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Multiscale Analysis of Mechanical an...

Hatami, Mohammad.

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Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs.

Record Type:	Electronic resources : Monograph/item
Title/Author:	Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs./
Author:	Hatami, Mohammad.
Published:	Ann Arbor : ProQuest Dissertations & Theses, : 2021,
Description:	128 p.
Notes:	Source: Dissertations Abstracts International, Volume: 83-01, Section: B.
Contained By:	Dissertations Abstracts International83-01B.
Subject:	Energy. -
Online resource:	https://pqdd.sinica.edu.tw/twdaoapp/servlet/advanced?query=28642394
ISBN:	9798516910494

Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs.
Hatami, Mohammad.

Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs. - Ann Arbor : ProQuest Dissertations & Theses, 2021 - 128 p.

Source: Dissertations Abstracts International, Volume: 83-01, Section: B.

Thesis (Ph.D.)--Ohio University, 2021.

This item must not be sold to any third party vendors.

This dissertation focuses on multiscale analysis in shale to improve understanding of mechanical and transport properties in shale gas reservoirs. Laboratory measurements of the effects of constant confining pressure (CCP), and constant effective stress (CES) on permeability were coupled with multiscale finite element simulations and the development of a comprehensive apparent permeability model to study the mechanical behavior of shale and transport mechanisms in shale.Predicting long-term production from gas shale reservoirs is a challenging task due to changes in effective stress and permeability during gas production. Unlike coal, the variation of sorbing gas permeability with pore pressure in shale does not always feature a biphasic trend under a constant confining pressure. The present contribution demonstrates that the biphasic dependence of permeability on pore pressure depends on a number of physical and geometrical factors, each with a distinct impact on gas permeability. This includes pore size, adsorption isotherm, and the variation of gas viscosity with pore pressure.In the first part, a single-capillary model was proposed for the apparent permeability of real gas in shale. Results indicated that the biphasic relation between apparent permeability and pore pressure is prevalent when the sorbing gas flows in sufficiently small pores. In addition, the effects of sorption isotherm and internal resistance of non-ideal gas to flow were shown to be non-trivial and could not be ignored.In the second part, experimental measurements were conducted on an intact Utica shale sample under constant confining pressure (CCP) and constant effective stress (CES) conditions to better understand how apparent permeability evolves over time. The average pore diameter of the sample is determined using nitrogen adsorption analysis. In low-permeability porous media, such as shale, gas slippage is more significant at low pore pressure, and using the Klinkenberg's theoretical model overestimates the apparent permeability. Therefore, a conceptual model based on the second-order slip boundary condition was developed to study the apparent permeability behavior with pore pressure. Results from the apparent permeability predicted by the proposed model reasonably matched against the experimental data, but deviated from the model using Klinkenberg's assumption at low pore pressures. These findings indicated that permeability under the CCP and CES conditions are dominated by gas slippage at low pore pressures, but as pore pressure increases, poroelastic effects become more significant. Moreover, it was found that the nonlinearity between the apparent permeability and pore pressure was more pronounced at small pores sizes and could be explained through more pronounced gas slippage in viscous flow.Finally, the thermomechanical behaviors of a solid-gas mixture were studied using the asymptotic expansion homogenization (AEH) method coupled with the finite element method to understand how porosity and pore density have effects on thermo-hydro-mechanical behaviors and transport properties of shale and how solid and gas interaction effect on permeability. It was found that increasing porosity results in a reduction of homogenized properties such as elastic stiffnesses, thermal expansion coefficients, and thermal conductivity, while the apparent permeability increases. In addition, under applied loading, micro stress distribution strongly influenced by pore clusters and pores sizes. It was shown that the apparent permeability at the microscale is two orders of magnitude smaller than the apparent permeability at the macroscale.

