Characterisation of the Krechba CO2 storage site: Critical elements controlling injection performance

Ringrose, Philip; Roberts, David; Gibson-Poole, Catherine Mary; Bond, Clare E.; Wightman, Ruth; Taylor, Mark A.; Raikes, Sue; Iding, Martin; Østmo, S.

doi:10.1016/j.egypro.2011.02.428

Cited by 31 publications

(15 citation statements)

References 11 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…2) (15,18). Using the two surveys, the operator was able to identify time-lapse differences created by injection.…”

Section: Evidence Of Lower Caprock Pressurizationmentioning

confidence: 99%

“…Available data include well logs, leak-off and formation integrity tests, core measurements, 3D and time-lapse seismic, interferometric synthetic aperture radar (InSAR) monitoring of surface deformations, water quality monitoring of the shallow aquifer, and surface gas monitoring (1,14,18). Microseismic recording at the site is limited, however, and only comes from a single geophone string in a shallow well (KB-601).…”

Section: Significancementioning

confidence: 99%

See 1 more Smart Citation

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

White¹,

Chiaramonte²,

Ezzedine

et al. 2014

Proc. Natl. Acad. Sci. U.S.A.

150

View full text Add to dashboard Cite

Almost 4 million metric tons of CO 2 were injected at the In Salah CO 2 storage site between 2004 and 2011. Storage integrity at the site is provided by a 950-m-thick caprock that sits above the injection interval. This caprock consists of a number of low-permeability units that work together to limit vertical fluid migration. These are grouped into main caprock units, providing the primary seal, and lower caprock units, providing an additional buffer and some secondary storage capacity. Monitoring observations at the site indirectly suggest that pressure, and probably CO 2 , have migrated upward into the lower portion of the caprock. Although there are no indications that the overall storage integrity has been compromised, these observations raise interesting questions about the geomechanical behavior of the system. Several hypotheses have been put forward to explain the measured pressure, seismic, and surface deformation behavior. These include fault leakage, flow through preexisting fractures, and the possibility that injection pressures induced hydraulic fractures. This work evaluates these hypotheses in light of the available data. We suggest that the simplest and most likely explanation for the observations is that a portion of the lower caprock was hydrofractured, although interaction with preexisting fractures may have played a significant role. There are no indications, however, that the overall storage complex has been compromised, and several independent data sets demonstrate that CO 2 is contained in the confinement zone.carbon sequestration | geomechanics

show abstract

“…2) (15,18). Using the two surveys, the operator was able to identify time-lapse differences created by injection.…”

Section: Evidence Of Lower Caprock Pressurizationmentioning

confidence: 99%

Section: Significancementioning

confidence: 99%

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

White¹,

Chiaramonte²,

Ezzedine

et al. 2014

Proc. Natl. Acad. Sci. U.S.A.

150

View full text Add to dashboard Cite

show abstract

“…These minor faults may extend into immediate caprock horizon, but there are no faults mapped extending from the injection zone through the caprock and into the shallow potable water aquifer. The faults appear to have some effect on the fluid flow and the ground surface uplift pattern (Ringrose et al 2011, Morris et al 2011a. However, to date, the CO 2 injection operation at In Salah has not resulted in any felt seismic event and InSAR surface deformations do not indicate substantial strike-slip shear movements.…”

Section: Potential Fault Reactivation and Notable Seismic Eventsmentioning

confidence: 99%

“…As mentioned, the injection pressure is quite substantial (up to 10 MPa, corresponding to about 160% of initial hydrostatic pressure) and the injection zone (the 20 m thick sandstone layer) is intersected by many subvertical minor faults observed from 3D seismic surveys (Iding and Ringrose 2010;Ringrose et al 2009Ringrose et al , 2011. Moreover, InSAR data on ground surface deformation have such a good spatial and temporal resolution that it is possible to detect potential injection-induced fault responses (Mathieson et al 2011;Morris et al 2011a, b;Vasco et al 2010;Bissell et al 2011).…”

