A dynamic pore-scale network model for two-phase imbibition

Wang, Sen; Feng, Qihong; Dong, Yeliang; Han, Xiaodong; Wang, Shoulei

doi:10.1016/j.jngse.2015.06.005

Cited by 50 publications

(16 citation statements)

References 76 publications

(109 reference statements)

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“…Previous studies have shown that pore geometry determines which imbibition mechanisms occur [58,59]. Based on previously proposed classification methods [59][60][61] and the test results of this study, we classified three types of imbibition mechanisms that occur during the water invasion process: piston-type invasion, tortuous throat flow, and macropore filling. 1) Piston-type invasion.…”

Section: Resultsmentioning

confidence: 98%

Prediction of preferential fluid flow in porous structures based on topological network models: Algorithm and experimental validation

Liu

Zhang³

et al. 2018

Sci. China Technol. Sci.

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The understanding and prediction of preferential fluid flow in porous media have attracted considerable attention in various engineering fields because of the implications of such flows in leading to a non-equilibrium fluid flow in the subsurface. In this study, a novel algorithm is proposed to predict preferential flow paths based on the topologically equivalent network of a porous structure and the flow resistance of flow paths. The equivalent flow network was constructed using Poiseuille's law and the maximal inscribed sphere algorithm. The flow resistance of each path was then determined based on Darcy's law. It was determined that fluid tends to follow paths with lower flow resistance. A computer program was developed and applied to an actual porous structure. To validate the algorithm and program, we tested and recorded two-dimensional (2D) water flow using an ablated Perspex sheet featuring the same porous structure investigated using the analytical calculations. The results show that the measured preferential flow paths are consistent with the predictions.

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Section: Resultsmentioning

confidence: 98%

Prediction of preferential fluid flow in porous structures based on topological network models: Algorithm and experimental validation

Liu

Zhang³

et al. 2018

Sci. China Technol. Sci.

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“…Starting with glass bead packs [18,19], researchers tend to test real reservoir rocks and create a more realistic experimental environment. In previous work, researchers obtained the images of real rock systems after both a non-wetting phase injection (drainage) and a wetting phase injection (imbibition) [20][21][22]. Simulation and experimental examination of the pore-scale multiphase flow behavior has focused on the relative permeability [23,24], fluid distribution [25][26][27][28][29], capillary pressure measurements [30,31], oil recovery [32][33][34], stress sensitivity [35][36][37], wettability [38][39][40][41], and etc.…”

Section: Introductionmentioning

confidence: 99%

Microscopic Determination of Remaining Oil Distribution in Sandstones With Different Permeability Scales Using Computed Tomography Scanning

Yang

Liu

et al. 2019

Journal of Energy Resources Technology

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To investigate the characteristics of oil distribution in porous media systems during a high water cut stage, sandstones with different permeability scales of 53.63 × 10−3 μm2 and 108.11 × 10−3 μm2 were imaged under a resolution of 4.12 μm during a water flooding process using X-ray tomography. Based on the cluster-size distribution of oil segmented from the tomography images and through classification using the shape factor and Euler number, the transformation of the oil distribution pattern in different injection stages was studied for samples with different pore structures. In general, the distribution patterns of an oil cluster continuously change during water injection. Large connected oil clusters break off into smaller segments. The sandstone with a higher permeability (108.11 × 10−3 μm2) shows the larger change in distribution pattern, and the remaining oil is trapped in the pores with a radius of approximately 7–12 μm. Meanwhile, some disconnected clusters merge together and lead to a re-connection during the high water cut period. However, the pore structure becomes compact and complex, the residual nonwetting phase becomes static and is difficult to move; and thus, all distribution patterns coexist during the entire displacement process and mainly distribute in pores with a radius of 8–12 μm. For the pore-scale entrapment characteristics of the oil phase during a high water cut period, different enhance oil recovery (EOR) methods should be considered in sandstones correspondent to each permeability scale.

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“…Nevertheless, the high experimental costs and complex operating procedures limit the application of visualization experiments in sensitivity analysis. Accounting for the inherent defects and limitations in pore-scale experiments, pore-scale numerical simulation can serve as the supplement and extension of experimental studies, which provides an economical and efficient way to explore the formation process of residual oil and the mechanisms of EOR [31]. A series of pore-scale numerical approaches have been developed for two-phase flow.…”

Section: Introductionmentioning

confidence: 99%

A Pore-Scale Investigation of Residual Oil Distributions and Enhanced Oil Recovery Methods

et al. 2019

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Water flooding is an economic method commonly used in secondary recovery, but a large quantity of crude oil is still trapped in reservoirs after water flooding. A deep understanding of the distribution of residual oil is essential for the subsequent development of water flooding. In this study, a pore-scale model is developed to study the formation process and distribution characteristics of residual oil. The Navier–Stokes equation coupled with a phase field method is employed to describe the flooding process and track the interface of fluids. The results show a significant difference in residual oil distribution at different wetting conditions. The difference is also reflected in the oil recovery and water cut curves. Much more oil is displaced in water-wet porous media than oil-wet porous media after water breakthrough. Furthermore, enhanced oil recovery (EOR) mechanisms of both surfactant and polymer flooding are studied, and the effect of operation times for different EOR methods are analyzed. The surfactant flooding not only improves oil displacement efficiency, but also increases microscale sweep efficiency by reducing the entry pressure of micropores. Polymer weakens the effect of capillary force by increasing the viscous force, which leads to an improvement in sweep efficiency. The injection time of the surfactant has an important impact on the field development due to the formation of predominant pathway, but the EOR effect of polymer flooding does not have a similar correlation with the operation times. Results from this study can provide theoretical guidance for the appropriate design of EOR methods such as the application of surfactant and polymer flooding.

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A dynamic pore-scale network model for two-phase imbibition

Cited by 50 publications

References 76 publications

Prediction of preferential fluid flow in porous structures based on topological network models: Algorithm and experimental validation

Prediction of preferential fluid flow in porous structures based on topological network models: Algorithm and experimental validation

Microscopic Determination of Remaining Oil Distribution in Sandstones With Different Permeability Scales Using Computed Tomography Scanning

A Pore-Scale Investigation of Residual Oil Distributions and Enhanced Oil Recovery Methods

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