Experimental determination of permeability of porous media in the presence of gas hydrates

Delli, Mohana Lakshme; Grozic, J. L. H.

doi:10.1016/j.petrol.2014.05.011

Cited by 163 publications

(64 citation statements)

References 28 publications

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“…Delli and Grozic [] experimentally observed the reduction of water permeability for CO 2 ‐hydrate‐bearing Ottawa 20‐30 sands by using excess‐gas method, similar to the capillary grain‐coating case here, and their results are compared with our reduction curves in Figure b. The experimental permeability data decrease along the linear estimation for capillary grain‐coating curve (solid cyan circles) up to S hyd ~0.3 and then a transitional shift to the capillary pore‐filling curve (solid magenta circles) within the shaded zone.…”

Section: Resultssupporting

confidence: 58%

“…Regardless of initial porosity and packing configuration, the permeability curves are primarily determined by the nucleation pattern. Figure 3b shows experimental data after Delli and Grozic []. Since hydrates are thought to initially nucleate at interparticle contacts at low S hyd , the experimental data align with capillary grain‐coating case.…”

Section: Resultssupporting

confidence: 52%

“…The experimental and numerical estimation of permeability has long been conducted (Figure ) [ Dai and Seol , ; Delli and Grozic , ; Johnson et al ., ; Kleinberg and Griffin , ; Kumar et al ., ; Lee , ; Li et al ., ; Liang et al ., ; Minagawa et al ., ; Sakamoto et al ., ; Wang et al ., ]. Yet because modeling hydrate formation and fluid flow in complex pore geometries has been a challenge, previous studies have focused on idealized hydrate formation in simple pore geometries and homogeneous distribution in pore space, without considering the effect of capillarity on hydrate nucleation and growth.…”

Section: Introductionmentioning

confidence: 99%

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Effect of hydrate nucleation mechanisms and capillarity on permeability reduction in granular media

Kang

Yun

Kim

et al. 2016

Geophysical Research Letters

109

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A model for water permeability reduction in hydrate‐bearing sediments is presented by considering capillary effect in hydrate nucleation. Both grain‐coating and pore‐filling cases are considered. The model is developed from a series of lattice Boltzmann flow simulations. Results show that the permeability decreases quasi‐linearly with increasing hydrate saturation during grain‐coating nucleation and that the permeability tends to be higher than predicted by previous analytical models, in which capillarity is not taken into account. The permeability follows unique reduction curve and is not so sensitive to initial sediment bulk density and grain size distribution. Simulations further show that there is a transition zone at Shyd = 0.3~0.4, where permeability reduction trend switches from grain‐coating model to pore‐filling model. Analyses of tortuosity and surface area confirm that the permeability reduction mechanisms result from pore‐channel blocking in grain‐coating case and pore size reduction in pore‐filling case.

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Section: Resultssupporting

confidence: 58%

Section: Resultssupporting

confidence: 52%

Section: Introductionmentioning

confidence: 99%

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Effect of hydrate nucleation mechanisms and capillarity on permeability reduction in granular media

Kang

Yun

Kim

et al. 2016

Geophysical Research Letters

109

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“…The validation results presented in Figure show that over the entire range of water saturation, MRPC is able to predict the relative permeability much better than the NRP after accounting for relevant phase pressures that can be different at the pore‐scale. The results for gas relative permeability are not as good as the water relative permeability, which shows a near perfect match, but the error is well within an acceptable range considering that the experimental errors for relative permeability of hydrate‐bearing medium can be significantly high as depicted by the data (Delli & Grozic, ; Johnson et al, ; Kumar et al, ; Li et al, ; Liang et al, ). The larger deviation in gas relative permeability compared to water relative permeability is also an issue for conventional hydrocarbon reservoirs where it has been observed (Honarpour, ; Li & Horne, ) that empirical models used to fit the relative permeability data are not able to fit the nonwetting phase (e.g., gas) and the wetting phase (e.g., water).…”

Section: Discussionmentioning

confidence: 91%

A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate‐Bearing Porous Media With Capillarity

