EXPERIMENTAL ASSEESSMENT OF DRILLING FLUID AND WALL SLIPPAGE FOR WELLBORE DISPLACEMENT

Document Type

Conference Proceeding

Publication Date

1-1-2024

Abstract

In the ideal plug-flow mode Bingham-type drilling fluids display strong frontal displacement potential at a very low flowrate. The rate may be significantly increased with the fluid’s wall slippage so that maximum size of the fluid’s plug is maintained. Based on this concept the study qualifies the wall slippage effect as a rheological property to be used in fluid’s selection and evaluation for the purpose of wellbore displacement. The effect is analyzed using a conceptual model of fluid motion between two parallel plates to define the relationship between velocity of undisturbed fluid plug (slip velocity) and shearing rate for the maximum slippage effect. Applying the analysis to coaxial geometry gives practical formulas and a simplified procedure for fluid testing using either modified or conventional rotational viscometer. Also defined are new parameters of the fluid’s displacement performance: Maximum Slip Velocity and Plug Displacement Index. The study evaluates a variety of water-base drilling fluids such as high-molecular-weight polymer solutions, dispersed clay suspensions and suspensions flocculated with different electrolytes. The results show that the best-performing displacement fluid is a prehydrated bentonite suspension flocculated with sodium chloride.

Publication Source (Journal or Book title)

Proceedings of the International Conference on Offshore Mechanics and Arctic Engineering - OMAE

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