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钻采工艺 ›› 2021, Vol. 44 ›› Issue (1): 115-119.DOI: 10.3969/J. ISSN.1006-768X.2021.01.27

• 油田化学 • 上一篇    下一篇

高黏滑溜水在秋林致密砂岩气压裂中的应用

冯逢1,张琳羚2,刘波1,张浩3,4,杨波3,蒋欣1   

  1. 1中国石油西南油气田分公司致密油气勘探开发项目部  2中国石油西南油气田分公司勘探开发研究院  3成都理工大学油气藏地质及开发工程国家重点实验室  4成都理工大学能源学院
  • 出版日期:2021-01-25 发布日期:2021-01-25
  • 通讯作者: 杨波
  • 作者简介:冯逢（1985-），本科，工程师，2008年毕业于成都理工大学，现就职于中国石油西南油气田公司致密油气勘探开发项目部，主要从事试油工作。地址：（610056）成都市成华区猛追湾横街99号世茂大厦14层，电话：19980467631，E-mail: ffxn@ petrochina. com. cn。
  • 基金资助:
    中国石油西南油气田分公司科研项目“金华—秋林区块沙溪庙组致密砂岩储层压裂液体体系研究”（编号：XNS致密JS2020-53）；国家自然科学基金面上项目“页岩纳微米储层保护压裂液降滤失作用机理研究”（编号：51874052）。

Application of High Viscosity Slickwater in Fracturing of Qiulin Tight Sandstone Gas Wells 

FENG Feng1, ZHANG Linling2, LIU Bo1, ZHANG Hao3,4, YANG Bo3, JIANG Xin1   

  1. 1. Tight Gas Project Department, PetroChina Southwest Oil & Gas Field Company, Chengdu, Sichuan 610015, China; 2. Exploration and Development Research Institute, PetroChina Southwest Oil & Gas Fields Company, Chengdu, Sichuan 610015, China; 3. State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Chengdu University of Technology, Chengdu, Sichuan 610015, China; 4. College of Energy, Chengdu University of Technology, Chengdu, Sichuan 610015, China
  • Online:2021-01-25 Published:2021-01-25

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摘要： 常规滑溜水压裂液携砂能力弱、耗水量大，而交联胶和线性胶通常具有较高的储层伤害，因此均难以较好地适应致密砂岩气藏的开发。在四川秋林区块沙二段 ８号砂组初期实施的水平井压裂中，采用滑溜水组合线性胶或交联胶的压裂效果不理想。为此筛选了一种乳液型高黏减阻剂，各项指标均优于常规减阻剂：其完全水化时间小于90ｓ；持续高剪切 15 min减阻率仍保持在74％以上；当浓度为 0.05％ ～0.25％，黏度达到 2.86～18.6ｍＰａ·ｓ；岩心渗透率损害率低于10％。在秋林地区5口井的应用表明，高黏减阻剂可以实现全程在线混配并通过调整减阻剂浓度实现变黏，简化了施工；携砂能力强，最高砂浓度可达到520 kg/ｍ3；压后试气效果好，单井初期绝对无阻流量均在30×104 m3/d以上，最高达214×104 m3 /d，平均绝对无阻流量为其它压裂液体系的3～5倍。高黏滑溜水高黏弹性、低伤害的特征有利于提高致密砂岩气藏压裂的增产效果。

关键词: 高黏减阻剂, 高黏滑溜水, 变黏滑溜水, 致密气, 砂岩, 水平井压裂

Abstract:

Conventional slick water fracturing fluids have weak sand-carrying capacity and huge water consumption, while cross-linked gel and linear gel usually have higher reservoir damage, so they are difficult to adapt to the development of tight sandstone gas reservoirs. In the initial stage of horizontal well fracturing in Sichuan Qiulin gas field, the effect was not good by using slickwater combined with linear or cross-linked gel. For this reason, a kind of emulsion-type high viscosity friction reducers (HVFRs) was screened out, which has better performance than conventional friction reducers. The time of complete hydration was less than 90s. The friction reduction still remained above 74% after 15 minutes of continuous high shear. The viscosity reached 2.86 mPa· s - 18.6 mPa· s with the concentration of 0.05% - 0.25% , and the core permeability damage rate was lower than 10%. The application in 5 wells in Qiulin gas field showed that: Variable viscosity slickwater can be prepared on-the fly by adjusting centration of HVFRs, which simplified the operation. The sand carrying capacity was strong and the maximum sand concentration reached to 520 kg/m3 . The low core permeability damage leaded to high gas production: the initial absolute open flow of gas wells was above 30 × 104 m3 /d, the maximum was 214 × 104 m3 /d, and the average was 3 - 5 times of other kinds of fracturing fluids. It’s beneficial for improving the stimulation effect in tight sandstone gas reservoirs resulting from the high viscoelasticity and low damage characteristics of the HVFRs.

Key words: high viscosity friction reducers, high viscosity slickwater, variable viscosity slickwater, tight gas, sandstone, horizontal well fracturing

ISSN 1006-768X
CN 51-1177/TE
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