低温固化型甲基丙烯酸甲酯树脂井筒修复体系的优选与评价

毕卫宇; 何治武; 王智勇; 周佩; 王小勇; 刘笑春

doi:10.3969/j.issn.1006-6535.2025.05.020

特种油气藏 >

2025 , Vol. 32 >Issue 5: 167 - 174

DOI: https://doi.org/10.3969/j.issn.1006-6535.2025.05.020

钻采工程

低温固化型甲基丙烯酸甲酯树脂井筒修复体系的优选与评价

毕卫宇 ,
何治武 ,
王智勇 ,
周佩 ,
王小勇 ,
刘笑春

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1.中国石油长庆油田分公司,陕西西安 710021;
2.咸阳师范学院化学与化工学院,陕西咸阳 712000;
3.低渗透油气田勘探开发国家工程实验室,陕西西安 710021;
4.中国石油长庆油田分公司采油一厂,陕西延安 716000

毕卫宇(1975—),男,高级工程师,1997年毕业于抚顺石油学院化学工程专业,2009年毕业于西北大学化学工程专业,获博士学位,现从事提高采收率方面的研究工作。

收稿日期: 2024-10-24

修回日期: 2025-08-01

网络出版日期: 2025-10-30

基金资助

中国石油科技专项“低渗/致密油藏大幅提高采收率关键技术研究”(2023ZZ17)

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Optimization and evaluation of low-temperature curable methyl methacrylate resin wellbore repair system

BI Weiyu ,
HE Zhiwu ,
WANG Zhiyong ,
ZHOU Pei ,
WANG Xiaoyong ,
LIU Xiaochun

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1. PetroChina Changqing Oilfield Company, Xi′an, Shaanxi 710021, China;
2. College of Chemistry and Chemical Engineering, Xianyang Normal University, Xianyang, Shaanxi 712000, China;
3. National Engineering Laboratory for Exploration and Development of Low-Permeability Oil and Gas Fields, Xi′an, Shaanxi 710021, China;
4. PetroChina Changqing Oilfield Company, No.1 Oil Production Company, Yan′an, Shaanxi 716000, China

Received date: 2024-10-24

Revised date: 2025-08-01

Online published: 2025-10-30

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摘要

CO₂驱油与封存过程中,受力学因素影响,可能导致井筒完整性缺失,出现气体窜逸和泄漏现象。针对该问题,以甲基丙烯酸甲酯为主剂,添加氧化还原引发剂和交联剂,研制了低温(30～45 ℃)固化型甲基丙烯酸甲酯(MMA)树脂井筒修复体系,并进行了性能评价。研究表明:在40 ℃条件下,该树脂修复体系的初凝时间为8.2 h,固化时间为10.4 h;修复体系具有良好的注入性能和黏结性能,表面张力为27.1 mN/m,与砂岩、N80钢片以及油井水泥的接触角均小于30°,与水泥柱-钢管界面的黏结强度较未修复前提高13.15倍。修复体系具有良好的CO₂封窜性能和耐CO₂老化性能,对水泥柱-钢管界面修复后,CO₂突破压力为26.78 MPa;在CO₂老化条件下,石英砂固结体的抗压强度及CO₂渗透率在30 d内变化幅度小于5.0%;该树脂修复体系可以进入尺寸为20～100 m的微孔隙中,并在固化后对其进行紧密充填。该井筒修复体系对于低温储层开展CO₂驱油与封存具有重要应用价值。

关键词： CO₂驱油与封存; 井筒完整性; 井筒修复; 甲基丙烯酸甲酯; 树脂

本文引用格式

毕卫宇 , 何治武 , 王智勇 , 周佩 , 王小勇 , 刘笑春 . 低温固化型甲基丙烯酸甲酯树脂井筒修复体系的优选与评价[J]. 特种油气藏, 2025 , 32(5) : 167 -174 . DOI: 10.3969/j.issn.1006-6535.2025.05.020

Abstract

During CO₂ flooding and storage, influenced by mechanical factors, wellbore integrity may be compromised, leading to gas channeling and leakage. In response to this problem, a low-temperature (30-45 ℃) curable methyl methacrylate (MMA) resin wellbore repair system was developed using methyl methacrylate as the main agent, with the addition of redox initiators and cross-linking agents. Performance evaluation of the system was subsequently conducted. The study shows that at 40 ℃, the initial setting time of this resin repair system is 8.2 hours, and the curing time is 10.4 hours; the repair system has good injection performance and adhesion performance, with a surface tension of 27.1 mN/m, and contact angles with sandstone, N80 steel sheet, and oil well cement are all less than 30°. The bonding strength at the cement-steel pipe interface is increased by 13.15 times compared to before repair. The repair system has good CO₂ channeling sealing performance and CO₂ aging resistance. After repairing the cement-steel pipe interface, the CO₂ breakthrough pressure is 26.78 MPa; under CO₂ aging conditions, the compressive strength and CO₂ permeability of the quartz sand consolidated body change by less than 5.0% within 30 days; this resin repair system can enter micro-pores with sizes of 20-100 μm and tightly fill them after curing. This wellbore repair system has important application value for CO₂ flooding and storage in low-temperature reservoirs.

Key words： CO₂ flooding and storage; wellbore integrity; wellbore repair; methyl methacrylate; resin

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