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Numerical Simulation of Gas Production from Gas Shale Reservoirs—Influence of Gas Sorption Hysteresis

Author

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  • Jamiu M. Ekundayo

    (Discipline of Petroleum Engineering, Western Australian School of Mines: Minerals, Energy and Chemical Engineering, Curtin University, 26 Dick Perry Avenue, Kensington, WA 6151, Australia)

  • Reza Rezaee

    (Discipline of Petroleum Engineering, Western Australian School of Mines: Minerals, Energy and Chemical Engineering, Curtin University, 26 Dick Perry Avenue, Kensington, WA 6151, Australia)

Abstract

The true contribution of gas desorption to shale gas production is often overshadowed by the use of adsorption isotherms for desorbed gas calculations on the assumption that both processes are identical under high pressure, high temperature conditions. In this study, three shale samples were used to study the adsorption and desorption isotherms of methane at a temperature of 80 °C, using volumetric method. The resulting isotherms were modeled using the Langmuir model, following the conversion of measured excess amounts to absolute values. All three samples exhibited significant hysteresis between the sorption processes and the desorption isotherms gave lower Langmuir parameters than the corresponding adsorption isotherms. Langmuir volume showed positive correlation with total organic carbon (TOC) content for both sorption processes. A compositional three-dimensional (3D), dual-porosity model was then developed in GEM ® (a product of the Computer Modelling Group (CMG) Ltd., Calgary, AB, Canada) to test the effect of the observed hysteresis on shale gas production. For each sample, a base scenario, corresponding to a “no-sorption” case was compared against two other cases; one with adsorption Langmuir parameters (adsorption case) and the other with desorption Langmuir parameters (desorption case). The simulation results showed that while gas production can be significantly under-predicted if gas sorption is not considered, the use of adsorption isotherms in lieu of desorption can lead to over-prediction of gas production performances.

Suggested Citation

  • Jamiu M. Ekundayo & Reza Rezaee, 2019. "Numerical Simulation of Gas Production from Gas Shale Reservoirs—Influence of Gas Sorption Hysteresis," Energies, MDPI, vol. 12(18), pages 1-12, September.
    • Handle: RePEc:gam:jeners:v:12:y:2019:i:18:p:3405-:d:263852
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    References listed on IDEAS

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    1. Jamiu M. Ekundayo & Reza Rezaee, 2019. "Volumetric Measurements of Methane-Coal Adsorption and Desorption Isotherms—Effects of Equations of State and Implication for Initial Gas Reserves," Energies, MDPI, vol. 12(10), pages 1-13, May.
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    Cited by:

    1. Xiaoqi Wang & Yanming Zhu & Yang Wang, 2020. "Fractal Characteristics of Micro- and Mesopores in the Longmaxi Shale," Energies, MDPI, vol. 13(6), pages 1-21, March.
    2. Reza Rezaee, 2022. "Editorial on Special Issues of Development of Unconventional Reservoirs," Energies, MDPI, vol. 15(7), pages 1-9, April.
    3. Yang, Xue & Chen, Zeqin & Liu, Xiaoqiang & Xue, Zhiyu & Yue, Fen & Wen, Junjie & Li, Meijun & Xue, Ying, 2022. "Correction of gas adsorption capacity in quartz nanoslit and its application in recovering shale gas resources by CO2 injection: A molecular simulation," Energy, Elsevier, vol. 240(C).

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    1. Reza Rezaee, 2022. "Editorial on Special Issues of Development of Unconventional Reservoirs," Energies, MDPI, vol. 15(7), pages 1-9, April.

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