Geological sequestration of CO2 in a water-bearing reservoir in hydrate-forming conditions

• Published in: Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles
• Main Authors: SINGH, Raghvendra Pratap, Shekhawat, Karanpal Singh, Das, Malay K., Muralidhar, Krishnamurthy
• Other Authors: Indian Institute of Technology Kanpur (IIT Kanpur)
• Format: Article in Journal/Newspaper
• Language: English
• Published: HAL CCSD 2020
• Subjects: [PHYS]Physics [physics]; [SDE]Environmental Sciences; Methane hydrate
• Online Access: https://hal.archives-ouvertes.fr/hal-02907906; https://hal.archives-ouvertes.fr/hal-02907906/document; https://hal.archives-ouvertes.fr/hal-02907906/file/ogst190378.pdf; https://doi.org/10.2516/ogst/2020038

International audience Higher concentration of carbon dioxide in the atmospheric air is a major environmental challenge and requires immediate attention for quicker mitigation. In that respect, the novel idea of CO2 sequestration in geological settings is worth examining from a quantitative perspective. In the present study, numerical simulation of CO2 injection into a porous reservoir is performed. The selected reservoir presents suitable thermodynamic conditions for CO2 hydrate formation. Unsteady simulations are carried out in one space dimension under isothermal and non-isothermal frameworks. An additional simulation of CO2 injection in a depleted methane hydrate reservoir is also reported. In the present study, the response of the reservoir to storage of CO2 is analyzed with respect to four parameters – reservoir porosity, initial water saturation and reservoir temperature and injection pressure. Quantities of interest are hydrate formation patterns and the cumulative CO2 mass sequestration in the reservoir as a function of time. Numerical experiments show that the initial water saturation is an important parameter as it affects both CO2 gas migration and hydrate formation. Isothermal simulation yields results that are similar to the non-isothermal model, thus suggesting that the isothermal assumption may be adopted for future CO2 injection studies. Hydrate formation rate of CO2 near the injection well is found to be one order of magnitude higher than the interior but its magnitude is quite small when compared to water and gas saturations. Higher injection pressure leads to a continuous increase in injected mass of CO2 primarily due to increased gas density, though an increase in hydrate formation near the injection well is also observed. Lower reservoir temperature supports a higher amount of hydrate formation from the injected mass of CO2 and is clearly desirable.