页岩气藏水力压裂渗吸机理数值模拟研究

doi:10.11885/j.issn.1674-5086.2015.03.11.05

西南石油大学学报(自然科学版) ›› 2017, Vol. 39 ›› Issue (2): 118-124.DOI: 10.11885/j.issn.1674-5086.2015.03.11.05

页岩气藏水力压裂渗吸机理数值模拟研究

雷征东¹, 覃斌², 刘双双¹, 蔚涛¹

1. 中国石油勘探开发研究院, 北京海淀 100083;
2. 保利协鑫石油天然气集团控股有限公司, 北京东城 100010

收稿日期:2015-03-11 出版日期:2017-04-01 发布日期:2017-04-01
作者简介:雷征东,1979年生,男,汉族,重庆人,高级工程师,博士,主要从事油气藏数值模拟、油藏工程、复杂岩性油气田开发等领域的基础理论及应用技术研究工作。E-mail:leizhengdong@petrochina.com.cn;覃斌,1976年生,男,汉族,四川南充人,工程师,博士,主要从事油气藏工程、页岩气/凝析气藏开发等领域的基础理论及应用技术研究。E-mail:9256559@qq.com;刘双双,1982年生,女,汉族,湖北南漳人,工程师,硕士,主要从事油气藏工程、油藏数值模拟等领域的基础理论、应用技术研究。E-mail:liuss622@petrochina.com.cn;蔚涛,1989年生,男,汉族,陕西延安人,工程师,硕士,主要从事油气藏工程、油藏数值模拟等领域的基础理论及应用技术研究。E-mail:taoyu001@petrochina.com.cn

Imbibition Mechanism of Hydraulic Fracturing in Shale Gas Reservoir

LEI Zhengdong¹, QIN Bin², LIU Shuangshuang¹, YU Tao¹

1. Research Institution of Petroleum Exploration and Development, PetroChina, Haidian, Beijing 100083, China;
2. POLY-GCL Petroleum Group Holdings Limited, Dongcheng, Beijing 100010, China

Received:2015-03-11 Online:2017-04-01 Published:2017-04-01
Contact: 雷征东,E-mail:leizhengdong@petrochina.com.cn

摘要/Abstract

摘要： 针对页岩储层在水力压裂作业和生产中渗吸机理及作用规律不清的问题，开展了渗吸机理及其引起的地层伤害评估的研究。建立了考虑不同影响因素的页岩水力压裂渗吸数学模型，包括基质和裂缝流动，气体扩散和解吸，应力敏感效应和毛细管压力，然后，讨论了在压裂气藏和后续生产期间如何通过量化裂缝面表皮演变来评估由于渗吸机制导致的储层伤害现象。结果表明，（1）在试井以及生产阶段渗吸对储层特性有较大影响，极大的毛细管压力是导致渗吸现象和水力裂缝附近水封的主要原因；（2）对于实施了水力压裂增产措施的新井通过探测裂缝压力可以获得原始气体压力；（3）润湿相阻塞导致的储层伤害是影响致密气藏水力压裂井生产能力的主要来源之一。研究结果对于页岩气藏的渗流特性能够提供深刻的理解，尤其是为早期生产阶段降低由渗吸作用可能造成的储层伤害来优化生产提供理论依据。

关键词: 数值模拟, 渗吸机理, 页岩气, 水力压裂, 毛细管压力

Abstract: To better understand the imbibition behavior in shale reservoirs during production and hydraulic fracturing operations, we investigated the imbibition mechanism and evaluated the formation damage resulting from imbibition. This paper first presents a hydro-mechanical model for a shale gas reservoir with consideration for multiple flow regimes, gas diffusion and desorption, stress sensitive effect, and capillary pressure. Then the formation damage caused by the imbibition mechanism is evaluated by quantifying facture face skin evolution during fracture cleanup and subsequent production. The simulation results indicate that (1) the imbibition has a huge influence on reservoir performance in well tests and production periods, and a high capillary pressure is the main cause behind the imbibition phenomenon and water blockage around hydraulic fractures; (2) it is possible to obtain the original gas pressure by detecting the fracture pressure of new wells with hydraulic fracturing stimulation; (3) formation damage caused by wetting phase trapping is one of the main causes impairing well productivity hydraulic fracturing of tight gas reservoirs, which should not be neglected. This research provides a theoretical foundation for a better understanding of reservoir performance of shale gas, especially for optimizing production by reducing formation damage caused by imbibition at an early period.

Key words: numerical simulation, imbibition mechanism, shale gas, hydraulic fracturing, capillary pressure

中图分类号:

TE312

雷征东, 覃斌, 刘双双, 蔚涛. 页岩气藏水力压裂渗吸机理数值模拟研究[J]. 西南石油大学学报(自然科学版), 2017, 39(2): 118-124.

LEI Zhengdong, QIN Bin, LIU Shuangshuang, YU Tao. Imbibition Mechanism of Hydraulic Fracturing in Shale Gas Reservoir[J]. 西南石油大学学报(自然科学版), 2017, 39(2): 118-124.

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页岩气藏水力压裂渗吸机理数值模拟研究

Imbibition Mechanism of Hydraulic Fracturing in Shale Gas Reservoir

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