IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v15y2022i4p1407-d749916.html
   My bibliography  Save this article

3D Field-Scale Geomechanical Modeling of Potential CO 2 Storage Site Smeaheia, Offshore Norway

Author

Listed:
  • Md Jamilur Rahman

    (Department of Geosciences, University of Oslo (UiO), 0371 Oslo, Norway)

  • Manzar Fawad

    (Department of Geosciences, University of Oslo (UiO), 0371 Oslo, Norway)

  • Nazmul Haque Mondol

    (Department of Geosciences, University of Oslo (UiO), 0371 Oslo, Norway
    Norwegian Geotechnical Institute (NGI), 0806 Oslo, Norway)

Abstract

Injection-induced rock mechanical failure risks are critical in CO 2 sequestration, and thus there is a need to evaluate these occurrences to ensure safe and reliable subsurface storage. A stress–strain-based numerical simulation can reveal the potential mechanical risks of any CO 2 sites. This study investigated the hydromechanical effect on geomechanical failure due to injection-induced stress and pore pressure changes in the prospective CO 2 storage site Smeaheia, offshore Norway. An inverted-seismic-property-driven 3D field-scale geomechanical model was carried out in the Smeaheia area to evaluate the rock failure and deformation risks in various pressure-build-up scenarios. A one-way coupling between the before- and after-injection pressure scenarios of nine different models has been iterated using the finite element method. The effect of the sensitivity of total pore volume and pore compressibility on rock mechanical deformation is also evaluated. Although various models illustrated comparative variability on failure potential, no model predicted caprock failure or fracture based on the Mohr–Coulomb failure envelope. Moreover, the lateral mechanical failure variation among different locations indicated the possibility to identify a safer injection point with less chances of leakage. In addition, the pore volume and pore compressibility significantly influence the mechanical behavior of the reservoir and caprock rocks. Although this analysis could predict better injection locations based on geomechanical behavior, a fluid simulation model needs to be simulated for assessing lateral and vertical plume migration before making an injection decision.

Suggested Citation

  • Md Jamilur Rahman & Manzar Fawad & Nazmul Haque Mondol, 2022. "3D Field-Scale Geomechanical Modeling of Potential CO 2 Storage Site Smeaheia, Offshore Norway," Energies, MDPI, vol. 15(4), pages 1-21, February.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:4:p:1407-:d:749916
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/15/4/1407/pdf
    Download Restriction: no
    File URL: https://www.mdpi.com/1996-1073/15/4/1407/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Streit, Jürgen E & Hillis, Richard R, 2004. "Estimating fault stability and sustainable fluid pressures for underground storage of CO2 in porous rock," Energy, Elsevier, vol. 29(9), pages 1445-1456.
    Full references (including those not matched with items on IDEAS)

    Citations

    Citations are extracted by the CitEc Project, subscribe to its RSS feed for this item.
    as


    Cited by:

    1. Aysylu Askarova & Aliya Mukhametdinova & Strahinja Markovic & Galiya Khayrullina & Pavel Afanasev & Evgeny Popov & Elena Mukhina, 2023. "An Overview of Geological CO 2 Sequestration in Oil and Gas Reservoirs," Energies, MDPI, vol. 16(6), pages 1-34, March.

    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. Torben Treffeisen & Andreas Henk, 2020. "Faults as Volumetric Weak Zones in Reservoir-Scale Hydro-Mechanical Finite Element Models—A Comparison Based on Grid Geometry, Mesh Resolution and Fault Dip," Energies, MDPI, vol. 13(10), pages 1-27, May.
    2. Sean P. Rigby & Ali Alsayah & Richard Seely, 2022. "Impact of Exposure to Supercritical Carbon Dioxide on Reservoir Caprocks and Inter-Layers during Sequestration," Energies, MDPI, vol. 15(20), pages 1-34, October.
    3. Wang, Jinkai & Feng, Xiaoyong & Wanyan, Qiqi & Zhao, Kai & Wang, Ziji & Pei, Gen & Xie, Jun & Tian, Bo, 2022. "Hysteresis effect of three-phase fluids in the high-intensity injection–production process of sandstone underground gas storages," Energy, Elsevier, vol. 242(C).
    4. Víctor Vilarrasa & Jonny Rutqvist & Antonio Pio Rinaldi, 2015. "Thermal and capillary effects on the caprock mechanical stability at In Salah, Algeria," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 5(4), pages 449-461, August.
    5. Bing Bai & Xiaochun Li & Haiqing Wu & Yongsheng Wang & Mingze Liu, 2017. "A methodology for designing maximum allowable wellhead pressure for CO 2 injection: application to the Shenhua CCS demonstration project, China," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(1), pages 158-181, February.
    6. Javad Naseryan Moghadam & Nazmul Haque Mondol & Per Aagaard & Helge Hellevang, 2016. "Effective stress law for the permeability of clay‐bearing sandstones by the Modified Clay Shell model," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 6(6), pages 752-774, December.
    7. Mingze Liu & Bing Bai & Xiaochun Li & Shuai Gao & Shaobin Hu & Lei Wang & Haiqing Wu, 2016. "Assessing the applicability of unsaturated effective stress models to tensile fracturing of sandstone in CO 2 ‐water two‐phase fluids," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 6(5), pages 670-681, October.
    8. Sikandar Khan & Yehia Abel Khulief & Abdullatif Al-Shuhail, 2019. "Mitigating climate change via CO2 sequestration into Biyadh reservoir: geomechanical modeling and caprock integrity," Mitigation and Adaptation Strategies for Global Change, Springer, vol. 24(1), pages 23-52, January.
    9. Ba Nghiep Nguyen & Zhangshuan Hou & Diana H. Bacon & Mark D. White, 2017. "A multiscale hydro‐geochemical‐mechanical approach to analyze faulted CO 2 reservoirs," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(1), pages 106-127, February.

    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:15:y:2022:i:4:p:1407-:d:749916. 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.