Special Oil & Gas Reservoirs >

2026 , Vol. 33 >Issue 3: 132 - 139

DOI: https://doi.org/10.3969/j.issn.1006-6535.2026.03.015

Drilling & Production Engineering

Hydraulic fracture propagation and optimization of treatment parameters for horizontal wells in the deep shale gas reservoir of the Zu 201 Well Area,western Chongqing

  • ZHANG Haijie ,
  • WANG Xintong ,
  • PU Junwei ,
  • LUO Yuanping ,
  • DING Yi ,
  • LI Yue ,
  • HE Xing ,
  • QUAN Hang
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  • 1. Chongqing Shale Gas Exploration and Development Co.,Ltd.,Chongqing 401120,China;
    2. Chengdu University of Technology,Chengdu,Sichuan 610059,China;
    3. PetroChina Southwest Oil & Gasfield Company,Chengdu,Sichuan 610000,China

Received date: 2025-04-10

  Revised date: 2026-02-24

  Online published: 2026-09-04

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Abstract

Deep shale gas reservoirs are characterized by great burial depth,complex flow mechanisms,and multi-physical-field coupling.Incomplete understanding of fracture propagation and seepage mechanisms has constrained the accuracy of productivity evaluation for such reservoirs.To solve this problem,based on the concept of geology-engineering integration and relying on the Mangrove software platform,this study incorporated field data on drilling,logging,natural fractures,geomechanics,and treatment parameters,together with an unconventional fracture model,to establish a hydraulic fracturing model for the Zu 201 Well area in western Chongqing.The model was validated by microseismic monitoring,and the effects of single-well fracturing treatment parameters on fracture propagation geometry and fracture parameters were investigated.The results show that fracture propagation exhibits dynamic characteristics of vertical layer crossing and lateral extension.Numerical simulation results are consistent with microseismic monitoring data,with an error of only 8.1%.For the typical Well YX2 in the Zu 201 Well Area,the optimal fluid intensity is 40 m3/m;excessive fluid intensity leads to interfracture interference.The optimal fracturing-fluid injection rate is 21 m3/min.The optimal proppant intensity is 4.0 t/m;an excessively high proppant intensity is prone to causing local sand plugging and restricting the extension of some fractures.The stimulated reservoir volume under the optimized scheme is 2 585.44×104 m3,which is 4% higher than that under the original scheme (2 475.40×104 m3).Following the geology-engineering integrated approach,this study validates the fracture propagation model for deep shale gas fracturing through microseismic monitoring and clarifies the propagation pattern of fractures and the influence mechanisms of key treatment parameters,thus providing guidance for hydraulic fracturing stimulation of deep shale gas reservoirs.

Key words： deep shale gas; hydraulic fracturing; fracture propagation; parameter optimization; western Chongqing Block

Cite this article

ZHANG Haijie , WANG Xintong , PU Junwei , LUO Yuanping , DING Yi , LI Yue , HE Xing , QUAN Hang . Hydraulic fracture propagation and optimization of treatment parameters for horizontal wells in the deep shale gas reservoir of the Zu 201 Well Area,western Chongqing[J]. Special Oil & Gas Reservoirs, 2026 , 33(3) : 132 -139 . DOI: 10.3969/j.issn.1006-6535.2026.03.015

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