岩性油气藏 ›› 2026, Vol. 38 ›› Issue (3): 173–181.doi: 10.12108/yxyqc.20260315

• 石油工程与油气田开发 • 上一篇    下一篇

双重孔隙介质油藏CO2驱压力动态特征

曹修太1(), 钟会影1,2(), 孙雨欣1, 周洪亮3, 付京4   

  1. 1 东北石油大学 提高采收率教育部重点实验室， 黑龙江 大庆 163318
    2 中国石油集团公司 油气藏改造重点实验室， 黑龙江 大庆 163318
    3 大庆油田有限责任公司 榆树林公司地质工艺研究所， 黑龙江 大庆 163000
    4 科罗拉多矿业大学 石油工程学院, 科罗拉多 高登 80401
  • 收稿日期:2025-09-23 修回日期:2025-11-06 出版日期:2026-05-01 发布日期:2026-01-22
  • 第一作者:曹修太（2002—），男，东北石油大学在读博士研究生，研究方向为油藏数值模拟及微观尺度下CO2渗流机理。地址：（163318）黑龙江省大庆市高新技术产业开发区学府街99号。Email:19861236313@163.com。
  • 通信作者: 钟会影（1981—），女，教授，博士生导师，现从事孔隙尺度微观渗流机理及油藏数值模拟方面的教学与研究工作。Email:zhhy987@126.com。
  • 基金资助:
    国家自然科学基金“考虑移动接触线特性的粘弹性流体驱油两相渗流相间微界面动力学行为研究”(52374032);黑龙江省自然科学基金项目“考虑复杂裂缝系统的致密油藏渗流理论及产能分析方法研究”(LH2022E023)

Pressure dynamic characteristics of CO2 flooding in dual porosity media reservoirs

CAO Xiutai1(), ZHONG Huiying1,2(), SUN Yuxin1, ZHOU Hongliang3, FU Jing4   

  1. 1 Key Laboratory of Enhanced Recovery of Ministry of Education, Northeast Petroleum University, Daqing 163318, Heilongjiang, China
    2 Key Laboratory of Reservoir Stimulation, China National Petroleum Corporation, Daqing 163318, Heilongjiang, China
    3 Yushulin Company Geological Technology Research Institute， Daqing Oilfield Co., Ltd., Daqing 163318, Heilongjiang, China
    4 Department of Petroleum Engineering, Colorado School of Mines, Golden 80401, Colorado, USA
  • Received:2025-09-23 Revised:2025-11-06 Online:2026-05-01 Published:2026-01-22

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摘要：

页岩油藏经过复杂压裂后易形成双重孔隙介质，由于基质-裂缝的渗流差异及CO2注入后“浓度-黏度”的平面非均质性，使得CO2驱的压力响应机制复杂，导致压力动态表征与参数反演精度不足。通过Fick定律研究了CO2分布特征，建立了同时考虑浓度-黏度-压力耦合、基质启动压力梯度的双重孔隙介质渗流模型，并对渗流方程进行了数值求解，绘制了双重孔隙介质油藏CO2驱压力动态曲线，分析了基质启动压力梯度、弹性储能比、窜流系数、注入速度、扩散系数对压力动态曲线的影响规律。研究结果表明：①基质启动压力梯度越大，试井曲线后期的压力及压力导数曲线“上翘”越显著。②弹性储能比越小，窜流阶段压力导数曲线的“凹子”越宽且越深。③随着窜流系数的减小，流体由基质流向裂缝的窜流速度越慢，“凹子”越靠右方，且“凹子”越深；窜流系数越大，压力曲线上翘越明显。④注入速度越大，全阶段压力和压力导数均呈现上升趋势，且窜流阶段“凹子”宽度越窄。⑤扩散系数主要影响后期的总系统径向流阶段，扩散系数越大，总系统径向流发生的时间越早，流动阻力越小，压力和压力导数曲线越靠下。⑥此模型在大庆油田压裂井CO2注入过程中实现了压力动态特征的定量表征。

关键词: 双重孔隙介质, CO2驱, 压力动态曲线, 启动压力梯度, 弹性储能比, 窜流系数, 注入速度, 扩散系数, 渗流数学模型

Abstract:

