Microscopic characteristics of jimsar shale oil reservoir and oil displacement mechanisms of modified nanofluids

LIU HUANG; TANG LINWEI; YAN RONGSHAN; SONG YATIAN; LIU HAILONG; HUANG HAO

doi:10.13809/j.cnki.cn32-1825/te.2025115

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Microscopic characteristics of jimsar shale oil reservoir and oil displacement mechanisms of modified nanofluids
Vol. 16, Issue 2, Pages: 344-352(2026)
Received：29 July 2025，

Published：26 March 2026
DOI： 10.13809/j.cnki.cn32-1825/te.2025115
稿件说明：

移动端阅览

刘煌, 唐林伟, 晏荣山, 等. 吉木萨尔页岩油藏储层微观特征与改性纳米流体驱油机理[J]. 油气藏评价与开发, 2026, 16(2): 344-352. DOI： 10.13809/j.cnki.cn32-1825/te.2025115.

LIU Huang, TANG Linwei, YAN Rongshan, et al. Microscopic characteristics of jimsar shale oil reservoir and oil displacement mechanisms of modified nanofluids[J]. Petroleum Reservoir Evaluation and Development, 2026, 16(2): 344-352. DOI： 10.13809/j.cnki.cn32-1825/te.2025115.

摘要

页岩油藏效益开发是当前的研究热点和难点，由于页岩油藏具有储层超致密、矿物-有机质混存、原油赋存状态复杂等特征，通常无法采用常规油藏开发技术实现页岩油藏的规模开采。文章以吉木萨尔页岩油藏提高采收率为研究目标，利用微观表征和岩心渗流模拟实验等研究手段，研制了提高页岩油采收率的纳米流体介质并揭示其相关作用机理。首先，采用场发射扫描电镜（SEM）、高压压汞、微CT扫描和激光共聚焦分析技术，分析页岩孔隙结构及原油分布特征；其次，通过复配纳米SiO

颗粒、表面活性剂十六烷基三甲基溴化铵（CTAB）和硅烷偶联剂γ-巯丙基三甲氧基硅烷（KH590），制备稳定分散纳米流体；最后，通过进一步开展地层水和纳米流体渗吸、注CO

吞吐、注CO

驱替、注纳米流体驱替等岩心实验，明确了不同开采方式动用页岩油的差异性及驱油机理。结果表明：吉木萨尔页岩藏储层以微纳米孔为主，形态多样且局部分布微裂缝，随着孔道尺寸减小，其内赋存的原油成分变轻，进而影响开发过程中的生产气油比；页岩原始润湿性为弱亲油（水-岩接触角为110°左右），经纳米流体改性后转变为稳定强亲水特性（接触角小于30°），且复配纳米流体能够长时间保持较好的分散性和稳定性，其密度与地层水相近，避免储层潜在伤害。受制于页岩孔隙尺度小和弱亲油等特征，地层水渗吸、注CO

吞吐和驱替效果不理想，驱油效率均低于15%；注纳米流体渗吸优于地层水渗吸，但作用距离有限；注纳米流体驱替通过润湿反转、化学驱、渗吸置换等多机制复合作用效果，驱油效率可达41.04%，远优于其他开发方式，其中储层改造扩大纳米流体注入和波及范围是矿场实施的关键前提。文章制备的纳米流体可有效改善页岩储层开发条件，其驱替技术对提高采收率有显著优势，对纳米流体改性页岩储层、提高页岩油采收率技术的发展和应用，具有重要指导意义。

Abstract

The efficient development of shale oil reservoirs is a current research focus and challenge. Due to characteristics—such as ultra‑tight formation

coexistence of minerals and organic matter

and the complex occurrence states of crude oil—conventional reservoir development technologies usually cannot achieve large-scale extraction of shale oil reservoirs. This study aims to improve oil recovery for the Jimsar shale oil reservoir. Using research methods such as micro-characterization and core flooding experiments

a nanofluid medium for enhancing oil recovery was developed

and its relevant mechanisms were revealed.

Firstly

field emission scanning electron microscopy (SEM)

high-pressure mercury intrusion

micro-CT scanning

and laser confocal analysis were used to analyze the shale pore structure and the distribution characteristics of crude oil. Subsequently

a stable and dispersed nanofluid was prepared by compounding nano-SiO

particles

the surfactant hexadecyltrimethylammonium bromide (CTAB)

and γ-mercaptopropyltrimethoxysilane (KH590). Finally

core experiments

including imbibition using formation water and nanofluid

huff and puff

flooding

and nanofluid flooding

were further conducted to clarify the differences in shale oil mobilization and the oil displacement mechanisms under different extraction methods. The results showed that the Jimsar shale reservoir pores were predominantly micro- to nano-scale with diverse morphologies and locally distributed micro-fractures. As the pore size decreased

the composition of the crude oil contained within became lighter

thereby affecting the produced gas-oil ratio during the development process. The original wettability of the shale was weakly oil-wet (water-rock contact angle≈110°)

and it was transformed into a stable

strongly water-wet state (contact angle

30°) after nanofluid modification. The compounded nanofluid could maintain good long-term dispersibility and stability

and its density was close to that of formation water

avoiding potential damage to the reservoir. Constrained by characteristics such as small pore size and weak oil-wettability of the shale

the performance of formation water imbibition

huff and puff

and CO

flooding was unsatisfactory

with displacement efficiencies all below 15%. Nanofluid imbibition outperformed formation water imbibition

though its effective distance remained limited. Nanofluid flooding achieved a oil displacement efficiency of 41.04% through the combined effects of multiple mechanisms such as wettability alteration

chemical flooding

and imbibition re

placement

significantly outperforming other development methods. Among them

reservoir stimulation to expand the injection and sweep range of the nanofluid was a key prerequisite for field implementation. The nanofluid developed in this study can effectively improve the development conditions of shale reservoirs

and its flooding technology demonstrates notable advantages in enhancing oil recovery. The findings provide important guidance for the development and application of nanofluid-based shale reservoir modification technology to improve shale oil recovery.

关键词

Keywords

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