Section: Potential Fault Reactivation and Notable Seismic Eventsmentioning

confidence: 99%

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

2012

View full text Add to dashboard Cite

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-

show abstract

“…Another growing application of fracture characterization and modeling deals with the impact of faults and fractures on the safety of underground storage of CO 2 . These works involve natural analogs studies [2] or the characterization of reservoir sites [3,4]. They underline the importance of the characterization and modeling of faults and fractures.…”

Section: Introductionmentioning

confidence: 99%

Joint Inversion of Fracture Model Properties for CO₂Storage Monitoring or Oil Recovery History Matching

Verscheure

Fourno

Chilès

2012

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

View full text Add to dashboard Cite

Résumé -Inversion conjointe des propriétés d'un modèle de fractures pour le monitoring d'un stockage de CO 2 ou le calage d'un historique de production -Que ce soit pour la production de pétrole ou le stockage de CO 2 , le terme réservoir est utilisé régulièrement. Un réservoir désigne une structure géologique hétérogène en types de roches ou en termes de propriétés de perméabilité et de porosité. Dans le domaine pétrolier, de nombreux réservoirs présentent des fractures ou des failles. Les réservoirs fracturés occupent une part importante de la production de pétrole dans le monde (Moyen Orient, Golfe du Mexique, etc.). Malgré la présence de fractures, ces réservoirs n'en restent pas moins de bons réservoirs. Des études de réservoirs dédiés au stockage de CO 2 ont montré de plus la présence de fractures diffuses ou de failles ainsi qu'un fort impact de celles-ci dans le transfert du CO 2 . Un facteur clé de la connaissance des réservoirs fracturés est la compréhension de la géométrie et de la conductivité hydraulique du réseau formé par les fractures. Cette compréhension nécessite la construction d'un modèle de réservoir intégrant l'ensemble des connaissances conceptuelles et des données disponibles sur le terrain. Le présent article expose une méthodologie permettant d'effectuer un calage d'historique d'un modèle réservoir par la modification des propriétés et de la géométrie d'un réseau de failles sub-sismiques. Un modèle original de réseau de failles sub-sismiques est présenté. Il est fondé sur une caractérisation fractale de la géométrie du réseau des failles à partir des données sismiques ou des affleurements. Ce modèle peut être simulé en étendant l'organisation du réseau des failles sismiques à l'échelle inférieure des failles sub-sismiques. Le réseau de failles obtenu peut alors être déformé de façon à refléter le comportement hydrodynamique du réservoir. Cette propriété permet d'effectuer le calage à l'historique de production : les positions et les propriétés hydrauliques des failles incertaines sont modifiées par un algorithme d'optimisation, permettant de réduire l'écart avec les données dynamiques observées. La cohérence géologique du modèle de failles est préservée. La mise en oeuvre des différentes étapes de l'approche proposée est illustrée par une application sur un réservoir synthétique. Abstract

show abstract

Characterisation of the Krechba CO2 storage site: Critical elements controlling injection performance

Cited by 31 publications

References 11 publications

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

Joint Inversion of Fracture Model Properties for CO₂Storage Monitoring or Oil Recovery History Matching

Contact Info

Product

Resources

About

Characterisation of the Krechba CO2 storage site: Critical elements controlling injection performance

Cited by 31 publications

References 11 publications

Geomechanical behavior of the reservoir and caprock system at the In Salah CO 2 storage project

Geomechanical behavior of the reservoir and caprock system at the In Salah CO 2 storage project

The Geomechanics of CO2 Storage in Deep Sedimentary Formations

Joint Inversion of Fracture Model Properties for CO2Storage Monitoring or Oil Recovery History Matching

Contact Info

Product

Resources

About

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

Geomechanical behavior of the reservoir and caprock system at the In Salah CO ₂ storage project

Joint Inversion of Fracture Model Properties for CO₂Storage Monitoring or Oil Recovery History Matching