Abstract
Geomechanical characterisation of a hydrocarbon reservoir has multifold implications throughout the lifecycle of an oil and gas field, starting from exploration through development to abandon stage. At each phase, geomechanics, its related challenges and complications are different, and thus the perspective of the solution. To provide a practical and reasonable answer, it is imperative to have a robust well based 1D geomechanical model in the first place. This work made an effort to construct a geomechanical model based on well log data, geological information, and drilling-related events in the Hugin Formation of the Volve field in the central part of the North Sea basin. The geomechanical model indicates a strike-slip fault regime (SHmax > Sv > Shmin) in the reservoir section. Vertical stress (Sv) gradient was estimated at 17 ppg (~ 77 MPa) in the reservoir section. Pore pressure profile shows variation along the stratigraphic sequence, and the maximum pressure gradient appeared was approximately 11–11.66 ppg (~ 30–34 MPa) in Skade Formation and 9.61 ppg (~ 33–36 MPa) in Hugin Formation. Within the reservoir intervals, uniaxial compressive strength ranges around 33–39 MPa, Young's modulus (E) at 15–18 GPa, Poisson's ratio (\(\nu\)) at 0.2–0.4 and internal friction at around 0.6 are observed. Based on previous references, the net maximum horizontal stress orientation appears to be approximately E–W. The study indicates mud weight used in Hugin Formation to drill is more than sufficient for wellbore stability. Mud weight estimation for various well trajectories was also analysed. The proposed base model for Hugin Formation of theta vest structure shall help plan future field development strategies and feasibility considerations for possible CO2 sequestration.
Article highlights
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An investigation has been performed to understand the geomechanical properties and optimum orientation of drilling in the Hugin Formation.
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Pore pressure data calibrated with direct pressure measurement, and the gradient shows higher than hydrostatic pressure, ~9.61 ppg.
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The stress state indicates a strong strike-slip fault regime within the Hugin Formation.
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Rock mechanical properties were calibrated with available core test data, and UCS values range from 31–41 MPa.
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Acknowledgements
The authors would like to express their sincere gratitude to the Baker Hughes geomechanics team for their suggestions during this work.
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Saha, S., Vishal, V., Mahanta, B. et al. Geomechanical model construction to resolve field stress profile and reservoir rock properties of Jurassic Hugin Formation, Volve field, North Sea. Geomech. Geophys. Geo-energ. Geo-resour. 8, 68 (2022). https://doi.org/10.1007/s40948-022-00359-5
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DOI: https://doi.org/10.1007/s40948-022-00359-5