Storage of CO2 as hydrate beneath the ocean floor

Qanbari, Farhad; Pooladi‐Darvish, Mehran; Tabatabaie, S. Hamed; Gerami, Shahab

doi:10.1016/j.egypro.2011.02.340

Cited by 36 publications

(25 citation statements)

References 19 publications

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“…Consequently, storage of CO 2 in hydrate is a feasible method of CO 2 capture and sequestration (CCS). The method has attracted extensive research interests . Since CO 2 forms hydrate more easily than CH 4 , it can be used to develop the natural gas hydrate (NGH) by replacement method, which accomplishes CO 2 storage and CH 4 release at the same time .…”

Section: Introductionmentioning

confidence: 99%

Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

et al. 2017

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In this work, a calculation model of CO 2 solubility in equilibrium with hydrate was developed on the basis of the Patel-Teja equation of state and Chen-Guo hydrate model. The solubility of CO 2 in water and NaCl solution in equilibrium with hydrate were calculated respectively under the temperature window of 273.95 K to 282.55 K and the pressure window of 2.0 MPa to 8.0 MPa. The comparisons between the calculated and experimental values show that the average absolute deviation percentages (AADP) are 2.12 % for the CO 2 /H 2 O system and 2.31 % for the CO 2 / NaCl/H 2 O system, respectively. It demonstrates that the model proposed in this work could well predict the solubility of CO 2 in NaCl solution in equilibrium with hydrate.

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Section: Introductionmentioning

confidence: 99%

Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

et al. 2017

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“…The Hydrate Formation Zone (HFZ) is the thickness of seabed where thermodynamic conditions are within the CO 2 hydrate stability zone. Fate of the injected liquid CO 2 beneath the deep seabed sediments below the NBZ and the HFZ was studied by Qanbari et al [18,19]. The authors concluded that liquid CO 2 can be effectively trapped beneath NBZ and HFZ for considerably longer period of time because of dual trapping mechanisms of gravitational stability and hydrate formation.…”

Section: Introductionmentioning

confidence: 99%

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

Singh

Shekhawat

Das

et al. 2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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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.

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“…They also experimentally investigated hydrate morphologies and their effects on retarding CO 2 migration rate. Qanbari et al (2011) numerically modeled the storage of CO 2 in deep ocean sediments. The results of their studies showed that hydrate formation and gravitational stability of CO 2 can restrict upward flow of CO 2 toward the seabed.…”

Section: Introductionmentioning

confidence: 99%

CO2 disposal as hydrate in ocean sediments

Qanbari

Pooladi‐Darvish

Tabatabaie

et al. 2012

Journal of Natural Gas Science and Engineering

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Storage of CO2 as hydrate beneath the ocean floor

Cited by 36 publications

References 19 publications

Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

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

CO2 disposal as hydrate in ocean sediments

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Storage of CO2 as hydrate beneath the ocean floor

Cited by 36 publications

References 19 publications

Solubility of CO2 in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

Solubility of CO2 in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

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

CO2 disposal as hydrate in ocean sediments

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Product

Resources

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Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

Solubility of CO₂ in water and NaCl solution in equilibrium with hydrate. Part II: Model calculation

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