渝西足201井区深层页岩气藏水平井压裂裂缝扩展及施工参数优化

张海杰; 王欣桐; 蒲俊伟; 罗远平; 丁奕; 李悦; 何兴; 全航

doi:10.3969/j.issn.1006-6535.2026.03.015

特种油气藏 >

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

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

钻采工程

渝西足201井区深层页岩气藏水平井压裂裂缝扩展及施工参数优化

张海杰 ,
王欣桐 ,
蒲俊伟 ,
罗远平 ,
丁奕 ,
李悦 ,
何兴 ,
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1.重庆页岩气勘探开发有限责任公司,重庆 401120;
2.成都理工大学,四川成都 610059;
3.中国石油西南油气田分公司,四川成都 610000

张海杰(1977—),男,高级工程师,2001年毕业于石油大学(北京)地质工程专业,现从事页岩气勘探、开发部署及钻井管理等工作。

收稿日期: 2025-04-10

修回日期: 2026-02-24

网络出版日期: 2026-09-04

基金资助

四川省科技教育联合基金面上项目“深层海相页岩气藏流体跨尺度传质与多场耦合模拟研究”(2024NSFSC2019)

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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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摘要

深层页岩气藏具有埋藏深、流动机理复杂、多物理场耦合等特征,其裂缝扩展规律及渗流机理的研究尚不完备,制约了深层页岩气藏产能评价的准确性。针对该问题,基于地质工程一体化理念并依托Mangrove软件平台,联合钻井、测井、天然裂缝、地质力学、施工参数等现场资料,引入非常规裂缝模型,建立渝西足201井区水力压裂模型,结合微地震监测技术对模型进行验证,并开展单井压裂施工参数对裂缝扩展形态及裂缝参数的影响研究。研究表明:裂缝扩展呈现纵向穿层、横向扩展的动态特征,数值模拟压裂裂缝扩展形态结果与微地震监测数据结果一致,误差仅为8.1%。典型井YX2井最优用液强度为40 m³/m,用液强度过大会导致缝间干扰;最优压裂液排量为21 m³/min;最优加砂强度为4.0 t/m,加砂强度过大易造成局部砂堵,部分裂缝扩展受限。优选方案压裂改造体积为2 585.44×10⁴ m³,较原始方案(2 475.40×10⁴ m³)提高了4.0%。该研究基于地质工程一体化思路,通过微地震监测验证了深层页岩气压裂裂缝扩展模型,明确了裂缝扩展规律与关键施工参数的影响机制,对深层页岩气藏压裂改造具有一定指导意义。

关键词： 深层页岩气; 压裂; 裂缝扩展; 参数优化; 渝西区块

本文引用格式

张海杰 , 王欣桐 , 蒲俊伟 , 罗远平 , 丁奕 , 李悦 , 何兴 , 全航 . 渝西足201井区深层页岩气藏水平井压裂裂缝扩展及施工参数优化[J]. 特种油气藏, 2026 , 33(3) : 132 -139 . DOI: 10.3969/j.issn.1006-6535.2026.03.015

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

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