Abstract The scope of this work is to compare multiple measurements of downhole fracture-initiation pressures in multiple carbonate and clastic reservoirs located in the Middle East and North America. The objective of characterizing formation breakdown across several porous and tight layers is to quantify the maximum gas and CO2 injection capacity on each reservoir for carbon storage or enhance oil recovery operations. This analysis also acquires pore pressure and fracture closure pressure measurements for calibrating the geomechanical in-situ stress model and far-field lateral strain boundary conditions. Several single-probe pressure drawdown tests and straddle packer microfrac injection provide accurate downhole measurements of reservoir pore pressure, fracture initiation, reopening and fracture closure pressures. These tests are achieved using a wireline or pipe-conveyed straddle packer logging tool capable to isolate 3 feet of openhole formation in a vertical pilot hole across multiple reservoirs zones. The fracture closure pressures are obtained from three decline methods during the pressure fall-off after fracture propagation injection cycle. The three methods are: (1) square-root of the shut-in time, (2) G-Function pressure derivative, and (3) Log-Log pressure derivative. The far-field strain values are estimated by multi-variable regression from the microfrac test data and the core-calibrated static elastic properties of the formations where the stress tests are done. The reservoir pressure across these formations are between 0.40 to 0.5 psi/ft with a value repeatability of 0.05 psi among build-up tests and 0.05 psi/min of pressure stability. The formation breakdown pressures are obtained between 0.88 and 1.7 psi/ft over 5,500 psi above hydrostatic pressure. The in-situ fracture closure measurements provide the magnitude of the minimum horizontal stress 0.62 – 0.85 psi/ft which is used to back-calculate the lateral strain values (0.07 and 0.78 mStrain) as far-field boundary condition for subsequent geomechanical modeling. These measurements provide critical subsurface information to accurately predict wellbore stability, hydraulic fracture containment and CO2 injection capacity for safe storage or effective enhance oil recovery within these reservoirs. This in-situ stress wellbore data represents the first of its kind on the CCUS fields allowing petroleum and reservoir engineers to optimize the subsurface CO2 injection plans for efficient field development.
Franquet et al. (Tue,) studied this question.