Estimation of three-phase relative permeability by simulating fluid dynamics directly on rock-microstructure images
Estimation of three-phase relative permeability by simulating fluid dynamics directly on rock-microstructure images
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DOI：
10.1002/2016wr019098
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发表时间：
2017-01-01
影响因子：
5.4
通讯作者：
Tsuji, T.
中科院分区：
文献类型：
--
作者：
Jiang, F.;Tsuji, T.
鉴于世界对能源的需求不断增长，地质二氧化碳封存和提高石油采收率（EOR）技术的结合目前被认为是一个有前途的解决方案，因为它将提供一种减少碳排放到大气中的手段，同时也带来了同时回收石油的经济效益。优化注入策略，以最大限度地提高CO2储存和提高石油采收率的因素，需要复杂的孔隙尺度的流动信息，在油藏系统共存的油，水，和CO2相。在这项研究中，不混溶的三相格子玻尔兹曼（LB）模型被开发用于研究多孔介质中水，油和CO2系统之间的相互作用的复杂的流动状态。该模型能够反映原油运移的两种主要机制，即双排和膜流。提出了利用数字岩石物理（DRP）模拟估算三相相对渗透率的方法。结果表明，CO2的相对渗透率计算使用我们的稳态方法是不敏感的初始石油馏分，如果石油分布最初是均匀的。对Baker（1988）的经验模型进行了测试，发现该模型能够很好地预测三相相对渗透率数据。该数值方法为直接基于岩石微CT图像精确预测三相相对渗透率数据提供了一种新的工具。
Given the world's growing demand for energy, a combination of geological CO2 sequestration and enhanced oil recovery (EOR) technologies is currently regarded as a promising solution, as it would provide a means of reducing carbon emissions into the atmosphere while also leading to the economic benefit of simultaneously recovering oil. The optimization of injection strategies to maximize CO2 storage and increase the oil recovery factors requires complicated pore-scale flow information within a reservoir system consisting of coexisting oil, water, and CO2 phases. In this study, an immiscible three-phase lattice-Boltzmann (LB) model was developed to investigate the complicated flow state with interaction between water, oil, and CO2 systems in porous media. The two main mechanisms of oil remobilization, namely, double-drainage and film flow, can be captured by our model. The estimation of three-phase relative permeability is proposed using the digital rock physics (DRP) simulations. The results indicate that the relative permeability of CO2 as calculated using our steady state method is not sensitive to the initial oil fraction if the oil distribution is originally uniform. Baker's (1988) empirical model was tested and found to be able to provide a good prediction of the three-phase relative permeability data. Our numerical method provides a new tool for accurately predicting three-phase relative permeability data directly based on micro-CT rock images.