State-of-the-Art of Gas Hydrates and Relative Permeability of Hydrate Bearing Sediments

Joseph, Jeevan; Singh, Devendrá; Kumar, Pushpendra; Dewri, S. K.; Tandi, C.; Singh, Jai Ram

doi:10.1080/1064119x.2015.1025929

Cited by 27 publications

(6 citation statements)

References 90 publications

(189 reference statements)

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“…As suggested by previous scholars (Yousif et al, 1991;Minagawa et al, 2009;Ordonez et al, 2009;Waite et al, 2009;Kumar et al, 2010;Johnson et al, 2011;Liang et al, 2011;Dai et al, 2012;Li et al, 2014;Joseph et al, 2016), many physical properties of porous media will be strongly influenced by hydrates, which can be categorized as pore filling hydrates (PF hydrates), wall coating hydrates (WC hydrates), grain cementing hydrates (GC hydrates), and other types of hydrates (e.g., discrete nodules, lenses, or veins) (seen in Fig. 1).…”

Section: Introductionmentioning

confidence: 67%

“…Moreover, it necessitates a precise control of pressure and temperature to ensure the maintenance of constant thermodynamic and geomechanical conditions, which is usually costly expensive. In addition, the obtained permeability is only applicable to specific hydrate-bearing medium, which becomes a cumbersome limitation (Yousif et al, 1991;Minagawa et al, 2009;Ordonez et al, 2009;Kumar et al, 2010;Johnson et al, 2011;Liang et al, 2011;Li et al, 2014;Joseph et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

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Stress dependent gas-water relative permeability in gas hydrates: A theoretical model

Lei

Liao

Lin

et al. 2020

Adv. Geo-Energy Res.

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Research activities are currently being conducted to study multiphase flow in hydratebearing sediments (HBS). In this study, in view of the assumption that hydrates are evenly distributed in HBS with two major hydrate-growth patterns, i.e., pore filling hydrates (PF hydrates), wall coating hydrates (WC hydrates) and a combination of the two, a theoretical relative permeability model is proposed for gas-water flow through HBS. Besides, in this proposed model, the change in pore structure (e.g., pore radius) of HBS due to effective stress is taken into account. Then, model validation is performed by comparing the predicted results from the derived model with that from the existing model and test data. By setting the value of hydrate saturation to zero, our derived model can be reducible to the existing model, which demonstrates that the existing model is a special case of our model. The results reveal that, under the same saturation, relative permeability to water K rw (or gas K rg) in PF hydrates is smaller than that in WC hydrates. Moreover, the morphological characteristics of relative permeability curve (relative permeability versus gas saturation) for WC hydrate and PF hydrate are different.

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Section: Introductionmentioning

confidence: 67%

Section: Introductionmentioning

confidence: 99%

Stress dependent gas-water relative permeability in gas hydrates: A theoretical model

Lei

Liao

Lin

et al. 2020

Adv. Geo-Energy Res.

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“…Naturally existing hydrate-bearing sediments (HBS) are widely distributed in continental margins and permafrost [3]. It has been estimated that the total carbon amount stored in the hydrates is at the same order of magnitude as all fossil fuels combined [4]. Therefore, NGH is viewed as a potential energy resource in the future.…”

Section: Introductionmentioning

confidence: 99%

Effect of Hydrate on Gas/Water Relative Permeability of Hydrate-Bearing Sediments: Pore-Scale Microsimulation by the Lattice Boltzmann Method

Xin

Yang

et al. 2021

Geofluids

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As a clean energy source with ample reserves, natural gas hydrate is studied extensively. However, the existing hydrate production from hydrate deposits faces many challenges, especially the uncertain mechanism of complex multiphase seepage in the sediments. The relative permeability of hydrate-bearing sediments is key to evaluating gas and water production. To study such permeability, a set of pore-scale microsimulations were carried out using the Lattice Boltzmann Method. To account for the differences between hydrate saturation and hydrate pore habit, we performed a gas-water multiphase flow simulation that combines the fluids’ fundamental properties (density ratio, viscosity ratio, and wettability). Results show that the Lattice Boltzmann Method simulation is valid compared to the pore network simulation and analysis models. In gas and water multiphase flow systems, the viscous coupling effect permits water molecules to block gas flow severely due to viscosity differences. In hydrate-bearing sediments, as hydrate saturation increases, the water saturation S w between the continuous and discontinuous gas phase decreases from 0.45 to 0.30 while hydrate saturation increases from 0.2 to 0.6. Besides, the residual water and gas increased, and the capillary pressure increased. Moreover, the seepage of gas and water became more tedious, resulting in decreased relative permeability. Compared with different hydrate pore habits, pore-filling thins the pores, restricting the gas flow than the grain-coating. However, hydrate pore habit barely affects water relative permeability.

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“…As an alternative to experiments, some researchers rely on fitting empirical relative permeability models (Joseph et al, 2016) to pore network modeling results (Kang et al, 2016;Katagiri et al, 2017;Mahabadi & Jang, 2014;Mahabadi, Dai, et al, 2016, Mahabadi, Zheng et al, 2016Wang et al, 2015), which, although useful, is limited by the lack of mechanistic models to describe petrophysical properties in addition to the computational expense required in developing a new pore network model for each scenario. The empirical relative permeability models used in pore network modeling, particle-based 3-D packs (Katagiri et al, 2016(Katagiri et al, , 2017, or otherwise (Yoneda et al, 2018) essentially involve fitting relative permeability curve separately for each hydrate saturation, which gives different model parameters for each hydrate saturation.…”

Section: Introductionmentioning

confidence: 99%

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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State-of-the-Art of Gas Hydrates and Relative Permeability of Hydrate Bearing Sediments

Cited by 27 publications

References 90 publications

Stress dependent gas-water relative permeability in gas hydrates: A theoretical model

Stress dependent gas-water relative permeability in gas hydrates: A theoretical model

Effect of Hydrate on Gas/Water Relative Permeability of Hydrate-Bearing Sediments: Pore-Scale Microsimulation by the Lattice Boltzmann Method

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

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