Abstract
An experimental investigation of single Taylor bubbles rising in stagnant and downward flowing non-Newtonian fluids was carried out in an 80 ft long inclined pipe (4°, 15°, 30°, 45° from vertical) of 6 in. inner diameter. Water and four concentrations of bentonite–water mixtures were applied as the liquid phase, with Reynolds numbers in the range 118 < Re < 105,227 in countercurrent flow conditions. The velocity and length of Taylor bubbles were determined by differential pressure measurements. The experimental results indicate that for all fluids tested, the bubble velocity increases as the inclination angle increases, and decreases as liquid viscosity increases. The length of Taylor bubbles decreases as the downward flow liquid velocity and viscosity increase. The bubble velocity was found to be independent of the bubble length. A new drift velocity correlation that incorporates inclination angle and apparent viscosity was developed, which is applicable for non-Newtonian fluids with the Eötvös numbers (E0) ranging from 3212 to 3405 and apparent viscosity (μapp) ranging from 0.001 Pa∙s to 129 Pa∙s. The proposed correlation exhibits good performance for predicting drift velocity from both the present study (mean absolute relative difference is 0.0702) and a database of previous investigator’s results (mean absolute relative difference is 0.09614).
Highlights
Gas bubble entry into a wellbore during oil and gas drilling operations can occur under a variety of conditions
The experimental data collected from both static tests and countercurrent flow tests were processed to obtain the velocity and length of the Taylor bubble
The experimental data collected from both static tests and countercurrent flow 12 tests were processed to obtain the velocity and length of the Taylor bubble
Summary
Gas bubble entry into a wellbore during oil and gas drilling operations can occur under a variety of conditions Their removal is usually required before drilling can continue. When drilling through highly fractured and vugular carbonate reservoirs, wellbore fluid pressure is balanced with reservoir pressure This is because the highly productive fracture/vug network intersects the wellbore with width dimensions too large to be plugged by drilled cuttings or drilling mud filter cake. Such conditions make it relatively easy for gas bubbles to enter a well bore and migrate upward. Bingham plastic fluids of varying plastic viscosities, μ p , and yield points, τy , were tested to determine their impact on gas bubble migration rates under static and downward-moving (i.e., countercurrent) fluid conditions
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