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Geochemical Assessment of Long-Term CO 2 Storage from Core- to Field-Scale Models

Author

Listed:
  • Paa Kwesi Ntaako Boison

    (Petroleum Engineering Department, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • William Ampomah

    (Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • Jason D. Simmons

    (Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • Dung Bui

    (Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • Najmudeen Sibaweihi

    (Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • Adewale Amosu

    (Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

  • Kwamena Opoku Duartey

    (Petroleum Engineering Department, New Mexico Institute of Mining and Technology, Socorro, NM 87801, USA)

Abstract

Numerical simulations enable us to couple multiphase flow and geochemical processes to evaluate how sequestration impacts brine chemistry and reservoir properties. This study investigates these impacts during CO 2 storage at the San Juan Basin CarbonSAFE (SJB) site. The hydrodynamic model was calibrated through history-matching, utilizing data from saltwater disposal wells to improve predictive accuracy. Core-scale simulations incorporating mineral interactions and equilibrium reactions validated the model against laboratory flow-through experiments. The calibrated geochemical model was subsequently upscaled into a field-scale 3D model of the SJB site to predict how mineral precipitation and dissolution affect reservoir properties. The results indicate that the majority of the injected CO 2 is trapped structurally, followed by residual trapping and dissolution trapping; mineral trapping was found to be negligible in this study. Although quartz and calcite precipitation occurred, the dissolution of feldspars, phyllosilicates, and clay minerals counteracted these effects, resulting in a minimal reduction in porosity—less than 0.1%. The concentration of the various ions in the brine is directly influenced by dissolution/precipitation trends. This study provides valuable insights into CO 2 sequestration’s effects on reservoir fluid dynamics, mineralogy, and rock properties in the San Juan Basin. It highlights the importance of reservoir simulation in assessing long-term CO 2 storage effectiveness, particularly focusing on geochemical interactions.

Suggested Citation

  • Paa Kwesi Ntaako Boison & William Ampomah & Jason D. Simmons & Dung Bui & Najmudeen Sibaweihi & Adewale Amosu & Kwamena Opoku Duartey, 2025. "Geochemical Assessment of Long-Term CO 2 Storage from Core- to Field-Scale Models," Energies, MDPI, vol. 18(15), pages 1-29, August.
    • Handle: RePEc:gam:jeners:v:18:y:2025:i:15:p:4089-:d:1715810
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    References listed on IDEAS

    as
    1. Kiseok Kim & Roman Y. Makhnenko, 2021. "Changes in rock matrix compressibility during deep CO2 storage," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 11(5), pages 954-973, October.
    2. Jiang, Xi, 2011. "A review of physical modelling and numerical simulation of long-term geological storage of CO2," Applied Energy, Elsevier, vol. 88(11), pages 3557-3566.
    3. Richard A. Esposito & Vello A. Kuuskraa & Charles G. Rossman & Michele M. Corser, 2019. "Reconsidering CCS in the US fossil‐fuel fired electricity industry under section 45Q tax credits," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 9(6), pages 1288-1301, December.
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