Assessment of carbon dioxide plume behaviour within the storage reservoir and the lower caprock around the KB-502 injection well at In Salah

Shi, Ji‐Quan; Sınayuç, Çağlar; Durucan, Şevket; Korre, Anna

doi:10.1016/j.ijggc.2012.01.002

Cited by 73 publications

(58 citation statements)

References 25 publications

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“…The evidence in favor of fluid migration from the reservoir along faults is weak, but there are small faults present at the site that could serve as partial migration pathways (7).…”

Section: Discussionmentioning

confidence: 99%

“…Several hypotheses have been put forward by various groups to explain these observations. These include fault leakage, flow through preexisting fractures, or the possibility that injection pressures hydraulically fractured a portion of the lower seal (2)(3)(4)(5)(6)(7)(8)(9)(10)(11)(12)(13). In this work, we evaluate these hypotheses in light of the available data.…”

mentioning

confidence: 99%

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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

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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

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“…The evidence in favor of fluid migration from the reservoir along faults is weak, but there are small faults present at the site that could serve as partial migration pathways (7).…”

Section: Discussionmentioning

confidence: 99%

mentioning

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

“…Thanks to the PEST protocol (Doherty, 1994), the use of the inverse capabilities of iTOUGH2 can be extended to any numerical forward model; here, we apply for the first time the code iTOUGH2-PEST (Finsterle and Zhang, 2011) to a coupled fluid flow and geomechanics application. Ringrose, 2010;Wright, 2011;Gemmer et al, 2012;Shi et al, 2012;White et al, 2014). Although these analyses are extremely useful to set model properties, the transient evolution of uplift as well as injection rates and well pressures play a crucial role in developing a wellconstrained coupled fluid flow and geomechanical model.…”

Section: Introductionmentioning

confidence: 99%

Inverse modeling of ground surface uplift and pressure with iTOUGH-PEST and TOUGH-FLAC: The case of CO2 injection at In Salah, Algeria

Rinaldi

Rutqvist

Finsterle

et al. 2017

Computers & Geosciences

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Ground deformation, commonly observed in storage projects, carries useful information about processes occurring in the injection formation. The Krechba gas field at In Salah (Algeria) is one of the best-known sites for studying ground surface deformation during geological carbon storage. At this first industrial-scale on-shore CO 2 demonstration project, satellite-based grounddeformation monitoring data of high quality are available and used to study the large-scale hydrological and geomechanical response of the system to injection. In this work, we carry out

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“…Table 1 includes the hydrothermal properties of the fracture and the rock matrix. The capillary functions of the rock matrix fit the retention curve and relative permeability curves measurements performed on the reservoir rock of In Salah, which were presented by Shi et al (2012).…”

Section: Modeling Of In Salah Algeriamentioning

confidence: 90%

Long-term thermal effects on injectivity evolution during CO2 storage

Vilarrasa

Rinaldi

Rutqvist

2017

International Journal of Greenhouse Gas Control

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Carbon dioxide (CO 2 ) is likely to reach the bottom of injection wells at a colder temperature than that of the storage formation, causing cooling of the rock. This cooling, together with overpressure, tends to open up fractures, which may enhance injectivity. We investigate cooling effects on injectivity enhancement by modeling the In Salah CO 2 storage site and a theoretical, long-term injection case. We use stress-dependent permeability functions that predict an increase in permeability as the effective stress acting normal to fractures decreases. Normal effective stress can decrease either due to overpressure or cooling. We calibrate our In Salah model, which includes a fracture zone perpendicular to the well, obtaining a good fitting with the injection pressure measured at KB-502 and the rapid CO 2 breakthrough that occurred at the observation well KB-5 located 2 km away from the injection well. CO 2 preferentially advances through the fracture zone, which becomes two orders of magnitude more permeable than the rest of the reservoir. Nevertheless, the effect of cooling on the long-term injectivity enhancement is limited in pressure dominated storage sites, like at In Salah, because most of the permeability enhancement is due to overpressure. However, thermal effects enhance injectivity in cooling dominated storage sites, which may decrease the injection pressure by 20 %, saving a significant amount of compression energy all over the duration of storage projects. Overall, our simulation results show that cooling has the potential to enhance injectivity in fractured reservoirs.

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Assessment of carbon dioxide plume behaviour within the storage reservoir and the lower caprock around the KB-502 injection well at In Salah

Cited by 73 publications

References 25 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

Inverse modeling of ground surface uplift and pressure with iTOUGH-PEST and TOUGH-FLAC: The case of CO2 injection at In Salah, Algeria

Long-term thermal effects on injectivity evolution during CO2 storage

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Assessment of carbon dioxide plume behaviour within the storage reservoir and the lower caprock around the KB-502 injection well at In Salah

Cited by 73 publications

References 25 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

Inverse modeling of ground surface uplift and pressure with iTOUGH-PEST and TOUGH-FLAC: The case of CO2 injection at In Salah, Algeria

Long-term thermal effects on injectivity evolution during CO2 storage

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