Pore network modeling of thin water film and its influence on relative permeability curves in tight formations

He, Minxia; Zhou, Yingfang; Wu, Keliu; Hu, Yongle; Feng, Dong; Zhang, Tao; Liu, Qing; Li, Xiangfang

doi:10.1016/j.fuel.2020.119828

Cited by 38 publications

(23 citation statements)

References 103 publications

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“…Tight reservoirs have a large proportion of nanoscale pores, which are characterized by low porosity and low permeability. Therefore, many scholars [6,15,19] believe that the capillary force is more important than the viscous force in the process of oil migration and accumulation. This means that the migration and accumulation of shale oil is more inclined to the steady-state migration mode, dominated by capillary force.…”

Section: Pore Network Model Simulationmentioning

confidence: 99%

“…The volume of the residual wetting phase depends on the thickness of the wetting film. Water film thickness is not easy to measure experimentally, so we use the disjoining pressure theory to calculate the water film thickness [15]. In the following part, we mainly elaborate on the flow characteristics in organic pores and inorganic pores.…”

Section: Pore Network Model Simulationmentioning

confidence: 99%

“…Another form of water in inorganic substances is water film. According to continuum theory, the flow rate of water film can be expressed as [15]:…”

Section: Water Phase Flow Characteristicsmentioning

confidence: 99%

“…At the same time, the shale oil reservoirs are self-generated and self-stored. Therefore, in the migration stage of the oil phase, we assumed that the organic pores contain just the oil phases and do not contain capillary water or film water [15].…”

Section: Water Phase Flow Characteristicsmentioning

confidence: 99%

“…However, the measurement of gas permeability requires multiple pressure points for testing. Due to the gas slippage effect (Klingberg effect) [15,16], the test's accuracy needs higher experimental pressure for tight cores, which makes the test process of the steady-state method for measuring permeability complicated [17]. The permeability is obtained through a trend line, which limits its accuracy.…”

Section: Introductionmentioning

confidence: 99%

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Microscale Evaluation of Tight Oil Mobility: Insights from Pore Network Simulation

et al. 2021

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Pore network modeling based on digital rock is employed to evaluate the mobility of shale oil in Qingshankou Formation, Songliao Basin, China. Computerized tomography technology is adopted in this work to reconstruct the digital rock of shale core. The pore network model is generated based on the computerized tomography data. We simulate the dynamics of fluid flow in a pore network model to evaluate the mobility of fluid in shale formation. The results show that the relative permeability of oil phase increases slowly in the initial stage of the displacement process, which is mainly caused by the poor continuity of the oil phase. In the later stages, with the increase in the oil phase continuity, the range of relative permeability increases. With the increase of organic matter content, the permeability of the water phase remains unchanged at low water saturation, but gradually increases at high water saturation. At the same time, it can be seen that, with the increase in organic matter content, the isosmotic point of the oil–water phase permeability shifts to the left, indicating that the wettability to water phase gradually weakens.

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Section: Pore Network Model Simulationmentioning

confidence: 99%

Section: Pore Network Model Simulationmentioning

confidence: 99%

“…Another form of water in inorganic substances is water film. According to continuum theory, the flow rate of water film can be expressed as [15]:…”

Section: Water Phase Flow Characteristicsmentioning

confidence: 99%

Section: Water Phase Flow Characteristicsmentioning

confidence: 99%