Long-term thermal effects on injectivity evolution during CO 2 storage

Vilarrasa, Victor; Rinaldi, Antonio P.; Rutqvist, Jonny

doi:10.1016/j.ijggc.2017.07.019

Title: Long-term thermal effects on injectivity evolution during CO ₂ storage

Journal Article · Tue Aug 22 00:00:00 EDT 2017 · International Journal of Greenhouse Gas Control

DOI:https://doi.org/10.1016/j.ijggc.2017.07.019· OSTI ID:1379923

Vilarrasa, Victor ^[1]; Rinaldi, Antonio P. ^[2]; Rutqvist, Jonny ^[3]

Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Earth and Environmental Sciences Area; Spanish National Research Council (CSIC), Barcelona (Spain). Inst. of Environmental Assessment and Water Research; Associated Unit Hydrogeology Group (UPC-CSIC), Barcelona (Spain)
Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Earth and Environmental Sciences Area; Swiss Federal Inst. of Technology, Zurich (Switzerland). Swiss Seismological Service
Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States). Earth and Environmental Sciences Area

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. Here, 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. But, 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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Research Organization:: Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)

Sponsoring Organization:: USDOE Office of Fossil Energy (FE)

Grant/Contract Number:: AC02-05CH11231

OSTI ID:: 1379923

Journal Information:: International Journal of Greenhouse Gas Control, Vol. 64, Issue C; ISSN 1750-5836

Publisher:: ElsevierCopyright Statement

Country of Publication:: United States

Language:: English

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Cited by: 34 works

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