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

Abstract

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 gasmore » hydrate saturation and then it can then be used to predict relative permeability at any gas hydrate saturation. Here, 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.« less

Authors:
ORCiD logo [1]; ORCiD logo [2];  [3]; ORCiD logo [1]
  1. National Energy Technology Lab. (NETL), Morgantown, WV (United States)
  2. Arizona State Univ., Tempe, AZ (United States)
  3. National Energy Technology Lab. (NETL), Morgantown, WV (United States); LRST, Pittsburgh, PA (United States)
Publication Date:
Research Org.:
National Energy Technology Lab. (NETL), Morgantown, WV (United States)
Sponsoring Org.:
USDOE
OSTI Identifier:
1569749
Alternate Identifier(s):
OSTI ID: 1509753
Report Number(s):
NETL-PUB-22142
Journal ID: ISSN 0043-1397
Grant/Contract Number:  
89243318CFE000003
Resource Type:
Accepted Manuscript
Journal Name:
Water Resources Research
Additional Journal Information:
Journal Volume: 55; Journal Issue: 4; Journal ID: ISSN 0043-1397
Publisher:
American Geophysical Union (AGU)
Country of Publication:
United States
Language:
English
Subject:
58 GEOSCIENCES; gas hydrates; relative permeability; two‐phase flow; capillarity

Citation Formats

Singh, Harpreet, Mahabadi, Nariman, Myshakin, Evgeniy M., and Seol, Yongkoo. A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate-Bearing Porous Media With Capillarity. United States: N. p., 2019. Web. doi:10.1029/2018WR024278.
Singh, Harpreet, Mahabadi, Nariman, Myshakin, Evgeniy M., & Seol, Yongkoo. A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate-Bearing Porous Media With Capillarity. United States. doi:10.1029/2018WR024278.
Singh, Harpreet, Mahabadi, Nariman, Myshakin, Evgeniy M., and Seol, Yongkoo. Tue . "A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate-Bearing Porous Media With Capillarity". United States. doi:10.1029/2018WR024278.
@article{osti_1569749,
title = {A Mechanistic Model for Relative Permeability of Gas and Water Flow in Hydrate-Bearing Porous Media With Capillarity},
author = {Singh, Harpreet and Mahabadi, Nariman and Myshakin, Evgeniy M. and Seol, Yongkoo},
abstractNote = {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. Here, 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.},
doi = {10.1029/2018WR024278},
journal = {Water Resources Research},
number = 4,
volume = 55,
place = {United States},
year = {2019},
month = {4}
}

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