Spontaneous Imbibition Characteristics of the Shale in Lucaogou Formation in Santanghu Basin

doi:10.7657/XJPG20200605

Abstract

Abstract:

After fracturing in shale reservoirs, the flowback rate of fracturing fluid is low, and the production capacity varies greatly. A large amount of fracturing fluid stays downhole for a long time and is spontaneously inhaled by the reservoir, which has a great impact on oil-gas development and effective production. Based on some related experiments such as shale oil mobility experiment, static spontaneous imbibition experiment and wettability experiment of the shale, etc., the experiment of fracturing fluid displacing oil with the spontaneous imbibition and the experiment of water displacing oil under constant-pressure in shale were carried out, and the unique spontaneous imbibition characteristics were revealed. On the basis of static spontaneous imbibition experiment, starting from the basic physical phenomenon that shale absorbs water, the spontaneous imbibition capacity of shale was reflected by two characteristic parameters on spontaneous imbibition curve, namely spontaneous imbibition saturation and spontaneous imbibition rate. And the flowback curve for producing fluid was analyzed, which was believed that the results of laboratory experiments had a certain predictive effect on fluid production after shale fracturing. Through the liquid-rock spreading experiment, for the shale from Permian Lucaogou formation in the Santanghu basin, the wettability and the influences of the wettability on spontaneous imbibition capacity and on spontaneous imbibition characteristics were analyzed, finding out that the shale had both lipophilicity and hydrophilicity. After analyzing related data comprehensively, it was concluded that the spontaneous imbibition capacity and spontaneous imbibition characteristics of the shale were mainly controlled and influenced by the microscopic pore structure and wettability of the shale.

Key words: Santanghu basin, Lucaogou formation, shale, fracturing fluid, flowback rate, spontaneous imbibition experiment, spontaneous imbibition saturation, spontaneous imbibition rate, wettability

CLC Number:

TE122.8

WAN Yongqing, CAO Xinyu, LIU Haitao, MA Qiang, BAI Zhaoyang, WANG Qi. Spontaneous Imbibition Characteristics of the Shale in Lucaogou Formation in Santanghu Basin[J]. Xinjiang Petroleum Geology, 2020, 41(6): 666-676.

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