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Title: CO2 storage and potential fault instability in the St. Lawrence Lowlands sedimentary basin (Quebec, Canada): Insights from coupled reservoir-geomechanical modeling

Journal Article · · International Journal of Greenhouse Gas Control
 [1];  [2]; ORCiD logo [1]
  1. National Inst. of Scientific Research (INRS), Quebec City, QC (Canada)
  2. Lawrence Berkeley National Lab. (LBNL), Berkeley, CA (United States)
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In this paper, coupled reservoir-geomechanical (TOUGH-FLAC) modeling is applied for the first time to the St. Lawrence Lowlands region to evaluate the potential for shear failure along pre-existing high-angle normal faults, as well as the potential for tensile failure in the caprock units (Utica Shale and Lorraine Group). This activity is part of a general assessment of the potential for safe CO2 injection into a sandstone reservoir (the Covey Hill Formation) within an Early Paleozoic sedimentary basin. Field and subsurface data are used to estimate the sealing properties of two reservoir-bounding faults (Yamaska and Champlain faults). The spatial variations in fluid pressure, effective minimum horizontal stress, and shear strain are calculated for different injection rates, using a simplified 2D geological model of the Becancour area, located ~110 km southwest of Quebec City. The simulation results show that initial fault permeability affects the timing, localization, rate, and length of fault shear slip. Contrary to the conventional view, our results suggest that shear failure may start earlier for a permeable fault than for a sealing fault, depending on the site-specific geologic setting. In simulations of a permeable fault, shear slip is nucleated along a 60 m long fault segment in a thin and brittle caprock unit (Utica Shale) trapped below a thicker and more ductile caprock unit (Lorraine Group) – and then subsequently progresses up to the surface. In the case of a sealing fault, shear failure occurs later in time and is localized along a fault segment (300 m) below the caprock units. The presence of the inclined low-permeable Yamaska Fault close to the injection well causes asymmetric fluid-pressure buildup and lateral migration of the CO2 plume away from the fault, reducing the overall risk of CO2 leakage along faults. Finally, fluid-pressure-induced tensile fracturing occurs only under extremely high injection rates and is localized below the caprock units, which remain intact, preventing upward CO2 migration.

Research Organization:
National Inst. of Scientific Research (INRS), Quebec City, QC (Canada); Lawrence Berkeley National Laboratory (LBNL), Berkeley, CA (United States)
Sponsoring Organization:
USDOE Office of Fossil Energy (FE); Ministry of Sustainable Development, Environment and Parks of Quebec (Canada)
Grant/Contract Number:
AC02-05CH11231
OSTI ID:
1407230
Alternate ID(s):
OSTI ID: 1868613
Journal Information:
International Journal of Greenhouse Gas Control, Vol. 22; ISSN 1750-5836
Publisher:
ElsevierCopyright Statement
Country of Publication:
United States
Language:
English
Citation Metrics:
Cited by: 15 works
Citation information provided by
Web of Science

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Cited By (4)

Basement Fault Reactivation by Fluid Injection Into Sedimentary Reservoirs: Poroelastic Effects journal July 2019
Fault and natural fracture control on upward fluid migration: insights from a shale gas play in the St. Lawrence Platform, Canada journal September 2018
Dynamic modeling of injection-induced fault reactivation and ground motion and impact on surface structures and human perception journal January 2014
Modeling of induced seismicity and ground vibrations associated with geologic CO2 storage, and assessing their effects on surface structures and human perception text January 2014

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Related Subjects

58 GEOSCIENCES
coupled reservoir-geomechanical modeling
fault seal capacity
shear slip
tensile fracturing
CO2 storage
St. Lawrence Lowlands