IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v16y2023i22p7599-d1281194.html
   My bibliography  Save this article

Pore-Scale Modeling of Methane Hydrate Dissociation Using a Multiphase Micro-Continuum Framework

Author

Listed:
  • Zhiying Liu

    (Key Laboratory for Thermal Science and Power Engineering of the Ministry of Education, Department of Energy and Power Engineering, Tsinghua University, Beijing 100084, China)

  • Qianghui Xu

    (School of Mechanical Engineering, Beijing Institute of Technology, Beijing 100081, China)

  • Junyu Yang

    (Department of Mechanical Engineering, University College London, Torrington Place, London WC1E 7JE, UK)

  • Lin Shi

    (Key Laboratory for Thermal Science and Power Engineering of the Ministry of Education, Department of Energy and Power Engineering, Tsinghua University, Beijing 100084, China)

Abstract

The development of methane hydrate extraction technology remains constrained due to the limited physical understanding of hydrate dissociation dynamics. While recent breakthroughs in pore-scale visualization techniques offer intuitive insights into the dissociation process, obtaining a profound grasp of the underlying mechanisms necessitates more than mere experimental observations. In this research, we introduce a two-phase micro-continuum model that facilitates the numerical simulation of methane hydrate dissociation at both single- and multiscale levels. We employed this numerical model to simulate microfluidic experiments and determined the kinetic parameters of methane hydrate dissociation based on experimental data under various dissociation scenarios. The simulations, once calibrated, correspond closely to experimental results. By comprehensively comparing the simulated results with experimental data, the rate constant and the effective diffusion coefficient were reliably determined to be k d = 1.5 × 10 8 kmol 2 /(J·s·m 2 ) and D l = 0.8 × 10 −7 m 2 /s, respectively. Notably, the multiscale model not only matches the precision of the single-scale model but also presents considerable promise for streamlining the simulation of hydrate dissociation across multiscale porous media. Moreover, we contrast hydrate dissociation under isothermal versus adiabatic conditions, wherein the dissociation rate is significantly reduced under adiabatic conditions due to the shifted thermodynamic condition. This comparison highlights the disparities between microfluidic experiments and real-world extraction environments.

Suggested Citation

  • Zhiying Liu & Qianghui Xu & Junyu Yang & Lin Shi, 2023. "Pore-Scale Modeling of Methane Hydrate Dissociation Using a Multiphase Micro-Continuum Framework," Energies, MDPI, vol. 16(22), pages 1-25, November.
  • Handle: RePEc:gam:jeners:v:16:y:2023:i:22:p:7599-:d:1281194
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/16/22/7599/pdf
    Download Restriction: no

    File URL: https://www.mdpi.com/1996-1073/16/22/7599/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Yin, Zhenyuan & Moridis, George & Tan, Hoon Kiang & Linga, Praveen, 2018. "Numerical analysis of experimental studies of methane hydrate formation in a sandy porous medium," Applied Energy, Elsevier, vol. 220(C), pages 681-704.
    2. Yu, Minghao & Li, Weizhong & Jiang, Lanlan & Wang, Xin & Yang, Mingjun & Song, Yongchen, 2018. "Numerical study of gas production from methane hydrate deposits by depressurization at 274K," Applied Energy, Elsevier, vol. 227(C), pages 28-37.
    3. E. Dendy Sloan, 2003. "Fundamental principles and applications of natural gas hydrates," Nature, Nature, vol. 426(6964), pages 353-359, November.
    4. Yin, Zhenyuan & Moridis, George & Chong, Zheng Rong & Tan, Hoon Kiang & Linga, Praveen, 2018. "Numerical analysis of experimental studies of methane hydrate dissociation induced by depressurization in a sandy porous medium," Applied Energy, Elsevier, vol. 230(C), pages 444-459.
    Full references (including those not matched with items on IDEAS)