ISBN: 9798516910494Subjects--Topical Terms:

876794
Energy.
Subjects--Index Terms:

Apparent permeability

Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs.
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100 1 $a Hatami, Mohammad. $3 3561226
245 1 0 $a Multiscale Analysis of Mechanical and Transport Properties in Shale Gas Reservoirs.
260 1 $a Ann Arbor : $b ProQuest Dissertations & Theses, $c 2021
300 $a 128 p.
500 $a Source: Dissertations Abstracts International, Volume: 83-01, Section: B.
500 $a Advisor: Bayless, David.
502 $a Thesis (Ph.D.)--Ohio University, 2021.
506 $a This item must not be sold to any third party vendors.
520 $a This dissertation focuses on multiscale analysis in shale to improve understanding of mechanical and transport properties in shale gas reservoirs. Laboratory measurements of the effects of constant confining pressure (CCP), and constant effective stress (CES) on permeability were coupled with multiscale finite element simulations and the development of a comprehensive apparent permeability model to study the mechanical behavior of shale and transport mechanisms in shale.Predicting long-term production from gas shale reservoirs is a challenging task due to changes in effective stress and permeability during gas production. Unlike coal, the variation of sorbing gas permeability with pore pressure in shale does not always feature a biphasic trend under a constant confining pressure. The present contribution demonstrates that the biphasic dependence of permeability on pore pressure depends on a number of physical and geometrical factors, each with a distinct impact on gas permeability. This includes pore size, adsorption isotherm, and the variation of gas viscosity with pore pressure.In the first part, a single-capillary model was proposed for the apparent permeability of real gas in shale. Results indicated that the biphasic relation between apparent permeability and pore pressure is prevalent when the sorbing gas flows in sufficiently small pores. In addition, the effects of sorption isotherm and internal resistance of non-ideal gas to flow were shown to be non-trivial and could not be ignored.In the second part, experimental measurements were conducted on an intact Utica shale sample under constant confining pressure (CCP) and constant effective stress (CES) conditions to better understand how apparent permeability evolves over time. The average pore diameter of the sample is determined using nitrogen adsorption analysis. In low-permeability porous media, such as shale, gas slippage is more significant at low pore pressure, and using the Klinkenberg's theoretical model overestimates the apparent permeability. Therefore, a conceptual model based on the second-order slip boundary condition was developed to study the apparent permeability behavior with pore pressure. Results from the apparent permeability predicted by the proposed model reasonably matched against the experimental data, but deviated from the model using Klinkenberg's assumption at low pore pressures. These findings indicated that permeability under the CCP and CES conditions are dominated by gas slippage at low pore pressures, but as pore pressure increases, poroelastic effects become more significant. Moreover, it was found that the nonlinearity between the apparent permeability and pore pressure was more pronounced at small pores sizes and could be explained through more pronounced gas slippage in viscous flow.Finally, the thermomechanical behaviors of a solid-gas mixture were studied using the asymptotic expansion homogenization (AEH) method coupled with the finite element method to understand how porosity and pore density have effects on thermo-hydro-mechanical behaviors and transport properties of shale and how solid and gas interaction effect on permeability. It was found that increasing porosity results in a reduction of homogenized properties such as elastic stiffnesses, thermal expansion coefficients, and thermal conductivity, while the apparent permeability increases. In addition, under applied loading, micro stress distribution strongly influenced by pore clusters and pores sizes. It was shown that the apparent permeability at the microscale is two orders of magnitude smaller than the apparent permeability at the macroscale.
590 $a School code: 0167.
650 4 $a Energy. $3 876794
650 4 $a Geophysics. $3 535228
650 4 $a Petroleum engineering. $3 566616
650 4 $a Chemical engineering. $3 560457
650 4 $a Mechanical engineering. $3 649730
653 $a Apparent permeability
653 $a Gas slip
653 $a Mechanical properties
653 $a Multiscale analysis
653 $a Shale
653 $a Transport properties
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690 $a 0765
690 $a 0791
690 $a 0373
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710 2 $a Ohio University. $b Mechanical Engineering (Engineering and Technology). $3 3561227
773 0 $t Dissertations Abstracts International $g 83-01B.
790 $a 0167
791 $a Ph.D.
792 $a 2021
793 $a English
856 4 0 $u https://pqdd.sinica.edu.tw/twdaoapp/servlet/advanced?query=28642394