Imbibition Replacement Rules of Bedding Shale in Lucaogou Formation in Jimsar Sag，Junggar Basin

doi:10.7657/XJPG20240312

Abstract

Abstract:

In order to investigate the production of crude oil during the imbibition period after hydraulic fracturing of the bedding shale in the Permian Lucaogou formation in the Jimsar sag, core imbibition replacement experiments and nuclear magnetic resonance (NMR) technology were combined to quantitatively describe the relative content of crude oil in different pores. Cores from the upper sweet spot in Jimsar sag were used in the experiments to identify the impacts of gravity, anisotropy, gravity differentiation, and hydraulic fracture width on imbibition replacement and quantitative characterization was conducted. The results show that during the spontaneous imbibition process of bedding shale, gravity plays a dynamic role, and the recovery of top imbibition is higher than that of horizontal imbibition. Anisotropy has a significant impact on imbibition of bedding shale, with a larger imbibition displacement of fracturing fluid into parallel bedding and a shorter period to reach imbibition equilibrium compared to vertical bedding, and imbibition recovery of parallel bedding is higher than that of vertical bedding. Gravity differentiation means that during the imbibition at the bottom of the core, the crude oil is displaced by imbibition and stays on the surface of the core to form an oil film, which prevents the fracturing fluid from further entering the matrix, deteriorating the imbibition effect. The recovery of imbibition at the bottom differs by 14.12% from the recovery of imbibition at the top. Given a simulated hydraulic fracture width of 2 mm, the volume of liquid involved in imbibition replacement is limited, causing a rapid decline of water saturation within the simulated fracture, which restricts further imbibition. Therefore, the fracture height should be oriented to pass through parallel bedding, so that the fracture width and the stimulated reservoir volume can be increased.

Key words: Jimsar sag, Lucaogou formation, shale, imbibition displacement, bedding fracture, reservoir stimulation, hydraulic fracture

CLC Number:

TE122.23

TIAN Gang, ZHU Jian, PU Pingfan, XIA An, DONG Zhuo, WU Jiayi, WANG Fei. Imbibition Replacement Rules of Bedding Shale in Lucaogou Formation in Jimsar Sag，Junggar Basin[J]. Xinjiang Petroleum Geology, 2024, 45(3): 346-354.

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岩心编号	直径/cm	长度/cm	渗透率/mD	孔隙度/%	岩样方向
21-1号	2.50	2	0.029 0	6.4	平行于层理
21-2号	2.50	2	0.029 0	6.4	平行于层理
21-3号	2.51	2	0.028 0	6.3	平行于层理
21-4号	2.54	2	0.029 0	6.4	平行于层理
23-2号	2.50	2	0.002 7	6.3	垂直于层理

岩心编号	渗吸方向	渗吸方式
21-1号	平行于层理	顶部渗吸
21-2号	平行于层理	水平渗吸
21-3号	平行于层理	底部渗吸
21-4号	平行于层理	限水量渗吸
23-2号	垂直于层理	水平渗吸

实验条件	影响因素	岩心编号
不同渗吸方向	各向异性	21-2号、23-2号
不同渗吸方式	重力作用	21-1号、21-2号
不同渗吸方式	重力分异	21-1号、21-3号
不同水力压裂裂缝宽度	裂缝宽度	21-2号、21-4号

T₂/ms	孔隙类型
T₂≤10	小孔隙
10<T₂≤100	中孔隙
100<T₂≤1 000	大孔隙