三维数字岩心孔喉特征与驱替参数对渗流驱替能力影响：以鄂尔多斯盆地富县地区长8油层组致密油储层为例

杨晓锋; 屈红军; 张磊岗; 刘贤; 苏帅; 尹虎

doi:10.19509/j.cnki.dzkq.tb20250285

三维数字岩心孔喉特征与驱替参数对渗流驱替能力影响：以鄂尔多斯盆地富县地区长8油层组致密油储层为例

doi: 10.19509/j.cnki.dzkq.tb20250285

杨晓锋^{1a, 1b,},
屈红军^{1a, 1b, ,},
张磊岗^{1a, 1b},
刘贤^{1a, 1b},
苏帅^{1a, 1b},
尹虎^{1a, 2}

1a.
西北大学：地质学系
1b.
西北大学：大陆演化与早期生命全国重点实验室，西安 710069
2.
延长油田公司富县采油厂，陕西富县 727500

基金项目: 国家自然科学基金重大项目课题（41390451）

详细信息

作者简介:
杨晓锋：E-mail：22444013460@qq.com

通讯作者:
E-mail：hongjun@nwu.edu.cn

计量
- 文章访问数: 244
- PDF下载量: 20
- 被引次数: 0
出版历程
- 收稿日期: 2025-06-22
- 录用日期: 2025-11-18
- 修回日期: 2025-11-17
- 网络出版日期: 2025-12-15

Influence of pore-throat characteristics and displacement parameters of 3D digital cores on seepage and displacement capability: A case study of tight oil reservoir of Chang 8 reservoir group in Fuxian area, Ordos Basin

YANG Xiaofeng^{1a, 1b
,},
QU Hongjun^{1a, 1b
, ,},
ZHANG Leigang^{1a, 1b},
LIU Xian^{1a, 1b},
SU Shuai^{1a, 1b},
YIN Hu^{1a, 2}

1a.
Department of Geology
1b.
State Key Laboratory of Continental Evolution and Early Life, Northwest University, Xi'an 710069, China
2.
Fuxian Oil Production Plant, Yanchang Oilfield Company, Fuxian Shaanxi 727500, China

