Geological storage of CO2 in saline aquifers—A review of the experience from existing storage operations

Michael, Karsten; Golab, Alexandra; Shulakova, Valeriya; Ennis‐King, Jonathan; Allinson, Guy; Sharma, Sandeep; Aiken, Toby

doi:10.1016/j.ijggc.2009.12.011

Cited by 546 publications

(286 citation statements)

References 65 publications

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“…CO 2 geological storage is a promising means to mitigate CO 2 emission [1][2][3][4][5] and storage in deep saline aquifers appears to hold the largest potential capacity [4,[6][7][8]. The sequestration capacity, long-term CO 2 behavior in receptor formations, and the quantification of possible CO 2 leaks are the main concerns [2,4,9,10], and there remains a need to study the potential mobility of CO 2 dissolved in brines over a wide range of spatial and temporal scales [4,9,11], the CO 2 concentration distribution in saline aquifers, as well as the density distribution in geological media [8].…”

Section: Introductionmentioning

confidence: 99%

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

Lü

et al. 2013

Sci. China Chem.

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To investigate long-term CO 2 behavior in geological formations and quantification of possible CO 2 leaks, it is crucial to investigate the potential mobility of CO 2 dissolved in brines over a wide range of spatial and temporal scales and density distributions in geological media. In this work, the mass transfer of aqueous CO 2 in brines has been investigated by means of a chemical potential gradient model based on non-equilibrium thermodynamics in which the statistical associating fluid theory equation of state was used to calculate the fugacity coefficient of CO 2 in brine. The investigation shows that the interfacial concentration of aqueous CO 2 and the corresponding density both increase with increasing pressure and decreasing temperature; the effective diffusion coefficients decrease initially and then increase with increasing pressure; and the density of the CO 2 -disolved brines increases with decreasing CO 2 pressure in the CO 2 dissolution process. The aqueous CO 2 concentration profiles obtained by the chemical potential gradient model are considerably different from those obtained by the concentration gradient model, which shows the importance of considering non-ideality, especially when the pressure is high.

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Section: Introductionmentioning

confidence: 99%

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

Lü

et al. 2013

Sci. China Chem.

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“…Recent experience from CO 2 injection at a number of pilot projects, as well as a few ongoing commercial projects demonstrates that CO 2 geological storage in deep sedimentary formations is technologically feasible (Michael et al 2010). However, if CCS is implemented on the scale needed to make noticeable reductions in atmospheric CO 2 , a billion metric tons or more must be stored annually, with the largest injection operations in regions with the highest CO 2 emissions (Benson and Cole 2008).…”

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confidence: 99%

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

2012

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This paper provides a review of the geomechanics and modeling of geomechanics associated with geologic carbon storage (GCS), focusing on storage in deep sedimentary formations, in particular saline aquifers. The paper first introduces the concept of storage in deep sedimentary formations, the geomechanical processes and issues related with such an operation, and the relevant geomechanical modeling tools. This is followed by a more detailed review of geomechanical aspects, including reservoir stressstrain and microseismicity, well integrity, caprock sealing performance, and the potential for fault reactivation and notable (felt) seismic events. Geomechanical observations at current GCS field deploy-

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“…According to the International Energy Agency (IEA), to achieve such objective, CO 2 emissions should be reduced by more than half with respect to the current CO 2 emissions by 2050 [1]. Furthermore, the IEA considers that geologic carbon storage should contribute with one fifth of the total reduction, which represents storing around 8 Gt of CO 2 per year in deep geological formations by 2050. Currently, only a few Mt of CO 2 are stored each year, mainly in pilot test sites [2,3].…”

Section: Introductionmentioning

confidence: 99%

“…Furthermore, the IEA considers that geologic carbon storage should contribute with one fifth of the total reduction, which represents storing around 8 Gt of CO 2 per year in deep geological formations by 2050. Currently, only a few Mt of CO 2 are stored each year, mainly in pilot test sites [2,3]. Thus, a tremendous amount of work has to be done before geologic carbon storage can become a real solution.…”

Section: Introductionmentioning

confidence: 99%

Two-phase flow effects on the CO₂injection pressure evolution and implications for the caprock geomechanical stability

2016

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Abstract. Geologic carbon storage is considered to be one of the main solutions to significantly reduce CO2 emissions to the atmosphere to mitigate climate change. CO2 injection in deep geological formations entails a twophase flow, being CO2 the non-wetting phase. One of the main concerns of geologic carbon storage is whether the overpressure induced by CO2 injection may compromise the caprock integrity and faults stability. We numerically investigate the two-phase flow effects that govern the overpressure evolution generated by CO2 injection and how this overpressure affects the caprock geomechanical stability. We find that fluid pressure increases sharply at the beginning of injection because CO2 has to displace the brine that fills the pores around the injection well, which reduces the relative permeability. However, overpressure decreases subsequently because once CO2 fills the pores around the injection well, CO2 can flow easily due to its low viscosity and because the relative permeability to CO2 increases. Furthermore, the pressure drop that occurs in the capillary fringe due to two-phase flow interference decreases as the CO2 plume becomes larger. This overpressure evolution induced by CO2 injection, which remains practically constant with time after the initial peak, is very beneficial for maintaining caprock stability. Thus, the sealing capacity of the caprock will be maintained, preventing CO2 leakage to occur across the caprock.

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Geological storage of CO2 in saline aquifers—A review of the experience from existing storage operations

Cited by 546 publications

References 65 publications

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

Two-phase flow effects on the CO₂injection pressure evolution and implications for the caprock geomechanical stability

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Geological storage of CO2 in saline aquifers—A review of the experience from existing storage operations

Cited by 546 publications

References 65 publications

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

Modeling mass transfer of CO2 in brine at high pressures by chemical potential gradient

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

Two-phase flow effects on the CO2injection pressure evolution and implications for the caprock geomechanical stability

Contact Info

Product

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Two-phase flow effects on the CO₂injection pressure evolution and implications for the caprock geomechanical stability