Shale oil reservoirs subjected to complex hydraulic fracturing are prone to evolve into dual porosity media. Due to differences in matrix-fracture seepage behavior and the areal heterogeneity of “concentration-viscosity” after CO2 injection, the pressure-response mechanism of CO2 flooding becomes highly complex, resulting in insufficient accuracy in pressure-transient characterization and parameter inversion. Fick’s law was employed to investigate the CO2 distribution characteristics. A dual porosity flow model was established by simultaneously accounting for concentration-viscosity-pressure coupling and the matrix threshold pressure gradient. The governing flow equations are solved numerically to generate pressure-transient curves for CO2 flooding in dual porosity reservoirs, and effects of the matrix threshold pressure gradient, elastic storativity ratio, interporosity-flow coefficient, injection rate, and diffusion coefficient on the pressure-transient behavior were analyzed. The results show that: (1) A larger matrix threshold pressure gradient leads to a more pronounced late-time upturn of both pressure and pressure-derivative curves on the well testing curve. （2） A smaller elastic storativity ratio produces a wider and deeper “trough” in the pressure-derivative curve during the interporosity-flow stage. （3） With decreasing interporosity-flow coefficient, matrix-to-fracture crossflow slows down,the “trough” in the pressure-derivative curve moves to the right and becomes deeper. A larger interporosity-flow coefficient makes the late-time upturn in the pressure curve more evident. （4） A higher injection rate increases both pressure and pressure-derivative levels over the entire testing period and narrows the “trough” during the interporosity-flow stage. （5） The diffusion coefficient mainly influences the radial-flow stage of the composite system in the late stage: a larger diffusion coefficient causes this stage to occur earlier, reduces flow resistance, and shifts the pressure and pressure-derivative curves downward. （6） The proposed model enables quantitative characterization of pressure-transient features during CO2 injection in fractured wells of Daqing Oilfield.

Key words: dual porosity media, CO2 flooding, pressure-transient curve, threshold pressure gradient, elastic storativity ratio, interporosity-flow coefficient, injection rate, diffusion coefficient, seepage mathematical model

中图分类号: 

  • TE353

图1

CO2驱双重孔隙介质油藏物理模型"

图2

裂缝-孔隙型双重孔隙介质油藏结构示意图"

表1

无因次量"

无因次变量 定义 无因次变量 定义
无因次渗透率 ${K}_{D}=\frac{{K}_{m}}{{K}_{f}}$ 无因次半径 ${r}_{D}=\frac{r}{{r}_{w}}$
无因次压力 ${{p}_{D}}_{{}_{j}}\left({r}_{D},{t}_{D}\right)=\frac{2\pi {K}_{f}h}{q{\mu }_{g}B}\left({p}_{0}-{p}_{j}\right)$
j=m,f		 无因次启动压力梯度 ${G}_{D}=\frac{2\pi {K}_{f}h{r}_{w}}{q{\mu }_{g}B}G$
无因次井筒储集系数 ${C}_{D}=\frac{1}{2\pi {\varphi }_{f}{C}_{tf}h{r}_{w}^{2}}C$ 无因次黏度 ${\mu }_{D}=\frac{{\mu }_{0}}{{\mu }_{mix}}$

图3

所建模型与tNavigator软件计算压力动态曲线对比"

表2

大庆油田S151区块油藏参数表"

参数 数值 参数 数值
CO2注入速度/
(m3·s-1)		 4.63×10-4 油藏厚度/m 5.0
扩散系数/(m2·s-1) 2.46×10-6 井筒半径/m 0.1
外边界半径/m 100 体积系数 1.12
基质渗透率/mD 0.500 裂缝渗透率/mD 1 000
启动压力梯度/
(Pa·m-1)		 4×104 井筒存储系数/(m3·Pa-1) 1×10-8
表皮系数 0.1 原油初始黏度/(Pa·s) 0.35×10-3
CO2黏度/(Pa·s) 0.05×10-3 窜流系数 1×10-6
弹性储能比 0.01 综合压缩系数/
Pa-1		 4×10-8

图4

双重孔隙介质油藏CO2浓度变化曲线"

图5

双重孔隙介质油藏混合黏度变化曲线"

图6

双重孔隙介质油藏CO2驱压力动态曲线"

图7

不同无因次启动压力梯度下的压力和压力导数曲线"

图8

不同弹性储能比下w的压力和压力导数曲线"

图9

不同窜流系数下λ的压力和压力导数曲线"

图10

不同CO2注入速度下Q的压力和压力导数曲线"

图11

不同扩散系数相同时间下H的混合黏度曲线（180 d）"

图12

不同扩散系数下H的压力和压力导数曲线"

图13

典型实测双重孔隙介质油藏CO2驱试井拟合曲线"

表3

大庆油田S151区块和S11区块X11井和X302井试井解释结果"

井号 井筒储集系数/(m3·Pa-1) 表皮
系数		 基质
渗透率/mD		 裂缝
渗透率/mD		 窜流系数 弹性
储能比		 扩散系数/
(m2·s-1)		 启动压力梯度/(Pa·m-1)
X11井 2.91×10-8 0.15 0.132 1 120 2.314×10-5 0.112 2.46×10-6 2.4×104
X302井 2.48×10-8 0.20 0.793 1 460 1.056×10-6 0.009 2.12×10-6 —
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