页岩气井复合暂堵泵压数学模型及影响因素

孔祥伟; 卾玄吉; 齐天俊; 陈青; 任勇; 王素兵; 李亭; 刘宇

doi:10.3969/j.issn.1006-6535.2023.04.019

特种油气藏 >

2023 , Vol. 30 >Issue 4: 156 - 162

DOI: https://doi.org/10.3969/j.issn.1006-6535.2023.04.019

钻采工程

页岩气井复合暂堵泵压数学模型及影响因素

孔祥伟 ,
卾玄吉 ,
齐天俊 ,
陈青 ,
任勇 ,
王素兵 ,
李亭 ,
刘宇

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1.长江大学石油工程学院,湖北武汉 430000;
2.长江大学油气钻完井技术国家工程研究中心,湖北武汉 430000;
3.中国石油川庆钻探工程有限公司,四川成都 610000

孔祥伟(1982—),男,副教授,2005年毕业于黑龙江科技大学信息与计算科学专业,2014年毕业于西南石油大学油气井工程专业,获博士学位,现从事油气井力学及储层改造方面的教学与科研工作。

收稿日期: 2022-12-10

修回日期: 2023-04-17

网络出版日期: 2023-09-18

基金资助

中国石化科技部“十三五”重点规划项目“川西中浅层致密砂岩气藏体积压裂关键技术”(P22047);国家自然科学基金“超深裂缝地层溢流多相流动机理及气体侵入类型识别研究”(52274001);校企合作项目“压裂靶向暂堵关键施工参数优化设计技术及现场试验”(CQCJ-2001-06)

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Study on Mathematical Model and Influencing Factors of Composite Temporary Plugging Pump Pressure in Shale Gas Wells

Kong Xiangwei ,
E Xuanji ,
Qi Tianjun ,
Chen Qing ,
Ren Yong ,
Wang Subing ,
Li Ting ,
Liu Yu

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1. School of Petroleum Engineering, Yangtze University, Wuhan, Hubei 430000, China;
2. National Engineering Research Center for Oil and Gas Drilling and Completion Technology, Yangtze University, Wuhan, Hubei 430000, China;
3. CNPC Chuanqing Drilling Engineering Co., Ltd., Chengdu, Sichuan 610000, China

Received date: 2022-12-10

Revised date: 2023-04-17

Online published: 2023-09-18

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摘要

目前页岩气井压裂的泵压预测主要依靠商业软件拟合,预测暂堵剂用量与泵压的数学模型较少。为此,考虑暂堵剂运移终速度、缝宽、暂堵剂阻力等因素,提出了复合暂堵泵压预测数学模型,分析了复合暂堵参数对泵压的影响。结果表明:随复合暂堵剂用量增大,泵压升高;复合暂堵剂同单一暂堵剂相比,复合暂堵剂用量对泵压影响更敏感;随暂堵粒径增大,泵压峰值呈现增大趋势;复合暂堵剂的起压及升压时间较单一暂堵剂明显减小,暂堵效果更佳;复合暂堵剂用量为180 g时,升压时间为31 s,泵压峰值可达到17.5 MPa,与粒径为0.8 mm的暂堵剂相比,升压时间缩短51 s,泵压峰值增大2.7 MPa,升压速度增大63.09%。室内实验和现场应用表明,泵压计算值与实测值最大误差分别为6.76%和6.27%。复合暂堵泵压预测数学模型对暂堵剂用量设计以及暂堵效果评价具有指导意义。

关键词： 深层页岩气; 复合暂堵; 泵压; 暂堵剂

本文引用格式

孔祥伟 , 卾玄吉 , 齐天俊 , 陈青 , 任勇 , 王素兵 , 李亭 , 刘宇 . 页岩气井复合暂堵泵压数学模型及影响因素[J]. 特种油气藏, 2023 , 30(4) : 156 -162 . DOI: 10.3969/j.issn.1006-6535.2023.04.019

Abstract

At present, the pump pressure prediction of shale gas well fracturing mainly relies on commercial software fitting, and there are few mathematical models for predicting the amount of temporary plugging agent and pump pressure. To this end, a mathematical model for pump pressure prediction of composite temporary plugging was proposed by taking into account the final speed of temporary plugging agent migration, fracture width, temporary plugging agent resistance and other factors, and the effect of composite temporary plugging parameters on pump pressure was analyzed. The result shows that with the dosage increase of composite temporary plugging agent dosage, the pump pressure increases; compared with the single temporary plugging agent, the dosage of composite temporary plugging agent dosage is more sensitive to the pump pressure; with the increase of temporary plugging particle size, the peak pump pressure shows an increasing trend; the pressure starting and boosting time of composite temporary plugging agent is significantly reduced compared with the single temporary plugging agent, and the temporary plugging effect is better; when the dosage of composite temporary plugging agent is 180 g, the pressure boosting time is 31 s, and the peak pump pressure can reach 17.5 MPa, compared with the temporary plugging agent with the particle size of 0.8 mm, the boosting time is shortened by 51 s, the peak pump pressure is increased by 2.7 MPa, and the boosting speed is increased by 63.09%. Indoor experiments and field applications show that the maximum errors between the calculated and measured pump pressure values are 6.76% and 6.27% respectively. It has guidance significance of the mathematical model of composite temporary plugging pump pressure prediction to the dosage of temporary plugging agent and the evaluation of temporary plugging effect.

Key words： deep shale gas; composite temporary plugging; pump pressure; temporary plugging agent

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