    Most related items

    These are the items that most often cite the same works as this one and are cited by the same works as this one.
    1. Olga Gaidukova & Sergei Misyura & Pavel Strizhak, 2022. "Key Areas of Gas Hydrates Study: Review," Energies, MDPI, vol. 15(5), pages 1-18, February.
    2. Shilong Shang & Lijuan Gu & Hailong Lu, 2021. "The Effects of the Length and Conductivity of Artificial Fracture on Gas Production from a Class 3 Hydrate Reservoir," Energies, MDPI, vol. 14(22), pages 1-13, November.
    3. Yin, Zhenyuan & Zhang, Shuyu & Koh, Shanice & Linga, Praveen, 2020. "Estimation of the thermal conductivity of a heterogeneous CH4-hydrate bearing sample based on particle swarm optimization," Applied Energy, Elsevier, vol. 271(C).
    4. Zhang, Panpan & Tian, Shouceng & Zhang, Yiqun & Li, Gensheng & Zhang, Wenhong & Khan, Waleed Ali & Ma, Luyao, 2021. "Numerical simulation of gas recovery from natural gas hydrate using multi-branch wells: A three-dimensional model," Energy, Elsevier, vol. 220(C).
    5. Wan, Qing-Cui & Si, Hu & Li, Gang & Feng, Jing-Chun & Li, Bo, 2020. "Heterogeneity properties of methane hydrate formation in a pilot-scale hydrate simulator," Applied Energy, Elsevier, vol. 261(C).
    6. Liao, Youqiang & Zheng, Junjie & Wang, Zhiyuan & Sun, Baojiang & Sun, Xiaohui & Linga, Praveen, 2022. "Modeling and characterizing the thermal and kinetic behavior of methane hydrate dissociation in sandy porous media," Applied Energy, Elsevier, vol. 312(C).
    7. Yin, Zhenyuan & Wan, Qing-Cui & Gao, Qiang & Linga, Praveen, 2020. "Effect of pressure drawdown rate on the fluid production behaviour from methane hydrate-bearing sediments," Applied Energy, Elsevier, vol. 271(C).
    8. Hao Peng & Xiaosen Li & Zhaoyang Chen & Yu Zhang & Changyu You, 2022. "Key Points and Current Studies on Seepage Theories of Marine Natural Gas Hydrate-Bearing Sediments: A Narrative Review," Energies, MDPI, vol. 15(14), pages 1-33, July.
    9. Dong, Lin & Wan, Yizhao & Li, Yanlong & Liao, Hualin & Liu, Changling & Wu, Nengyou & Leonenko, Yuri, 2022. "3D numerical simulation on drilling fluid invasion into natural gas hydrate reservoirs," Energy, Elsevier, vol. 241(C).
    10. Jianchun Xu & Ziwei Bu & Hangyu Li & Xiaopu Wang & Shuyang Liu, 2022. "Permeability Models of Hydrate-Bearing Sediments: A Comprehensive Review with Focus on Normalized Permeability," Energies, MDPI, vol. 15(13), pages 1-65, June.
    11. Tian, Hailong & Yu, Ceting & Xu, Tianfu & Liu, Changling & Jia, Wei & Li, Yuanping & Shang, Songhua, 2020. "Combining reactive transport modeling with geochemical observations to estimate the natural gas hydrate accumulation," Applied Energy, Elsevier, vol. 275(C).
    12. Song, Rui & Feng, Xiaoyu & Wang, Yao & Sun, Shuyu & Liu, Jianjun, 2021. "Dissociation and transport modeling of methane hydrate in core-scale sandy sediments: A comparative study," Energy, Elsevier, vol. 221(C).
    13. Wan, Qing-Cui & Yin, Zhenyuan & Gao, Qiang & Si, Hu & Li, Bo & Linga, Praveen, 2022. "Fluid production behavior from water-saturated hydrate-bearing sediments below the quadruple point of CH4 + H2O," Applied Energy, Elsevier, vol. 305(C).
    14. Yin, Zhenyuan & Huang, Li & Linga, Praveen, 2019. "Effect of wellbore design on the production behaviour of methane hydrate-bearing sediments induced by depressurization," Applied Energy, Elsevier, vol. 254(C).
    15. Wu, Zhaoran & Liu, Weiguo & Zheng, Jianan & Li, Yanghui, 2020. "Effect of methane hydrate dissociation and reformation on the permeability of clayey sediments," Applied Energy, Elsevier, vol. 261(C).
    16. Zhen Li & Erik Spangenberg & Judith M. Schicks & Thomas Kempka, 2022. "Numerical Simulation of Hydrate Formation in the LArge-Scale Reservoir Simulator (LARS)," Energies, MDPI, vol. 15(6), pages 1-27, March.
    17. Chong, Zheng Rong & Moh, Jia Wei Regine & Yin, Zhenyuan & Zhao, Jianzhong & Linga, Praveen, 2018. "Effect of vertical wellbore incorporation on energy recovery from aqueous rich hydrate sediments," Applied Energy, Elsevier, vol. 229(C), pages 637-647.
    18. Sun, Huiru & Chen, Bingbing & Zhao, Guojun & Zhao, Yuechao & Yang, Mingjun & Song, Yongchen, 2020. "The enhancement effect of water-gas two-phase flow on depressurization process: Important for gas hydrate production," Applied Energy, Elsevier, vol. 276(C).
    19. Ye, Hongyu & Wu, Xuezhen & Guo, Gaoqiang & Huang, Qichao & Chen, Jingyu & Li, Dayong, 2023. "Application of the enlarged wellbore diameter to gas production enhancement from natural gas hydrates by complex structure well in the shenhu sea area," Energy, Elsevier, vol. 264(C).
    20. Gu, Yuhang & Sun, Jiaxin & Qin, Fanfan & Ning, Fulong & Cao, Xinxin & Liu, Tianle & Qin, Shunbo & Zhang, Ling & Jiang, Guosheng, 2023. "Enhancing gas recovery from natural gas hydrate reservoirs in the eastern Nankai Trough: Deep depressurization and underburden sealing," Energy, Elsevier, vol. 262(PB).

    Corrections

    All material on this site has been provided by the respective publishers and authors. You can help correct errors and omissions. When requesting a correction, please mention this item's handle: RePEc:gam:jeners:v:16:y:2023:i:22:p:7599-:d:1281194. See general information about how to correct material in RePEc.

    If you have authored this item and are not yet registered with RePEc, we encourage you to do it here. This allows to link your profile to this item. It also allows you to accept potential citations to this item that we are uncertain about.

    If CitEc recognized a bibliographic reference but did not link an item in RePEc to it, you can help with this form .

    If you know of missing items citing this one, you can help us creating those links by adding the relevant references in the same way as above, for each refering item. If you are a registered author of this item, you may also want to check the "citations" tab in your RePEc Author Service profile, as there may be some citations waiting for confirmation.

    For technical questions regarding this item, or to correct its authors, title, abstract, bibliographic or download information, contact: MDPI Indexing Manager (email available below). General contact details of provider: https://www.mdpi.com .

    Please note that corrections may take a couple of weeks to filter through the various RePEc services.

    IDEAS is a RePEc service. RePEc uses bibliographic data supplied by the respective publishers.