Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

Yongchao Wang, Yanqing Xia, Zihui Feng, Hongmei Shao, Junli Qiu, Suping Ma, Jiaqiang Zhang, Haoyuan Jiang, Jiyong Li, Bo Gao and Lingling Li
Additional contact information
Yongchao Wang: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Yanqing Xia: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Zihui Feng: Research Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, China
Hongmei Shao: Research Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, China
Junli Qiu: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Suping Ma: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Jiaqiang Zhang: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Haoyuan Jiang: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Jiyong Li: Northwest Institute of Eco-Environment and Resources, Chinese Academy of Sciences, Lanzhou 730000, China
Bo Gao: Research Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, China
Lingling Li: Research Institute of Petroleum Exploration and Development, Daqing Oilfield of CNPC, Daqing 163000, China

Energies, 2021, vol. 14, issue 15, 1-10

Abstract: Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens.

Keywords: shale oil; mobility; pore network model; relative permeability (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2021
References: View complete reference list from CitEc
Citations: View citations in EconPapers (3)

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