Lithologic Reservoirs ›› 2019, Vol. 31 ›› Issue (3): 145-151.doi: 10.12108/yxyqc.20190317

• PETROLEUM ENGINEERING • Previous Articles     Next Articles

Shut-in and flow-back pattern of fractured shale gas wells

DU Yang, LEI Wei, LI Li, ZHAO Zhejun, NI Jie   

  1. Research Institute of Petroleum Engineering Technology, Sinopec Southwest Oil & Gas Company, Deyang 618000, Sichuan, China
  • Received:2018-11-26 Revised:2019-02-13 Online:2019-05-21 Published:2019-05-06

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Abstract: Horizontal well staged fracturing is the main technical mean of shale gas reservoir reformation, the large fracturing fluid was injected into the formation but the flow-back rate was relatively low. The pros and cons are still unclear about the retention fracturing fluid in the formation. In order to solve this problem, cores of Longmaxi Formation from well YY1 in Xindianzi structure of Yongchuan were selected to carry out imbibition experiment with slick-water, and the variation rules of core physical properties, pore structure characteristics and micro-structure were compared. The results show that after fracturing fluid imbibition, the average porosity and permeability increased by 50% and 25% respectively, while gas adsorption capacity and specific surface area decreased by 35% and 40% respectively. Micro fissures were created along the bedding direction after imbibition test, and with the continuous infiltration, the fissures expanded and extended, gradually communicated the fracture network, and increased the infiltration area of liquid. Through field test of well YY1 HF, it is found that after 30 days of shut-in test under the production rate of 60 000 m3/d, the production of liquid is greatly reduced, and the production of gas wells is stable. Therefore, post-frac shut-in is beneficial to improve reservoir physical properties and increase seepage channels, and gradual enlargement flow-back strategy is better for gas recovery.

Key words: shale gas, shut-in, fracture fluid, imbibition, flow-back rate

CLC Number: 

  • TE377
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