苏北盆地陆相页岩油高强度压裂增产措施研究

邸士莹; 马收; 蔡履忠; 程时清; 史文洋

doi:10.13809/j.cnki.cn32-1825/te.2024587

油气藏评价与开发 >

2025 2024587

DOI: https://doi.org/10.13809/j.cnki.cn32-1825/te.2024587

苏北盆地陆相页岩油高强度压裂增产措施研究

邸士莹 ,
马收 ,
蔡履忠 ,
程时清 ,
史文洋

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1.中石化华东石油工程有限公司华美孚泰油气增产技术服务有限责任公司,北京 100101;
2.中石化华东石油工程有限公司,江苏南京 210019;
3.中国石油大学（北京）石油工程教育部重点实验室,北京 102249;
4.常州大学石油与天然气工程学院,江苏常州 213164

邸士莹（1982—）,女,博士,高级工程师,主要从事页岩油气渗吸机理、油气藏增产技术研究,地质工程一体化研究。地址：北京市朝阳区北辰世纪中心A座938室,邮政编码：100101。E-mail：dishiying_320@163.com

收稿日期: 2024-12-02

网络出版日期: 2025-12-29

基金资助

国家自然科学基金项目“致密油藏注水诱发微裂缝机理反演化方法”（11872073）; 2022年教育部“春晖计划”合作科研项目“断溶体油藏多分支储层产液规律研究”（HZKY20220144）; 中石化华东石油工程有限公司项目“页岩水力压裂天然裂缝扩展研究”（ECPE20230315）

收起

Research on high intensity fracturing stimulation measures for continental shale oil in Subei Basin

DI Shiying ,
MA Shou ,
CAI Lyuzhong ,
CHENG Shiqing ,
SHI Wenyang

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1. SinoFTS Petroleum Services Ltd., Beijing 100101, China;
2. Sinopec East China Petroleum Engineering Company, Nanjing, Jiangsu 225100;
3. MOE Key Laboratory of Petroleum Engineering, China University of Petroleum (Beijing), Beijing 102249, China;
4. School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou, Jiangsu 213164,China

Received date: 2024-12-02

Online published: 2025-12-29

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摘要

页岩油藏结构复杂,储层普遍具有低渗、低孔特征,基质向裂缝的供液能力较弱,压裂增产措施是改善储层裂缝发育程度与流体流动能力的关键手段。传统压裂施工方案中,针对储层结构特征对压裂强度影响的直接研究较少,导致增产效果不佳。为优化压裂方案,基于储层结构开展系统研究,通过X射线衍射实验（XRD）明确岩石矿物成分及含量;借助小直径真三轴实验获取岩石力学参数及应力-应变测试曲线;结合电镜扫描资料与薄片观察确定储层微观结构;利用渗吸实验及核磁共振实验（NMR）,基于T₂谱曲线分析储层岩石孔径分布特征。采用数值模拟手方法,对比常规强度压裂与高强度压裂后的裂缝扩展形态及产能差异。研究结果表明,苏北页岩脆性矿物含量较高;平行层理方向页岩破坏后裂缝主要沿层理发育,垂直层理方向破裂形态多样,岩心内部形成交叉复杂裂缝;储层微观结构以粒间孔为主,微裂缝以层理缝为主;核磁共振T₂谱曲线显示储层岩心发育小孔隙、中孔隙及天然微裂缝。数值模拟结果显示,该区块岩石特征适配高强度压裂方案（排量20 m³/min、单段液量4 000 m³、单段砂量400 m³）。实施该方案后,水平井附近储层含油饱和度场与压力场发生明显变化,表明高强度压裂可形成更复杂的缝网系统,提升储层流体流动性,有效改善压裂增产效果。研究成果为页岩油藏压裂增产方案优化提供了参考依据。

关键词： 苏北盆地; 陆相页岩油; 矿物组分; 岩石力学参数; 微观结构; 孔径分布; 渗吸作用; 高强度压裂

本文引用格式

邸士莹 , 马收 , 蔡履忠 , 程时清 , 史文洋 . 苏北盆地陆相页岩油高强度压裂增产措施研究[J]. 油气藏评价与开发, 2025 : 2024587 . DOI: 10.13809/j.cnki.cn32-1825/te.2024587

Abstract

Shale oil reservoirs are characterized by complex structures, ultra-low permeability and low porosity. The fluid supply capacity from the matrix to the fractures is not sufficient. Fracturing stimulation measures can effectively increase the complexity of the reservoir fractures and enhance the fluid flow capacity. There are few studies directly exploring the influence of reservoir structural features on fracturing intensity in traditional fracturing operation designs, which leads to unsatisfactory results of fracturing stimulation measures.To optimize the fracturing design, starting from the reservoir structure, the data from XRD experiments were analyzed to clarify the mineral composition and content of the reservoir rocks; small-diameter true triaxial experiments were carried out to obtain the rock mechanical parameters and stress-strain test curves; the scanning electron microscope data and thin section observation images were analyzed to determine the microscopic structure of the reservoir; and imbibition experiments and nuclear magnetic resonance experiments were conducted, and the pore size distribution characteristics of the reservoir rocks were analyzed based on the T₂ spectrum curves. The study on the fracture propagation patterns after conventional and high-intensity fracturing stimulation measures was conducted by means of numerical simulation, and the analysis of production capacity evaluation for both measures was also carried out. The results indicate that the brittle minerals in the shale of northern Jiangsu Province are abundant. Fractures mainly occur along the bedding direction after the shale along the parallel bedding direction is damaged. The fracture patterns of shale along the vertical bedding direction are diverse and complex interlaced fractures are formed inside the core. The microscopic structure of the reservoir mainly consists of intergranular pores and the micro-fractures are mainly layer-bedding fractures. The T₂ spectrum curve obtained from the nuclear magnetic resonance experiment shows that the reservoir core contains small pores, medium pores and natural micro-fractures. The numerical simulation results indicate that the rock characteristics of this block are suitable for implementing the high-intensity fracturing stimulation measures, and the parameters of this scheme are a displacement rate of 20 m³/min, a single-stage fluid volume of 4 000 m³ and a single-stage sand volume of 400 m³. The oil saturation field and pressure field in the reservoir near the horizontal well have undergone significant changes after the implementation of this measure. This indicates a more complex fracture network has formed near the horizontal well after the application of high-intensity fracturing, enhancing the fluid mobility of the reservoir and improving the effectiveness of the fracturing stimulation measures. This research achievement provides a reference idea for the fracturing stimulation measures in shale oil reservoirs.

Key words： Subei Basin; continental shale oil; mineral components; rock mechanics parameters; microstructure; pore size distribution; imbibition effect; high intensity fracturing

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