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Permeability-porosity transforms from small sandstone fragments

多孔性 磁导率 钻屑 地质学 演习 矿物学 样品(材料) 多孔介质 土壤孔隙空间特征 流体力学 岩土工程 材料科学 机械 钻探 物理 化学 钻井液 生物化学 冶金 热力学
作者
Ayako Kameda,Jack Dvorkin,Youngseuk Keehm,Amos Nur,William J. Bosl
出处
期刊:Geophysics [Society of Exploration Geophysicists]
卷期号:71 (1): N11-N19 被引量:48
标识
DOI:10.1190/1.2159054
摘要

Numerical simulation of laboratory experiments on rocks, or digital rock physics, is an emerging field that may eventually benefit the petroleum industry. For numerical experimentation to find its way into the mainstream, it must be practical and easily repeatable — i.e., implemented on standard hardware and in real time. This condition reduces the size of a digital sample to just a few grains across. Also, small physical fragments of rock, such as cuttings, may be the only material available to produce digital images. Will the results be meaningful for a larger rock volume? To address this question, we use a number of natural and artificial medium- to high-porosity, well-sorted sandstones. The 3D microtomography volumes are obtained from each physical sample. Then, analogous to making thin sections of drill cuttings, we select a large number of small 2D slices from a 3D scan. As a result, a single physical sample produces hundreds of 2D virtual-drill-cuttings images. Corresponding 3D pore-space realizations are generated statistically from these 2D images; fluid flow is simulated in three dimensions, and the absolute permeability is computed. The results show that small fragments of medium– to high-porosity sandstones that are statistically subrepresentative of a larger sample will not yield the exact porosity and permeability of the sample. However, a significant number of small fragments will yield a site-specific permeability-porosity trend that can then be used to estimate the absolute permeability from independent porosity data obtained in the well or inferred from seismic techniques.
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