Pore-Network Stitching Method: A Pore-to-Core Upscaling Approach for Multiphase Flow

Kohanpur, Amir H.; Valocchi, Albert J.

doi:10.1007/s11242-020-01491-0

Cited by 17 publications

(6 citation statements)

References 49 publications

Supporting

Mentioning

Contrasting

Unclassified

Order By: Relevance

“…The observation that the dynamics of flow in porous media involves phenomena that occur over a wide range of times and distances has necessitated research to bridge these scales Jackson and Krevor (2020), Jackson et al. (2020), Kohanpur and Valocchi (2020), Rücker, Bartels, Garfi, et al. (2020); Rücker, Bartels, Bultreys, et al.…”

Section: Introductionmentioning

confidence: 99%

Red Noise in Steady‐State Multiphase Flow in Porous Media

Spurin

Rücker

Moura

et al. 2022

Water Resources Research

View full text Add to dashboard Cite

show abstract

Section: Introductionmentioning

confidence: 99%

Red Noise in Steady‐State Multiphase Flow in Porous Media

Spurin

Rücker

Moura

et al. 2022

Water Resources Research

View full text Add to dashboard Cite

show abstract

“…Digital Rock Physics is made possible by advances in high resolution imaging techniques, notably X-ray Microtomography (XCT) (Baker et al, 2012;Singh et al, 2018;Kohanpur and Valocchi, 2020) and focused ion beam scanning electron microscopy (FIB-SEM) (Cnudde and Boone, 2013;Kelly et al, 2016;Welch et al, 2017;Ruspini et al, 2021). The first method, XCT, involves recording hundreds or thousands of two-dimensional (2-D) X-ray scans through a sample that are then computationally reconstructed to create a 3-D image.…”

Section: Rock Imaging Techniques and Sub-resolution Porositymentioning

confidence: 99%

The Impact of Sub-Resolution Porosity on Numerical Simulations of Multiphase Flow

Carrillo,

Soulaine,

Bourg

2021

Preprint

View full text Add to dashboard Cite

Sub-resolution porosity (SRP) is an ubiquitous, yet often ignored, feature in Digital Rock Physics. It embodies the trade-off between image resolution and field-of-view, and it is a direct result of choosing an imaging resolution that is larger than the smallest pores in a heterogeneous rock sample. In this study, we investigate the impacts of SRP on multiphase flow in porous rocks. To do so, we use our newly developed Multiphase Micro-Continuum model to perform first-of-a-kind direct numerical simulations of two-phase flow in porous samples containing SRP. We show that SRP properties (porosity, permeability, wettability) can impact predicted absolute permeabilities, fluid breakthrough times, residual saturations, and relative permeabilities by factors of up to 2, 1.5, 3, and 20, respectively. In particular, our results reveal that SRP can function as a persistent connector preventing the formation of isolated wetting fluid domains during drainage, thus dramatically increasing relative permeabilities to both fluids at low saturations. Overall, our study confirms previous evidence that the influence of SRP cannot be disregarded without incurring significant errors in numerical predictions or experimental analyses of multiphase flow in heterogeneous porous media.

show abstract

“…PNM is also a simulation tool based on the actual physical existence of multiphase flow in porous media [26]. It can complete the simulation of flow in the media with a low computational cost and thereby obtain the relevant attribute parameters, such as relative permeability, capillary force and oil saturation [27]. The advantage of pore network modeling is that it enables flow simulation at the pore scale that is not considered by conventional basin-modeling methods [28].…”

Section: Introductionmentioning

confidence: 99%

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

et al. 2021

View full text Add to dashboard Cite

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.

show abstract

Pore-Network Stitching Method: A Pore-to-Core Upscaling Approach for Multiphase Flow

Cited by 17 publications

References 49 publications

Red Noise in Steady‐State Multiphase Flow in Porous Media

Red Noise in Steady‐State Multiphase Flow in Porous Media

The Impact of Sub-Resolution Porosity on Numerical Simulations of Multiphase Flow

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

Contact Info

Product

Resources

About