Geomechanical model construction to resolve field stress profile and reservoir rock properties of Jurassic Hugin Formation, Volve field, North Sea

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 per...

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Published in:	Geomechanics and geophysics for geo-energy and geo-resources. Vol. 8; no. 2
Main Authors:	Saha, Sankhajit, Vishal, Vikram, Mahanta, Bankim, Pradhan, Sarada Prasad
Format:	Journal Article
Language:	English
Published:	Cham Springer International Publishing 01-04-2022 Springer Nature B.V
Subjects:	Carbon dioxide Carbon dioxide fixation Complications Compressive strength Drilling Energy Engineering Environmental Science and Engineering Feasibility studies Foundations Geoengineering Geomechanics Geophysics/Geodesy Geotechnical Engineering & Applied Earth Sciences Horizontal orientation Hydraulics Hydrostatic pressure Internal friction Jurassic Life cycle analysis Mechanical properties Modulus of elasticity Mud Oil and gas fields Oil exploration Oil reservoirs Original Article Poisson's ratio Pore pressure Pore water pressure Pressure gradients Pressure measurement Reservoirs Rock properties Rocks Slip Stability analysis Stratigraphy Stress Trajectory analysis Weight North Sea Wellbore stability Stress state North Sea Strike-slip fault 1D geomechanical model Carbon sequestration
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Summary:	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 (S Hmax > S v > S hmin ) 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 ( ν ) 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 CO 2 sequestration. Article highlights An investigation has been performed to understand the geomechanical properties and optimum orientation of drilling in the Hugin Formation. Pore pressure data calibrated with direct pressure measurement, and the gradient shows higher than hydrostatic pressure, ~9.61 ppg. The stress state indicates a strong strike-slip fault regime within the Hugin Formation. Rock mechanical properties were calibrated with available core test data, and UCS values range from 31–41 MPa.
ISSN:	2363-8419 2363-8427
DOI:	10.1007/s40948-022-00359-5