Singh

Mahabadi

Myshakin

et al. 2019

Water Resources Research

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Lack of mechanistic models to describe petrophysical properties of mobile phases in gas hydrate‐bearing sediments is one of the key challenges in accurately predicting gas production. The major drawback of empirical models that are used to fit a relative permeability curve for mobile phases in gas hydrate‐bearing sediments is that they are based on experimental data, which are limited, and not able to account for hydrate morphology in pore space. This study proposes a relative permeability model that is mechanistic in nature and developed to account capillarity by building on the original nonempirical relative permeability model that assumes negligible capillary pressure. The proposed model implicitly accounts for capillarity with the help of four empirical parameters (two for each mobile phase) that incorporate each mobile phase pressure. It is shown that the proposed model provides an improved match to relative permeability data (derived from pore‐scale simulation of gas hydrate‐bearing sediments) than nonempirical relative permeability by accounting for the effect of capillary pressure. Additionally, unlike fully empirical models that can predict relative permeabilities reliably only at gas hydrate saturations for which experimental data are available, the proposed model only requires fitting the empirical parameters once with experimental data at any single gas hydrate saturation and then it can then be used to predict relative permeability at any gas hydrate saturation. The mechanistic nature of the proposed model allows studying relative permeability of hydrate‐bearing sediments as a function of hydrate morphology and wettability (fluid phase distribution) besides other physical parameters of the model (e.g., porosity, gas, and water residual saturation). Based on the sensitivity analysis of different hydrate morphologies on gas/water relative permeability, it is found that gas relative permeability is sensitive to hydrate morphologies, while water relative permeability shows little dependency on hydrate localization in pore space.

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“…Saturated water permeability refers to the single‐phase fluid permeability, and it is a hydraulic parameter that largely governs convective heat and mass transfer through hydrate deposits during production. Saturated water permeability of hydrate deposits generally increases with decreasing hydrate saturation in sandy sediments (Delli & Grozic, ; Li et al, ; Liang et al, ; Sakamoto et al, ), and this permeability enhancement due to hydrate dissociation is usually depicted by normalized permeability or relative permeability that is defined as the ratio of the saturated water permeability of hydrate‐bearing sediments over that of hydrate‐free sediments. Appropriate selections of normalized permeability models and their parameter values are basically required by field‐scale numerical simulations of hydrate production, and in the gas hydrate community, empirical and semiempirical models are widely used.…”

Section: Introductionmentioning

confidence: 99%

Pore Fractal Characteristics of Hydrate‐Bearing Sands and Implications to the Saturated Water Permeability

Zhang

Ning

et al. 2020

JGR Solid Earth

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Permeability mainly governs fluid flow through hydrate‐bearing sediments, and its theoretical models play a primary role in the efficiency prediction of gas recovery from hydrate reservoirs by using numerical simulators. Most of these numerical simulators rely on empirical or semiempirical permeability models largely due to the lack of suitable parameters that well quantify the evolution of pore structures. In this study, X‐ray computed tomography scans are conducted on methane hydrate‐bearing sands, followed by extractions of the maximal diameter and fractal dimensions for the pore space occupied by fluids. These extracted parameters, including area and volume pore‐size fractal dimensions, tortuosity fractal dimension, and the area maximal pore diameter, are further extended to develop fractal theory‐based models for predictions of the hydraulic tortuosity and the saturated water permeability in hydrate‐bearing sands. Results show that the pore space occupied by fluids within hydrate‐bearing sands is inherently fractal. The area pore‐size fractal dimension decreases but the tortuosity fractal dimension changes little with increasing hydrate saturation, and the sum of these two fractal dimensions can be used to predict the volume pore‐size fractal dimension. In addition, the area maximal pore diameter decreases with increasing hydrate saturation, and a semiempirical model is proposed. The fractal theory‐based permeability reduction model agrees well with available experimental data, and it can capture the essential physics of saturated water permeability reduction in hydrate‐bearing sediments during hydrate formation.

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Experimental determination of permeability of porous media in the presence of gas hydrates

Cited by 163 publications

References 28 publications

Effect of hydrate nucleation mechanisms and capillarity on permeability reduction in granular media

Effect of hydrate nucleation mechanisms and capillarity on permeability reduction in granular media

A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate‐Bearing Porous Media With Capillarity

Pore Fractal Characteristics of Hydrate‐Bearing Sands and Implications to the Saturated Water Permeability

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