CO2 dissolution and its impact on reservoir pressure behavior

Peters, E.; Egberts, P.J.P.; Loeve, D.; Hofstee, C.

doi:10.1016/j.ijggc.2015.10.016

Cited by 7 publications

(6 citation statements)

References 28 publications

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“…The injection of CO2, the development of the CO2 plume and the dissolution of CO2 into brine has been investigated in many studies (e.g. Ghanbari et al, 2006;Heinemann et al, 2012;Peters et al, 2015). Figure 6 shows that when injected into the hydrostatic model, the CO2 remains in the top of the anticline with a nearly horizontal FWL.…”

Section: Resultsmentioning

confidence: 99%

Hydrodynamics in subsurface CO 2 storage: Tilted contacts and increased storage security

Heinemann

Stewart

Wilkinson

et al. 2016

International Journal of Greenhouse Gas Control

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Hydrodynamic aquifers with horizontal variations in overpressure and brine flow have been reported from sedimentary basins worldwide. In a hydrodynamic aquifer pore-waters flow in the direction of overpressure reduction, whereas trapped hydrocarbons remain static. The main effect of this pressure disequilibrium in the aquifer is a tilt of the free water levels (FWL) in the direction of lower overpressure. Although the impact of hydrodynamics on the petroleum system is established in the oil industry and provides important information for exploration and field development, the interaction of CO2 storage and hydrodynamic flow has hardly been investigated. Supercritical CO2 has a density comparable with oil densities in known hydrodynamic systems in the North Sea. Hence, a tilted CO2-water FWL is expected and has to be taken into account during the planning of CO2 storage. Hydrodynamic spill points will replace structural spill points as a parameter in CO2 storage capacity calculations. Storage security is dependent on CO2 dissolution rates, among other factors. The more effectively CO2 dissolves into brine the more CO2 will be permanently stored in the subsurface. Numerical simulations show that CO2 storage in hydrodynamic aquifers enhances the dissolution of CO2 compared with a static regime. When CO2 dissolves into brine, the brine density increases and the CO2-saturated brine sinks to the bottom of the reservoir and is replaced by under-saturated brine. In a hydrodynamic system the brine saturated with CO2 will be removed more effectively from the CO2brine interface. Hence, CO2 comes in contact with more under-saturated brine and dissolves at a greater rate. The presence of hydrodynamic flow in a reservoir requires a high degree of understanding but research on oil reservoirs has proven that it is an uncertainty that can be adequately characterized. For long term CO2 storage operations hydrodynamic flow can even be an opportunity for more secure CO2 storage.

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Section: Resultsmentioning

confidence: 99%

Hydrodynamics in subsurface CO 2 storage: Tilted contacts and increased storage security

Heinemann

Stewart

Wilkinson

et al. 2016

International Journal of Greenhouse Gas Control

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“…This disparity was accounted for by the measure of capillary trapped CO2 within each strata. This is because in pore spaces, the incumbent aqueous phase will further dissolve immobilised CO2 ganglia which can account for the pressure drop (Peters et al, 2015). In other words, the degree of CO2 dissolution through residual trapping within a strata serves to counteract the impact of mobile CO2 saturation on the pore fluid pressure (Fig.…”

Section: Pressure Evolutionmentioning

confidence: 99%

The impact of gradational contact at the reservoir-seal interface on geological CO2 storage capacity and security

Onoja

Shariatipour

2018

International Journal of Greenhouse Gas Control

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“…Since adsorption of CO 2 depends on the total organic carbon and clay content, it is not commonly occurring in depleted reservoirs and saline aquifers . In solubility trapping, CO 2 dissolves in the subsurface fluids such as brine and hydrocarbons and hence increase the oleic phase and aqueous phase densities . In the mature oil reservoirs, generally the solubility of CO 2 in the oil phase is often higher than that of brine .…”

Section: Introductionmentioning

confidence: 99%

Investigation of an Indian Site with Mafic Rock for Carbon Sequestration

Saif,

Kiran,

Rajak

et al. 2024

ACS Omega

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The increasing extent of greenhouse gas emissions has necessitated the development of techniques for atmospheric carbon dioxide removal and storage. Various techniques are being explored for carbon storage including geological sequestration. The geological sequestration has various avenues such as depleted oil and gas reservoirs, coal-bed methane reservoirs, and mafic and ultramafic rocks. Different trapping mechanisms are in play in these subsurface storage systems. In these sequestration sites, the mafic and ultramafic rocks are best suited for long-term and effective sequestration as they comprise minerals, conducive for chemical alteration, forming stable carbonates. However, these sites often suffer from distinct disadvantages of injectivity issues due to their low permeability and porosity. This study investigates the potential of sequestration in the rock samples obtained from one such site located in India. The rock samples are first characterized using various techniques including X-ray fluorescence, X-ray diffraction, Raman spectroscopy, and field emission scanning electron microscopy (FESEM). The mineralogical characterization shows that the rock sample contains approximately 10% of diopside. The samples were put in the reactor chamber comprising CO 2 , which were then investigated using FESEM analysis. Additionally, a reservoir block simulation using commercial software was conducted with the representative minerals in the sample to evaluate the CO 2 sequestration potential. The simulation result suggests the formation of magnesite which corresponds to a major part of CO 2 mineral trapping. The reduced injectivity due to low porosity and permeability in this rock can be addressed using hydraulic fracturing. The geomechanical behavior of the rock sample for hydraulic fracturing is studied using the Brazilian disc test. The Monte Carlo-based uncertainty analysis was conducted using the tensile strength data of the sample. Results suggest that the most likely fracturing pressure is 2100 psi for this rock sample.

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CO2 dissolution and its impact on reservoir pressure behavior

Cited by 7 publications

References 28 publications

Hydrodynamics in subsurface CO 2 storage: Tilted contacts and increased storage security

Hydrodynamics in subsurface CO 2 storage: Tilted contacts and increased storage security

The impact of gradational contact at the reservoir-seal interface on geological CO2 storage capacity and security

Investigation of an Indian Site with Mafic Rock for Carbon Sequestration

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