More Information

Author Bio:
E-mail：22444013460@qq.com

Corresponding author: E-mail：hongjun@nwu.edu.cn

摘要

摘要:
目的
鄂尔多斯盆地长 8 段为典型特低孔、特低渗致密砂岩储层，微观孔喉非均质性强、水驱剩余油分布规律复杂；现有数字岩心渗流研究多单独剖析孔隙结构或单一驱替条件，缺少孔喉本征参数与驱替工况协同作用的定量表征体系。厘清微观孔喉结构、驱替参数共同控制下的渗流驱替演化机理，可为富县地区致密油高效注水开发提供微观理论支撑。
方法
以鄂尔多斯盆地富县延长组长 8 致密砂岩储层为研究载体，选取 2 块代表性岩心开展显微 CT 扫描，通过灰度增强、非局部均值滤波、阈值二值化完成切片预处理，依托最大球算法重构三维孔隙网络；开展 REV 单元尺度校验后对孔隙网格粗化、几何缺陷修复，采用 N-S 方程组耦合 Cahn–Hilliard 相场法搭建微观渗流数值模型，分别开展单相水渗流、油水两相水驱油瞬态仿真；设置多梯度驱动压力、油水粘度比两组控制变量，定量对比 YP1、YP2 两类差异化孔喉岩心的渗流与驱替响应规律，系统揭示孔喉结构、驱替参数对渗流驱替效率的协同控制机制。
结果
单相渗流条件下，流体流速、压差集中于细小喉道形成应力集中带，孔隙腔体内流速、压力波动微弱；YP1 样品具备大孔隙、细喉道、强微观非均质特征，驱替演化曲线分段陡变，若要达到与 YP2 同等剩余油饱和度，所需驱动压力显著更高；两类岩心渗透率均随驱动压力增大呈递减趋势，低压区间渗透率保持稳定。细小喉道与复杂孔喉网络产生的应力集中易造成流体封堵、驱替停滞；喉道半径、孔喉非均质性直接控制水驱推进速度与平面波及范围，连通孔隙的体积占比决定有效可动用储集空间规模，孤立微小孔隙易形成永久剩余油滞留区。定量模拟结果显示：喉道半径<8 μm 占比高的 YP1 岩心，提高驱动压力可大幅提升驱替效率；喉道整体偏大的 YP2 样品升压增效幅度微弱；孔隙半径>18 μm 占比高、优势渗流通道发育岩心，降低油水粘度比可拓宽波及范围、改善驱替效果；以微小孔隙为主的岩心，减小粘度比会增大渗流阻力，驱替效率出现衰减。
结论
综合孔喉本征属性与人为驱替工况的耦合响应规律，建立了区分孔隙、喉道两类主控因素的微观驱替定量认识，可为鄂尔多斯盆地富县长 8 致密油储层注水参数优化、剩余油精准预测提供微观数值理论依据。
- 致密储层 /
- CT扫描 /
- 微观孔隙结构 /
- 驱替参数 /
- 渗流驱替能力
Abstract:
Objective
The Chang 8 member of the Yanchang Formation in the Ordos Basin is a typical ultra-low-porosity and ultra-low-permeability tight sandstone reservoir characterized by severe microscopic pore-throat heterogeneity and complex distribution patterns of residual oil after water flooding. Existing studies utilizing digital core simulation mostly focus on the independent characterization of pore structure or single displacement condition, and few quantitative investigations have systematically revealed the synergistic effects of intrinsic pore-throat properties and displacement conditions. A comprehensive quantitative understanding of seepage and displacement evolution mechanism under the joint control of microscopic pore-throat structure and displacement parameters can provide a microscopic theoretical basis for efficient water-flooding development of tight oil in Fuxian area, Ordos Basin.
Methods
In this study, the tight sandstone reservoir in the Chang 8 member of the Yanchang Formation in Fuxian area, Ordos Basin was selected as the study object. Two representative tight sandstone core samples (labeled YP1 and YP2) were collected and scanned by micro-CT scan with a spatial resolution of 1 μm. A series of image preprocessing procedures, including grayscale enhancement, non-local mean filtering, and threshold binarization, were performed to eliminate instrument noise, and the maximal ball algorithm was adopted to reconstruct 3D pore-throat network. Representative elementary volume (REV) analysis was carried out to confirm the stable core calculation unit with a side length of 350 μm. Subsequently, grid coarsening and geometric defect repair were conducted to reduce computational cost. A microscopic seepage numerical model coupling Navier-Stokes (N-S) equations with the Cahn–Hilliard (C-H) phase-field method was established to simulate single-phase water seepage and transient oil-water two-phase displacement separately. Two sets of controlled variables—multiple gradient driving pressures (0.001-500 MPa) and eight groups of oil-water viscosity ratios (0.06-3.00)—were designed to quantitatively compare the seepage and displacement response patterns of YP1 and YP2 with distinct pore-throat configurations.
Results
Under single-phase seepage conditions, fluid velocity and differential pressure were concentrated within narrow throats to form high stress concentration zones, while fluid velocity and pressure fluctuated slightly inside large pore cavities. Sample YP1 was characterized by large pores, small throats, and strong microscopic heterogeneity, and its displacement evolution curves showed segmented steep changes. To achieve the same residual oil saturation as YP2, YP1 required remarkably higher driving pressure. For both samples, the calculated absolute permeability declined continuously as driving pressure increased, while permeability remained stable in the low-pressure range. Stress concentration generated by small throats and intricate pore-throat networks easily caused fluid blockage and displacement stagnation. Throat radius and pore-throat heterogeneity directly controlled the advancing speed and sweep range of water flooding, while the volume fraction of connected pores determined the scale of effectively mobilizable pore space and ultimately controlled final displacement efficiency. Isolated micropores were prone to forming permanent residual oil retention zones. Quantitative simulation results showed that, for cores with a high proportion of throats smaller than 8 μm, increasing driving pressure could greatly improve displacement efficiency, whereas cores dominated by large throats showed limited efficiency improvement after increasing pressure. For samples with abundant pores larger than 18 μm and well-developed preferential seepage channels, reducing the oil-water viscosity ratio could expand the sweep range and improve displacement performance. In contrast, reservoirs dominated by micropores showed higher seepage resistance and lower displacement efficiency when the viscosity ratio decreased. The simulated permeability values (0.32–0.75×10⁻³ μm²) were consistent with laboratory core measurements, which verified the reliability of the established simulation model.
Conclusion
This study distinguishes the respective controlling effects of pores and throats on microscopic oil-water displacement and clarifies their coupling response patterns under different water-flooding parameters. The quantitative relationships among pore-throat configuration, driving pressure, and viscosity ratio can provide a basis for optimizing water-flooding parameters and predicting residual oil for Chang 8 tight oil reservoirs in Fuxian area, Ordos Basin. Unlike previous single-factor simulation studies, this study establishes a complete quantitative evaluation framework considering the joint influence of intrinsic pore-throat properties and artificial displacement conditions, which offers new microscopic insights for the efficient exploitation of analogous tight sandstone reservoirs worldwide.
- tight reservoir /
- CT scan /
- microscopic pore structure /
- displacement parameter /
- seepage displacement capability

HTML全文

图 1 CT 切片预处理、三维数字岩心重构、最大球算法提取及孔喉网络模型

图b 中蓝色区域为阈值分割提取的孔隙；图 e 蓝色代表重建填充后的孔隙空间；图 f 内曲线为流体优势渗流通道，其中蓝色为孔隙，黄、红色分别对应不同尺寸喉道

Figure 1. CT slice preprocessing, 3D digital core reconstruction, extraction via maximal ball algorithm, and pore-throat network model

下载: 全尺寸图片幻灯片

图 2 YP1、YP2 样品孔喉结构参数分布直方图

Figure 2. Histograms of pore-throat structural parameters for samples YP1 and YP2

下载: 全尺寸图片幻灯片

图 3 初始压力0.1 MPa 下单相渗流速度场(a, b)、压力场(c, d)及压差−渗透率拟合曲线(e, f)

