基于页岩储层各向异性的双重介质模型和渗流模拟

刘卫群, 王冬妮, 苏强

doi:10.11764/j.issn.1672-1926.2016.08.1374

天然气地球科学 >

2016 , Vol. 27 >Issue 8: 1374 - 1379

DOI: https://doi.org/10.11764/j.issn.1672-1926.2016.08.1374

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基于页岩储层各向异性的双重介质模型和渗流模拟

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1.中国矿业大学深部岩土力学与地下工程国家重点实验室，江苏徐州 221116；
2.中国矿业大学力学与建筑工程学院，江苏徐州221116

刘卫群（1970-），男，上海人，教授，博士生导师，主要从事计算岩石力学、岩体稳定和渗流等研究. E-mail:weiqun_liu@126.com.

收稿日期: 2015-06-18

修回日期: 2016-04-20

网络出版日期: 2019-09-11

基金资助

国家“973”计划（编号：2015CB251602；2009CB219605）；江苏省自然科学基金（编号：BK20141125）联合资助.

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Dual media model of shale layer with anisotropy involved and its simulation on gas migration

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1.State Key Lab for Geomechanics & Deep Underground Engineering,CUMT,Xuzhou 221116,China;
2.School of Mechanics & Civil Engineering,CUMT,Xuzhou 221116,China

Received date: 2015-06-18

Revised date: 2016-04-20

Online published: 2019-09-11

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摘要

页岩储层渗透性的准确预测是优化压裂手段和确定页岩气开采方案的前提。综合考虑地质条件、应力水平和解吸吸附等影响，现有的许多预测模型仍有改进提高的空间。基于双重介质理论，引入裂隙法向弹性模量和渗透率各向异性，分别推导出基质和裂隙的孔隙度和渗透率表达式，联合考虑解吸吸附和介质间质量交换的流固耦合控制方程，开展针对页岩气储层的渗流数值模拟。结果表明，储层压力沿3个主渗透系数方向并非均匀分布，开采周期内，井周水平方向的页岩气开发程度不高，各向异性程度增加明显减小页岩气井的产气速率，垂直水平渗透率的3倍差异也会导致产气速率明显减半。

关键词： 双重孔隙介质; 渗透率; 各向异性; 解吸吸附; 数值模拟

本文引用格式

刘卫群, 王冬妮, 苏强 . 基于页岩储层各向异性的双重介质模型和渗流模拟[J]. 天然气地球科学, 2016 , 27(8) : 1374 -1379 . DOI: 10.11764/j.issn.1672-1926.2016.08.1374

Abstract

It is necessary to accurately foresee the permeability of shale layers in fracturing optimization and gas-exploiting arrangement.Since integrating and reflecting all the influences of geological conditions,in-situ stress levels,adsorption-desorption effects on modeling is a progressive procedure,most of the permeability-foreseeing methods published nowadays could be improved naturally.In this paper,based on dual media theory,we firstly introduced a normal crack elastic modulus and considered infiltration anisotropy,and hence developed new porosity and permeability functions respectively for the matrix or fractures.After that,we employed them to build hydro-mechanical coupling equations with gas desorption and pore-fracture mass exchange.Finally,all the equations were transformed and utilized to simulate shale gas migration in the reservoir.The results show that reservoir pressure is not homogeneously distributed along three principal directions of permeability;within a well-service cycle,the developing degree of shale gas is not high in the horizontal direction around the well;Anisotropy upgrading obviously decreases gas production rate,and surprisingly a 3∶1 vertical-horizontal permeability difference would lead to a half decrease of gas production rate.

Key words： Dual porosity media; Permeability; Anisotropy; Adsorption-desorption; Numerical simulation

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