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Analysis of spontaneous imbibition in fractured, heterogeneous sandstone.

机译：裂隙非均质砂岩的自吸性分析。

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摘要

Multiphase flow studies in naturally fractured reservoirs have numerous applications in hydrocarbon recovery, hydrogeology and environmental remediation of subsurface contamination. The presence of natural fractures has significant effects on recovery from oil and gas reservoirs. In these reservoirs, fracture networks serve as better flow paths for fluids, while the porous rock provides storage space. The efficiency of hydrocarbon recovery as well as pollution and contaminant removal from soil and groundwater are mainly controlled by our ability to understand and define fluid transport mechanisms in naturally fractured formations. Appropriate representation of transport properties, such as relative permeability and capillary pressure, is essential for the success of any predictive flow process in permeable media. In addition, the presence of heterogeneities such as fractures, faults, and other geological features adds to the difficulty of assigning flow properties that are representative of the system. The present study focuses on the development and implementation of a numerical model of two-phase flow in fractured rocks showing contrasting rock properties in the form of bedding planes. A unique experimental data set of spontaneous imbibition in a fractured sandstone core is used for the development and verification of the model. This data set consists of a series of high-resolution X-ray computed tomography scans of a rock sample showing local rock heterogeneities, fracture orientation, bedding planes, and fluid saturation as a function of time. An automated history matching approach is proposed to determine relative permeability and capillary pressure curves. A commercial reservoir simulator is used in coordination with an optimization protocol in the proposed history matching iv method. Four different synthetic and a semi-synthetic data sets were used to test the automated history matching approach. Absolute permeability and oil relative permeability curves were predicted in those synthetic cases, using different relative permeability representations. In the semi-synthetic case, known relative permeability for the matrix and capillary pressure for both matrix and the fracture were determined simultaneously using experimental spontaneous imbibition data of a heterogeneous fractured core sample. Results of this study indicate that the automated history matching approach was successful in predicting the absolute permeability, relative permeability and capillary pressure. The effects of transport properties on the imbibition process were also investigated by sensitivity analysis. Results from this work improve understanding of multiphase flow in fractured and heterogeneous porous media and ability to predict fluid migration in fractured reservoirs.
机译：天然裂缝性储层中的多相流研究在油气开采，水文地质学和地下污染的环境修复中具有许多应用。天然裂缝的存在对油气藏的采收具有重大影响。在这些储层中，裂缝网络可作为流体的更好流动路径，而多孔岩石可提供储存空间。碳氢化合物回收以及从土壤和地下水中去除污染和污染物的效率主要受我们了解和定义天然裂缝地层中流体输送机制的能力控制。传输特性（例如相对渗透率和毛细压力）的适当表示，对于任何可预测的渗透性介质流动过程的成功至关重要。另外，诸如裂缝，断层和其他地质特征之类的异质性的存在增加了分配代表系统的流动特性的难度。本研究致力于裂隙岩石两相流数值模型的开发和实现，该模型以层理面的形式显示出对比的岩石特性。破裂的砂岩岩心中自发吸水的独特实验数据集用于模型的开发和验证。该数据集由一系列的高分辨率X射线计算机断层扫描技术对岩石样品进行扫描，显示出局部岩石异质性，裂缝方向，层理面和流体饱和度随时间的变化。提出了一种自动历史匹配方法来确定相对渗透率和毛细管压力曲线。在建议的历史匹配iv方法中，将商业油藏模拟器与优化协议配合使用。使用四个不同的合成数据集和半合成数据集来测试自动历史匹配方法。在这些合成情况下，使用不同的相对渗透率表示法来预测绝对渗透率和油相对渗透率曲线。在半合成情况下，使用异质破裂岩心样品的实验自发吸收数据，同时确定基质的已知相对渗透率以及基质和裂缝的毛细管压力。这项研究的结果表明，自动历史匹配方法可以成功地预测绝对渗透率，相对渗透率和毛细管压力。还通过敏感性分析研究了运输性质对吸收过程的影响。这项工作的结果增进了对裂缝性和非均质多孔介质中多相流的理解以及预测裂缝性储层中流体运移的能力。

著录项

  • 作者

    Basbug, Basar.;

  • 作者单位

    The Pennsylvania State University.;

  • 授予单位 The Pennsylvania State University.;
  • 学科 Petroleum Geology.;Engineering Petroleum.
  • 学位 Ph.D.
  • 年度 2009
  • 页码 185 p.
  • 总页数 185
  • 原文格式 PDF
  • 正文语种 eng
  • 中图分类 石油、天然气工业;
  • 关键词

  • 入库时间 2022-08-17 11:38:29

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