Thermo-poroelastic analysis of drilling fluid pressure and temperature on wellbore stresses in the Mansouri oilfield, SW Iran

Ensuring wellbore stability is essential for successful oilfield drilling operations, as instability can prolong drilling time and escalate costs, potentially resulting in halted operations and loss of wells. This study presents a comprehensive thermo-poroelastic analysis of wellbore stability, focusing on the impact of thermal effects and pore pressure dynamics in shale formations. Utilizing a coupled thermo-poroelastic model, the research investigates the influence of varying drilling fluid pressure and temperature on wellbore stresses in the Bangestan Reservoir in SW Iran. The analysis employs Hoek-Brown's law, continuity equation, Darcy's law, compatibility equation, and thermal relations, solved using the finite element method within a complex geological model. The findings reveal that horizontal wells are more stable than other configurations, with a pressure limit of 57.23 MPa required to maintain stability. Additionally, a 55–60° azimuth demonstrates the highest mud limit among horizontal wells, while a 20° contrast is observed between formation temperature and drilling fluid in the optimal azimuth. This research introduces innovative methodologies that integrate thermal and pore pressure effects, significantly enhancing the understanding of wellbore stability and contributing to safer and more efficient drilling operations. • Drilling fluid pressure and temperature are key parameters for determining wellbore stresses. • Thermo-poroelastic analysis provides a more realistic assessment of the wellbore's drilling conditions. • Finite element method can accurately predict wellbore stresses. • Application of numerical techniques can improve decision-making in drilling operations. • Enhanced safety and cost-effectiveness minimize wellbore instability risks.