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裂缝性致密砂岩气藏时变形状因子研究

朱超凡1，李亚军1，桑茜1，宫厚健1，李彦超2，董明哲1,3   

  1. 1．中国石油大学(华东)石油工程学院，山东 青岛 266580；
    2．中国石油集团川庆钻探工程有限公司井下作业公司，四川 成都 610052；
    3．卡尔加里大学化学与石油工程学院，加拿大 卡尔加里  T2N 1N4
  • 收稿日期:2016-09-08 修回日期:2017-04-09 出版日期:2017-05-10 发布日期:2017-05-10
  • 通讯作者: 董明哲(1954-)，男，加拿大人，国家“千人计划”特聘教授，主要从事非常规油气渗流理论与提高采收率研究. E-mail:mtdong@ucalgary.ca.
  • 作者简介:朱超凡(1990-)，男，河南郑州人，博士研究生，主要从事非常规油气渗流理论与提高采收率研究. E-mail:Zhu_Chaof@163.com.
  • 基金资助:

    国家科技重大专项(编号:2016ZX05023-001；2017ZX05049-006)；国家重点基础研究发展计划(973计划)项目(编号:2014CB239103)；国家自然科学基金项目(编号:51674279)联合资助.

The time-dependent shape factor study for tight sandstone with fracture

Zhu Chao-fan1，Li Ya-jun1，Sang Qian1，Gong Hou-jian1，Li Yan-chao2，Dong Ming-zhe1,3   

  1. 1.School of Petroleum Engineering,China University of Petroleum (East China),Qingdao 266580,China;
    2.Chuanqing Drilling Compamy Down-hole Service Corporation,CNPC,Chengdu 610052,China;
    3.Department of Chemical and Petroleum Engineering,University of Calgary,Calgary T2N 1N4,Canada
  • Received:2016-09-08 Revised:2017-04-09 Online:2017-05-10 Published:2017-05-10

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摘要：

形状因子是裂缝性致密砂岩气藏产能模拟分析的重要参数,但研究多集中在常规油气藏中，超低渗透率致密砂岩气藏的形状因子研究尚未开展。通过对Ehsan模型进行改进，运用数值计算方法得到了一维径向基质_裂缝模型时变形状因子，研究了渗透率、孔隙度、基质尺寸对时变形状因子的影响，并运用室内实验对该模型进行验证。结果表明:由于压力在超低渗透率(k<10-5×10-3μm2)基质中传递较慢，超低渗透率致密砂岩气藏形状因子出现明显的3个不同阶段:基质外边界压力下降阶段，基质内边界压力下降阶段，形状因子向稳定过渡阶段。随着渗透率和孔隙度的降低，第一,二阶段所持续时间增加，气体生产时间同时增加。随着基质尺寸的增加，形状因子达到稳定的整体时间增加，但各阶段所持续时间的相对关系未发生变化。通过数值模拟结果与实验结果对比发现，发现运用改进Ehsan模型计算得到的形状因子能够对致密砂岩气藏生产进行较好的预测。它可以为超低渗致密砂岩气藏的产能预测提供更准确的理论方法,也可为试井解释提供合适的形状因子、计算合理的窜流系数。

关键词: 时变形状因子, 致密砂岩, 无限导流能力裂缝, 超低渗基质, 可压缩流体

Abstract:

The matrix-fracture transfer shape factor is an important parameter of the modeling of fluidflow in fractured porous media,researches on it mainly focus on the conventionaloil and gasreservoirs,and it hasnt been developed in the tight gas reservoirs.Numerical method and experiments were conducted to study thematrix-fracture transfer shape factor and test the model.This paper mainly improves the Ehsan Model and obtainsthe time-dependent shape factors of the radial matrix-fracture model by numerical method.Moreover,the effect of the permeability,porosity,media size on the time-dependent shape factor were studied,and then the improved Ehsan Model was verified through the experiment.The results show: The pressure transmission is slow in the ultra-low permeability matrix(k<10-8μm2),so the time-dependent shape factors of tight gas reservoirs can be divided into three stages,including pressure drop stage of the matrix outer boundary,pressure drop stage of the matrix inner boundary and theshape factor transit to stabilization stage.The duration of the first and second stage increases with the decrease of the permeability and porosity,the gas production time increases at the same time.The time of shape factor transit to stabilization increases with the increase of media size,while the relationship between the relative duration doesnt change.It can be found in this paper that we can predict the production of the tight gas reservoirs better with the time-dependent shape factor.It can provide more accurate theory and methods for production forecastinultra-lowpermeability tight sandstone reservoir,and it also can provide suitable shape factor and calculate reasonable interporosityf low coefficient for well test interpretation.

Key words: The time-dependent shape factors, Tight sandstone, Fracture in infinite conductivity, Ultra-lowpermeability matrix, Compressible fluid

中图分类号: 

  • TE31

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