Gas-Water Two Phase Flow Simulation Based on Pore Network Model for Reservoir Rocks

Mutailipu, Meiheriayi; Liu, Yu; Wu, Bin; Song, Yongchen; Wang, Dayong; Ai, Li

doi:10.1016/j.egypro.2017.12.493

Cited by 6 publications

(5 citation statements)

References 21 publications

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“…In a previous study, the pore network flow simulation model was used to study the influences of the thermodynamic properties and pore structure on the CO 2 -brine seepage characteristics at 323 K and 12.4 MPa with a 6 g/L NaCl solution, providing a fundamental understanding of the CO 2 -brine displacement process under CO 2 reservoir storage conditions [220]. The results indicate that changing the rock-wetting behavior and interactions between the fluid and gas-rock has a significant effect on the gas-flooding process compared to water flooding as the temperature and pressure increase.…”

Section: Effects Of Wettabilitymentioning

confidence: 99%

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Mutailipu,

Xue,

et al. 2023

Energies

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Emission reduction in the main greenhouse gas, CO2, can be achieved efficiently via CO2 geological storage and utilization (CCUS) methods such as the CO2 enhanced oil/water/gas recovery technique, which is considered to be an important strategic technology for the low-carbon development of China’s coal-based energy system. During the CCUS, the thermodynamic properties of the CO2–water–rock system, such as the interfacial tension (IFT) and wettability of the caprock, determine the injectability, sealing capacity, and safety of this scheme. Thus, researchers have been conducting laboratory experiments and modeling work on the interfacial tension between CO2 and the water/brine, wettability of caprocks, the solubility of gas–liquid binary systems, and the pH of CO2-saturated brine under reservoir temperature and pressure conditions. In this study, the literature related to the thermodynamic properties of the CO2–water–rock system is reviewed, and the main findings of previous studies are listed and discussed thoroughly. It is concluded that limited research is available on the pH of gas-saturated aqueous solutions under CO2 saline aquifer storage conditions, and less emphasis has been given to the wettability of the CO2–water/brine–rock system. Thus, further laboratory and modeling research on the wettability alternations of caprock in terms of molecular dynamics is required to simulate this phenomenon at the molecular level. Moreover, simplified IFT and solubility prediction models with thermodynamic significance and high integrity need to be developed. Furthermore, interaction mechanisms coupling with multi-factors associated with the gas–liquid–solid interface properties and the dissolution and acidification process need to be explored in future work.

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Section: Effects Of Wettabilitymentioning

confidence: 99%

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Mutailipu,

Xue,

et al. 2023

Energies

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“…To date, there are two main modeling approaches for the simulation of microscopic seepage of rock using digital core technology-the pore network model and the digital core model (Mutailipu et al 2017). The pore network model replaces complicated pores and throats in the rock with capillaries of different diameters, thus transforming fluid flow in complex pore structure into flow in regular capillaries.…”

Section: Fluid Flow Modelmentioning

confidence: 99%

Investigating microscopic seepage characteristics and fracture effectiveness of tight sandstones: a digital core approach

Song

et al. 2020

Pet. Sci.

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Microscopic seepage characteristics are critical for the evaluation of tight sandstone reservoirs. In this study, a digital core approach integrating microscopic seepage simulation and CT scanning was developed to characterize microscopic seepage and fracture effectiveness (the ratio of micro-fractures that contributes to fluid flow) of tight sandstones. Numerical simulations were carried out for characterizations of tight sandstones. The results show that the axial permeability of the investigated cylindrical tight sandstone from Junggar Basin in China is 0.460 μm2, while the radial permeability is 0.3723 μm2, and the axial and radial effective fracture ratios are 0.4387 and 0.4806, respectively, indicating that cracks are not fully developed and the connectivity between micro-cracks is poor. Directional permeability that is difficult to measure by laboratory experiments can be obtained readily using the proposed method in this paper. The results provide important information for improving the exploration and development of tight sandstone reservoirs.

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“…In recent years, researchers have conducted a great deal of research on pore-scale two-phase flow in rock, among which visualization has gradually become one of the hot spots [9,10]. In this context, there are two major research methods: physical observation experiment [11][12][13][14][15] and numerical simulation [16][17][18][19].…”

Section: Introductionmentioning

confidence: 99%

“…In recent years, with the improvement of pore-scale flow theories and computer performance, the numerical simulation of pore-scale flow in rock has developed rapidly [15][16][17][18][19]. At present, the commonly used simulation methods include the Lattice Boltzmann Method (hereafter referred to as "the LBM") [23][24][25][26][27] and the Navier-Stokes equation based numerical simulation method [28][29][30][31][32][33][34][35].…”

Section: Introductionmentioning

confidence: 99%

Pore-scale gas–water flow in rock: Visualization experiment and simulation

Yao

Cong

et al. 2020

Open Geosciences

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The characteristics of pore-scale two-phase flow are of significance to the effective development of oil and gas resources, and visualization has gradually become one of the hot spots in the research of pore-scale two-phase flow. Based on the pore structure of rock, this research proposed a microscopic glass etching displacement experiment and a Navier–Stokes equation based finite element simulation to study the pore-scale gas–water two-phase flow. Then, this research conducted the proposed methods on the type I, type II and type III tight sandstone reservoirs in the Penglaizhen Formation of western Sichuan Basin, China. Results show that the outcomes of both the microscopic glass etching displacement experiment and the finite element simulation are by and large consistent. The water distributed in the large pores is displaced, and the trapped water mainly exists in the area induced by flow around high-permeability pores, perpendicular pores and disconnected ends of pores. The microscopic glass etching displacement experiment is conducive to better observing the phenomenon of a viscous finger-like breakthrough and air jumps in migration flows in narrow throats, while the finite element simulation has the advantages of cost effectiveness, easy operation and strong experimental reproducibility.

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Gas-Water Two Phase Flow Simulation Based on Pore Network Model for Reservoir Rocks

Cited by 6 publications

References 21 publications

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Investigating microscopic seepage characteristics and fracture effectiveness of tight sandstones: a digital core approach

Pore-scale gas–water flow in rock: Visualization experiment and simulation

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