During the drilling of shale formations, drilling fluids can intrude into the wellbore, raise the pore pressure, and lead to wellbore instability. Based on the thermodynamic theory, a new model was established to calculate pore pressure. The model considers the effects of solute diffusion and solution convection and conducts sensitivity analyses. The results show that the drilling fluid activity significantly affects the pore pressure distribution. The pore pressure under high drilling fluid activity will increase rapidly in the early stage. Low drilling fluid activity can effectively suppress the growth of pore pressure. And a low effective diffusion coefficient of solute and a high membrane efficiency also help to reduce pore pressure. Therefore, reducing drilling fluid activity should be conducted in priority in drilling fluid design. Lowering its solute effective diffusion coefficient and increasing its viscosity can also be considered as auxiliary methods.
Two-Dimensional Pore Pressure Distribution Model to Evaluate Effects of Shale Semipermeable Membrane Characteristics
Contributed by the Petroleum Division of ASME for publication in the Journal of Energy Resources Technology. Manuscript received May 6, 2018; final manuscript received June 18, 2019; published online July 17, 2019. Assoc. Editor: Fanhua Zeng.
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Wei, J., Cheng, Y., and Yan, C. (July 17, 2019). "Two-Dimensional Pore Pressure Distribution Model to Evaluate Effects of Shale Semipermeable Membrane Characteristics." ASME. J. Energy Resour. Technol. January 2020; 142(1): 012902. https://doi.org/10.1115/1.4044122
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