysis of the different slippage behaviour of He and Ar. The apparent permeability model predicts that during depletion of a shale gas reservoir apparent permeability passes through a minimum in the pressure range from 2 to 10 MPa due to the transition from a poro-elastic to a fluid-dynamic dominated realm.