石油学报 ›› 2014, Vol. 35 ›› Issue (3): 511-518.DOI: 10.7623/syxb201403013

• 油田开发 • 上一篇    下一篇

川西页岩-砂岩交互水平井压裂参数优化设计

郭建春1, 苟波1, 任山2, 刘林2, 王兴文2   

  1. 1. 西南石油大学油气藏地质及开发工程国家重点实验室 四川成都 610500;
    2. 中国石油化工股份有限公司西南油气分公司工程技术研究院 四川德阳 618000
  • 收稿日期:2013-11-28 修回日期:2014-03-03 出版日期:2014-05-25 发布日期:2014-04-11
  • 通讯作者: 苟 波,男,1984年6月生,2008年获西南石油大学学士学位,现为西南石油大学博士研究生,主要从事油气藏增产技术与理论研究及现场应用工作。Email:gouboyouxiang@163.com
  • 作者简介:郭建春,男,1970年9月生,1992年获西南石油学院学士学位,1998年获西南石油学院油气田开发工程专业博士学位,现为西南石油大学石油与天然气工程学院院长、教授、博士生导师,主要从事油气藏开采和增产技术方面的研究和教学。Email:guojianchun@vip.163.com
  • 基金资助:

    国家重大科技专项(2011ZX05002-004-007HZ)、国家自然科学基金项目(No.51374178)和四川省青年科技创新研究团队资助计划项目(2011JTD0018)资助。

Fracturing parameters optimization design for horizontal well with shale and sandstone interbeds in western Sichuan

Guo Jianchun1, Gou Bo1, Ren Shan2, Liu Lin2, Wang Xingwen2   

  1. 1. State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China;
    2. Institute of Engineering and Technology, Sinopec Southwest Oil & Gas Company, Deyang 618000, China
  • Received:2013-11-28 Revised:2014-03-03 Online:2014-05-25 Published:2014-04-11

摘要:

针对川西须家河组五段页岩-砂岩交互及埋藏深情况下的水平井无成熟压裂优化设计方法可借鉴的难题,以XYHF-2井为例,从脆性指数、天然裂缝发育程度、地应力等方面分析了水力裂缝形态;将压后复杂的水力裂缝形态等效为高渗透带,采用数值模拟方法以累积产量为目标优选了高渗透带特征参数;根据等效渗流原理,建立了高渗透带特征参数、岩石力学参数、实验测试导流能力和压裂规模的数学关系模型,并确定了各段压裂规模。研究结果表明:砂岩段容易形成中等水平复杂性的裂缝系统,页岩段容易形成低水平复杂性的裂缝系统;高渗透带特征参数对累积产量的影响程度从大到小依次为:高渗透带数量、高渗透带渗透率和高渗透带长度,XYHF-2井最优的高渗透带数量为10段,渗透率为1.5 mD,单翼长度为160 m。现场应用结果表明,该设计方法符合须家河组五段地质特征,取得了工区非常规储层的勘探开发突破。该设计方法可以进一步推广至须家河组五段后续压裂井的方案设计。

关键词: 页岩-砂岩交互, 体积压裂, 复杂裂缝, 高渗透带, 水平井, 优化设计

Abstract:

The unconventional reservoir in the Member 5 of Xujiahe Formation is deeply buried with sandstone and shale interbedding, which led to the lack of method of optimized fracturing design for horizontal well. Based on the analysis of brittleness index, development degree of natural fracture and ground stress, the paper predicts the morphology of hydraulic fractures in Well XYHF-2. Then the complex hydraulic fractures are treated as a high permeability zone (HPZ) and the HPZ parameters are optimized for the goal of cumulative production by means of numerical simulation. According to the principle of equivalent of porous flow, the model of the relationship among the HPZ parameters, rock mechanics parameters, flow conductivity data from experimental test and treatment size is established. The study results show that the intermediate-level complex fractures are presented easily in tight sandstone while low-level complex fractures are created in shale effortlessly. The influence of HPZ parameters on cumulative production is different, according to the order of largest to smallest, following as the amount of number, permeability and length. The optimal HPZ parameters are 10 stages for number, 1.5 mD for permeability and 160 m for fracture half length in Well XYHF-2. The field application shows that the design method is fit for the geologic characteristics of the Member 5 of Xujiahe Formation and can be extended to subsequent horizontal wells. The Well XYHF-2 also obtains the breakthrough of unconventional reservoir exploration and development in the Member 5 of Xujiahe Formation.

Key words: shale and sandstone interbeds, volume fracturing, complex fractures, high permeability zone, horizontal well, optimization design

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