Pore space network characterization with sub-voxel definition

Schena, Gianni; Favretto, Stefano

doi:10.1007/s11242-006-9094-z

Cited by 18 publications

(12 citation statements)

References 14 publications

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“…Particular attention is paid to avoid the removal of clays in the pore space of the digital sample. Some preliminary findings on the digital volume of this sample calculated with a network model are reported elsewhere (Schena and Favretto 2007), where it is shown that the permeability values are of the same order of magnitude as determined from experimental laboratory tests.…”

Section: Analysis Of a Real Porous Samplementioning

confidence: 67%

“…14 and the hydraulic network result (Schena and Favretto 2007) in Table 6. Both the computed results and Carman's correlation overestimate the experimental measurement.…”

Section: Analysis Of a Real Porous Samplementioning

confidence: 99%

“…More recently, Schena and Favretto (2007) and Schena et al (2008) used well-established image analysis transformations in 3D (namely the geodesic distance transform applied to the distance map) to efficiently extract the centred paths in a tomographic pore space and to characterize morphologically the pore space with great detail. Using an unstructured mesh and Finite Element Methods (FEM, hereafter) the local conductivity of pore-connecting conducts could be calculated by assuming fully developed laminar flow.…”

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confidence: 99%

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Analysis of Hydraulic Permeability in Porous Media: From High Resolution X-ray Tomography to Direct Numerical Simulation

et al. 2009

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The development and application of a strategy are presented, for estimating the full tensor of hydraulic permeability of porous media, without any a priori assumption on the principal directions. A comprehensive description of the X-ray tomographic and image analysis techniques is drawn for the quantitative morphological characterization of the pore space. Pore-scale Direct Numerical Simulation is used to compute the velocity and pressure fields in the digital pore space, reconstructed from high-resolution X-ray tomography. A commercial Finite Volume fluid dynamic solver is used, which operates on voxel-based computational meshes. The proposed methodology is validated by reproducing literature results on monodisperse periodic arrays of spheres. The hydraulic permeability of real-life porous media, characterized by highly complex morphology, is compared with laboratory experimental measurements.

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Section: Analysis Of a Real Porous Samplementioning

confidence: 67%

“…14 and the hydraulic network result (Schena and Favretto 2007) in Table 6. Both the computed results and Carman's correlation overestimate the experimental measurement.…”

Section: Analysis Of a Real Porous Samplementioning

confidence: 99%

mentioning

confidence: 99%

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Analysis of Hydraulic Permeability in Porous Media: From High Resolution X-ray Tomography to Direct Numerical Simulation

et al. 2009

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“…[38][39][40]108] do not necessarily reflect properties of particular rocks. Although advanced algorithms for generating irregular pore networks which would characterize the pore space geometry of a desired particular rocks have been developed [70,90], this task is challenging and apparently no routine approach is available. Even in a regular network, the geometry of the cross-sections of the throats can produce unexpected results [8].…”

Section: Discussionmentioning

confidence: 99%

Pore-scale mechanisms of gas flow in tight sand reservoirs

Silin¹,

Kneafsey²,

Ajo‐Franklin³

et al. 2010

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“…Running flow simulations directly on the digital image bypasses the challenging task of building a network characterizing the pore space geometry of the sample under consideration [78,79]. Capillary equilibrium does not uniquely define the fluid distribution in the pore space.…”

Section: Flow Simulation and Evaluation Of Permeabilitymentioning

confidence: 99%

A Multimodal 3D Imaging Study of Natural Gas Flow in Tight Sands

Silin

Kneafsey

Ajo‐Franklin

et al. 2011

SPE Annual Technical Conference and Exhibition

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Pore scale phenomena, especially in multi-phase flow, have a strong impact on the mechanisms and efficiency of gas recovery. We studied the impact of the pore space geometry on single-and two-phase flow properties of tight-sands. X-ray computed tomography (CT) and scanning-electron microscopy (SEM), along with other imaging tools provide insights into pore structure at multiple scales. Segmented micron-scale resolution CT 3D images were used as input data for simulations based on the Maximal Inscribes Spheres (MIS) method. Finite-difference flow simulations of creeping flow on MIS-evaluated equilibrium fluid distribution predict of the relative permeability curves as functions of saturation. A pore-scale model of two-phase gas flow accounts for condensate dropout based on thermodynamic equilibrium. The pore-scale analysis results are applied in optimal-control model of wet gas flow with liquid skin.This study leads to the following conclusions: (a) the estimated minimal wetting fluid threshold saturation, at which the gas phase is disconnected, is much lower than that for conventional sandstones; (b) pore-scale flow simulations suggest that in imbibition, the gas and brine (or other wetting fluid) can block the other phase's flow ("Permeability Jail"), where the blockage of gas is of capillary nature, and the blockage of liquid phase is dynamic; (c) pore-scale simulations of drainage do not show mutual blockage of the fluids; (d) the rate of the local condensate dropout is proportional to the dot product of the local flow velocity and pressure gradient; (e) upscaling of conclusion (d) to Darcy scale leads to condensate dropout rate proportional to the pressure gradient; (f) the optimal-control model suggests that gas well production-rate control may have potential for considerably increasing the total gas recovery. IntroductionMore than a quarter of the natural gas produced in the United States comes from low-permeability tight-sand formations [1]. Tight sands, along with gas shales and coal-bed methane, are unconventional natural gas resources. According to Holditch [2], the best definition of tight gas reservoir is "a reservoir that cannot be produced at economic flow rates nor recover economic volumes of natural gas unless the well is stimulated by a large hydraulic fracture treatment or produced by use of a horizontal wellbore or multilateral wellbores."The rock matrix in tight gas reservoirs is characterized by millidarcy or lower permeability. Access of a gas well to a network of natural or created fractures is critical for production. The gas, which is stored in the matrix pores, must first get into the surrounding fractures and then transported to the producing well. Consequently, the matrix-fracture interaction plays crucial role in gas recovery. The hydrocarbon reservoir double-porosity model [3][4][5] describes this interaction at the reservoir scale. In this study, we focus on pore-scale and local meso-scale aspects of gas flow.Reservoir natural gas is a mixture of methane and other hydrocarbon and no...

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Pore space network characterization with sub-voxel definition

Cited by 18 publications

References 14 publications

Analysis of Hydraulic Permeability in Porous Media: From High Resolution X-ray Tomography to Direct Numerical Simulation

Analysis of Hydraulic Permeability in Porous Media: From High Resolution X-ray Tomography to Direct Numerical Simulation

Pore-scale mechanisms of gas flow in tight sand reservoirs

A Multimodal 3D Imaging Study of Natural Gas Flow in Tight Sands

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