Figure 3. Single-phase seepage velocity field (a, b), pressure field (c, d), and differential pressure-permeability fitting curves (e, f) under an initial driving pressure of 0.1 MPa

下载: 全尺寸图片幻灯片

图 4 驱替压力5 MPa 下 YP1、YP2 样品水驱油饱和度演化时序图

模型上、下边界分别为驱替入口与出口，红色表征油相，蓝色表征水相，下同

Figure 4. Temporal evolution of oil and water saturation in samples YP1 and YP2 under a driving pressure of 5 MPa

下载: 全尺寸图片幻灯片

图 5 YP1、YP2 样品驱替过程含油、含水饱和度随时步变化曲线

Figure 5. Variation curves of oil and water saturation with time step during displacement in samples YP1 and YP2

下载: 全尺寸图片幻灯片

图 6 不同驱动压力(a～d)和粘度比(e～h)下累计驱出油量和驱替效率

Figure 6. Cumulative oil displacement and displacement efficiency under different driving pressures (a-d) and viscosity ratios (e-h)

下载: 全尺寸图片幻灯片

图 7 不同驱动压力和粘度比下驱替结果对比

绿色线框用于圈定典型区域，直观突出不同模拟压力、粘度比下油水分布与驱替效果的差异；图c，d为模型局部放大

Figure 7. Comparison of displacement results under different driving pressures and viscosity ratios

下载: 全尺寸图片幻灯片

表 1 样品孔喉结构参数及对比

Table 1. Pore-throat structural parameters and comparison of samples

样品编号	孔隙					喉道	非均质性
样品编号	孤立孔隙数量占比/%	连通孔隙体积占比/%	连通孔隙半径/μm （主流外高占比/%）	数量连通率/%	体积连通率/%	半径/μm（主流外高占比/%）	迂曲度	逐层面孔率标准差
YP1	97.60	85.64	>18（54）	2.40	91.78	<8（83）	2.62	0.028
YP2	97.43	72.67	<18（58）	2.57	76.23	>8（58）	1.58	0.015
对比	YP1>YP2					YP1<YP2	YP1<YP2

下载: 导出CSV

表 2 不同出入口压差下渗流模拟绝对渗透率

Table 2. Absolute permeability obtained from seepage simulations under different inlet-outlet pressure differences

样品编号	驱动压力/MPa	体积流量 Q/(m³·s⁻¹)	流动横截面积A/m²	入口压力 p₁/Pa	出口压力 p₂/Pa	渗透率 K/10⁻³ μm²
YP1	0.1	2.52×10⁻¹¹	2.81×10⁻⁹	9.81×10⁴	3.34	0.32
	0.25	6.28×10⁻¹¹	2.81×10⁻⁹	2.45×10⁵	8.39	0.32
	0.5	1.25×10⁻¹⁰	2.81×10⁻⁹	4.91×10⁵	1.20×10	0.32
	0.8	1.99×10⁻¹⁰	2.81×10⁻⁹	7.85×10⁵	2.72×10	0.32
	1	2.47×10⁻¹⁰	2.81×10⁻⁹	9.81×10⁵	3.43×10	0.32
	10	2.17×10⁻⁹	2.81×10⁻⁹	9.76×10⁶	4.23×10²	0.74
	50	8.95×10⁻⁹	2.81×10⁻⁹	4.84×10⁷	4.19×10³	0.62
	100	1.61×10⁻⁸	2.81×10⁻⁹	9.63×10⁷	1.30×10⁴	0.55
	500	5.90×10⁻⁸	2.81×10⁻⁹	4.76×10⁸	1.79×10⁵	0.41
YP2	0.001	9.11×10⁻¹³	4.40×10⁻⁹	9.87×10²	7.45	0.75
	0.025	2.27×10⁻¹¹	4.40×10⁻⁹	2.47×10⁴	1.90×10²	0.74
	0.05	4.52×10⁻¹¹	4.40×10⁻⁹	4.94×10⁴	3.85×10²	0.74
	0.1	8.94×10⁻¹¹	4.40×10⁻⁹	9.87×10⁴	7.93×10²	0.73
	0.25	2.17×10⁻¹⁰	4.40×10⁻⁹	2.47×10⁵	2.13×10³	0.71
	0.5	4.16×10⁻¹⁰	4.40×10⁻⁹	4.93×10⁵	4.73×10³	0.68
	0.8	6.29×10⁻¹⁰	4.40×10⁻⁹	7.88×10⁵	8.44×10³	0.65
	1	7.58×10⁻¹⁰	4.40×10⁻⁹	9.84×10⁵	1.12×10⁴	0.63
	10	5.44×10⁻⁹	4.40×10⁻⁹	9.71×10⁶	2.76×10⁵	0.46
	50	2.03×10⁻⁸	4.40×10⁻⁹	4.77×10⁷	2.71×10⁶	0.36
	100	3.57×10⁻⁸	4.40×10⁻⁹	9.45×10⁷	7.14×10⁶	0.33
	500	1.24×10⁻⁷	4.40×10⁻⁹	4.60×10⁸	6.37×10⁷	0.25

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