Geomechanical properties are important for reservoir characterization and optimal stimulation design in the oil and gas industry. The conventional techniques, such as laboratory core analysis and downhole acoustic/wireline logging can be expensive and sometimes uncertain to process for unconventional reservoirs. In this study, a convenient and cost-effective technology is presented that uses routinely available drilling data to calculate the geomechanical properties without the need for downhole logging operations. A wellbore friction model is used to estimate the coefficient of friction and effective downhole weight on bit (DWOB) from the routinely collected drilling data. The inverted rate of penetration (ROP) models use the estimated downhole weight on bit and formation lithology constants to calculate the geomechanical properties throughout the horizontal reservoir formations such as confined compressive strength (CCS), unconfined compressive strength (UCS), Young’s modulus, permeability, porosity and Poisson’s ratio. In this article, the field case study is presented for a sample North American well applied to the lower Eagle Ford formation. The calculated geomechanical property log is also verified with tests performed on cores in reservoir rock formations.

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