Containment of CO2 in CCS: Role of Caprocks and Faults

Kaldi, John; Daniel, Ric; Tenthorey, Eric; Michael, Karsten; Schacht, U.; Nicol, Andy; Underschultz, Jim; Backé, Guillaume

doi:10.1016/j.egypro.2013.06.458

Cited by 55 publications

(28 citation statements)

References 6 publications

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“…The behaviour of injected CO 2 is infl uenced by different parameters, such as geometry of reservoir and cap rocks, stratigraphic relations, reservoir heterogeneity, relative permeability, faults and fractures, pressure and temperature conditions, mineralogical composition, hydrodynamic conditions, reservoir fl uids chemistry, etc. (Root, 2007;Kaldi et al, 2013).…”

Section: Discussionmentioning

confidence: 99%

“…The most significant aspect of this mechanism relates to the seal potential of the cap rock, defi ned by its sealing capacity, geometry and cap rock integrity. Sealing capacity is defi ned by the height of a CO 2 column that can be held up by the seal rock to the moment when capillary forces in the cap rock pore space are defeated enabling migration due to changes in wettability and/or interfacial tension caused by CO 2 -caprock interaction (Daniel and Kaldi, 2009;Kaldi et al, 2013).…”

Section: Injection Zonementioning

confidence: 99%

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Depleted Hydrocarbon Reservoirs and Co2 Injection Wells –Co2 Leakage Assessment

Gaurina-Međimurec¹,

Mavar²

2017

MGPB

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Migration risk assessment of the injected CO 2 is one of the fi rst and indispensable steps in determining locations for the implementation of projects for carbon dioxide permanent disposal in depleted hydrocarbon reservoirs. Within the phase of potential storage characterization and assessment, it is necessary to conduct a quantitative risk assessment, based on dynamic reservoir models that predict the behaviour of the injected CO 2 , which requires good knowledge of the reservoir conditions. A preliminary risk assessment proposed in this paper can be used to identify risks of CO 2 leakage from the injection zone and through wells by quantifying hazard probability (likelihood) and severity, in order to establish a risk-mitigation plan and to engage prevention programs. Here, the proposed risk assessment for the injection well is based on a quantitative risk matrix. The proposed assessment for the injection zone is based on methodology used to determine a reservoir probability in exploration and development of oil and gas (Probability of Success, abbr. POS), and modifi ed by taking into account hazards that may lead to CO 2 leakage through the cap rock in the atmosphere or groundwater. Such an assessment can eliminate locations that do not meet the basic criteria in regard to short-term and long-term safety and the integrity of the site. Keywordsgeological storage of CO2, preliminary risk assessment, depleted hydrocarbon reservoirs, CO2 leakage, integrity

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Section: Discussionmentioning

confidence: 99%

Section: Injection Zonementioning

confidence: 99%

Depleted Hydrocarbon Reservoirs and Co2 Injection Wells –Co2 Leakage Assessment

Gaurina-Međimurec¹,

Mavar²

2017

MGPB

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“…Moreover, the effects of active faults on the process of leakage are an area where more research has to be performed; scientists generally suggest that the existence of seismogenic faults affects the permeability structure of the zone enhancing fluid transport [32]. In the process of hydraulic fracturing, the latter may lead to possible leakage of liquefied CO 2 [33] or flowback water, thus resulting in potential hazards. Moving towards a bigger picture, the major effects are the possible contamination of shallow groundwater layers by the migration of the toxic components of the flowback fluids as well as the leakage of methane, which acts as a greenhouse gas, into the atmosphere [34].…”

Section: Hazards In Hydraulic Fracturingmentioning

confidence: 99%

Recent Developments in Multiscale and Multiphase Modelling of the Hydraulic Fracturing Process

Sheng

Sousani

Ingham

et al. 2015

Mathematical Problems in Engineering

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Recently hydraulic fracturing of rocks has received much attention not only for its economic importance but also for its potential environmental impact. The hydraulically fracturing technique has been widely used in the oil (EOR) and gas (EGR) industries, especially in the USA, to extract more oil/gas through the deep rock formations. Also there have been increasing interests in utilising the hydraulic fracturing technique in geological storage of CO 2 in recent years. In all cases, the design and implementation of the hydraulic fracturing process play a central role, highlighting the significance of research and development of this technique. However, the uncertainty behind the fracking mechanism has triggered public debates regarding the possible effect of this technique on human health and the environment. This has presented new challenges in the study of the hydraulic fracturing process. This paper describes the hydraulic fracturing mechanism and provides an overview of past and recent developments of the research performed towards better understandings of the hydraulic fracturing and its potential impacts, with particular emphasis on the development of modelling techniques and their implementation on the hydraulic fracturing.

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“…Introduction The geo-sequestration of carbon dioxide (CO2) serves as one of the mitigation tools to tackle global warming and has been the subject of extensive research in recent times (IEAGHG, 2017). The main objectives of reservoir engineering studies of CO2 geosequestration include determining reservoir injectivity (André et al, 2014;Miri, 2015), calculating storage capacity (Bachu, 2015;Noy et al, 2012), estimating project costs (Deng et al, 2012;Middleton et al, 2012), evaluating the contribution of different trapping mechanisms (Kaldi et al, 2013;Peters et al, 2015), assessing the risks associated with CO2 sequestration (Birkholzer et al, 2015;Nicot et al, 2009), and assessing the financial consequences of CO2 leakage from the geologic repository (Anderson, 2017;Bielicki et al, 2014). These objectives are embodied in the basic metrics for geo-sequestration projects which include the extent of the CO2 plume migration, formation pressure response, and the measure of immobile and mobile CO2.…”

mentioning

confidence: 99%

“…Consequently, the major requirement for CO2 geo-sequestration is a suitable underground storage site subjacent to a sufficiently thick and laterally continuous caprock that will prohibit the upward leakage of in-situ fluid (Kaldi et al, 2013;Shukla et al, 2011). Among the geological options for CO2 sequestration, deep saline sedimentary formations offer the highest capacity for storage projects and siliciclastic rocks make up the largest percentage of these formations (IPCC, 2005).…”

mentioning

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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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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Containment of CO2 in CCS: Role of Caprocks and Faults

Cited by 55 publications

References 6 publications

Depleted Hydrocarbon Reservoirs and Co2 Injection Wells –Co2 Leakage Assessment

Depleted Hydrocarbon Reservoirs and Co2 Injection Wells –Co2 Leakage Assessment

Recent Developments in Multiscale and Multiphase Modelling of the Hydraulic Fracturing Process

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

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