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

Onoja, Michael U.; Shariatipour, Seyed M.

doi:10.1016/j.ijggc.2018.03.007

Cited by 19 publications

(18 citation statements)

References 62 publications

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“…Consequently, the exclusion of relative permeability heterogeneities during such modelling exercise could easily give the notion that reverse gradation in the transition zone has negligible effects on caprock pressurisation in comparison to the absence of a basal transition zone. This further accentuates the relevance of relative permeability functions in reservoir simulations as portrayed by Onoja and Shariatipour (2018) and Mori et al (2015). Over the 20-year scCO2 injection period, the modelling exercise indicates that the average pressure along the reference depth (i.e.…”

Section: Pressure Evolution In the Caprockmentioning

confidence: 79%

“…This would suggest that for confined reservoirs that show gradation in the sealing formation, higher overpressure within the limit of the fracture pressure in the transition zone will result in further compression of the fluid, resulting in the higher storage capacity of the porous media in comparison to open reservoirs. In numerical simulations, this assertion is mostly applicable for gradational changes that are duly accounted for by relative permeability functions in the reservoir model (Onoja and Shariatipour, 2018). To check the applicability of the pressure profile for closed systems confined at 6km boundary ( Fig.…”

Section: 3mentioning

confidence: 99%

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Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Onoja

Williams

Vosper

et al. 2019

International Journal of Greenhouse Gas Control

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Numerical models of geologic carbon sequestration (GCS) in saline aquifers use multiphase fluid flow-characteristic curves (relative permeability and capillary pressure) to represent the interactions of the non-wetting CO2 and the wetting brine. Relative permeability data for many sedimentary formations is very scarce, resulting in the utilisation of mathematical correlations to generate the fluid flow characteristics in these formations. The flow models are essential for the prediction of CO2 storage capacity and trapping mechanisms in the geological media. The observation of pressure dissipation across the storage and sealing formations is relevant for storage capacity and geomechanical analysis during CO2 injection. This paper evaluates the relevance of representing relative permeability variations in the sealing formation when modelling geological CO2 sequestration processes. Here we concentrate on gradational changes in the lower part of the caprock, particularly how they affect pressure evolution within the entire sealing formation when duly represented by relative permeability functions. The results demonstrate the importance of accounting for pore size variations in the mathematical model adopted to generate the characteristic curves for GCS analysis. Gradational changes at the base of the caprock influence the magnitude of pressure that propagates vertically into the caprock from the aquifer, especially at the critical zone (i.e. the region overlying the CO2 plume accumulating at the reservoir-seal interface). A higher degree of overpressure and CO2 storage capacity was observed at the base of caprocks that showed gradation. These results illustrate the need to obtain reliable relative permeability functions for GCS, beyond just permeability and porosity data. The study provides a formative principle for geomechanical simulations that study the possibility of pressure-induced caprock failure during CO2 sequestration.

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Section: Pressure Evolution In the Caprockmentioning

confidence: 79%

Section: 3mentioning

confidence: 99%

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Onoja

Williams

Vosper

et al. 2019

International Journal of Greenhouse Gas Control

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“…Nevertheless, the rock and fluid property dataset used in this study, with the exception of the saturation functions, were based broadly on Singh et al (2010). Relative permeability curves for the CO 2 /brine flow dynamics in sandstone, siltstone, mudstone, and claystone were based on the description of relative permeability functions in siliciclastic units by Onoja and Shariatipour (2018) using Van Genutchten's formulation (Figure 2). Residual brine saturations, S wr , of 0.3 and 0.605 were adopted for the sandstone and mudrocks respectively.…”

Section: Methodsmentioning

confidence: 99%

Predictive Modelling Of CO2 Storage In Aquifers: Integrating The Effects Of Boundary Conditions And Saturation Functions

Onoja¹,

Shariatipour²

2018

Proceedings

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In reservoir engineering, the predictive analyses of CO2 sequestration in subsurface formations commonly employ numerical models of subsurface formations. A significant number of work have utilised numerical modelling techniques to predict the impact of the reservoir's boundary conditions and interlayer communication on CO2 storage capacity in aquifers. To the best of our knowledge, no study on the impact of boundary conditions on CO2 storage efficiency has focused on the combined effect of this factor in the reservoir and saturation functions in the caprock. To this end, this study examined the effect of integrating both processes on pressure evolution in the caprock during the numerical simulation of CO2 injection into a deep saline aquifer. Utilising the Sleipner benchmark model, we also showed how varying saturation functions in the caprock can affect the storage efficiency in the reservoir formation.

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“…Once CO2 is injected into the depleted oil and gas reservoirs, it will begin moving beneath the caprock. However, it should be noted that the caprock itself will be affected by the presence of CO2-bearing fluids Mackay, 2014, 2016;Onoja and Shariatipour, 2018). Based on this, both the cement sections within the caprock and reservoirs are vulnerable to face the CO2 plume.…”

Section: Introductionmentioning

confidence: 99%

Durability of oilwell cement in CO2-rich environments

Bagheri¹,

Shariatipour²,

Ganjian

2019

Sustainable Construction Materials and Technologies (SCMT)

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The anthropogenic emissions of carbon dioxide (CO2) into the atmosphere is considered as one of the main reasons for global warming. The injection of CO2 into underground formations is an immediate to mid-term option to decrease the level of this gas in the atmosphere. Depleted oil and gas reservoirs are among the best candidates for the carbon capture and storage projects (CCS). The reason for this is based on the well-characterised structure of these type of underground formations through the different periods of their life. One of the most concerned problems associated with CCS projects is CO2 leakage through well cements. Oilwell cements exposed to CO2-bearing fluids undergo geomechanical and geochemical changes which may endanger their integrity. This paper aims at providing a framework to predict the lifespan of a cement exposed to CO2-bearing fluid using numerical modelling based on coupling geochemical and geomechanical processes. The main processes of the radial compaction and the radial cracking are investigated. It was shown that the radial cracking process leads to a definite lifespan of the cement matrix after being exposed to CO2-bearing fluids, while the radial compaction process can increase the durability of the cement matrix. Generally, this process becomes more effective with increasing the radial stress on the cement sheath from the surrounding rocks.

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

Cited by 19 publications

References 62 publications

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Effect of sedimentary heterogeneities in the sealing formation on predictive analysis of geological CO2 storage

Predictive Modelling Of CO2 Storage In Aquifers: Integrating The Effects Of Boundary Conditions And Saturation Functions

Durability of oilwell cement in CO2-rich environments

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