Invasion and Movement of Fluids in Shale Formations and Wellbore Stability

Abstract

Abstract The invasion and movement of drilling fluids through shale formations can significantly contribute to wellbore instability. By combining the experimental results with the microstructural studies of core samples, we will examine the invasion and movement of fluids in shale formations near wellbore, including the mechanisms, rates, affecting factors, and impact on shale stability. Pre-test core studies provided insight into rock composition, structure, fracture distribution, water activity, and pore-fluid composition. Pore-fluid transmission tests were conducted on preserved shale cores from four different formations, each with a different water activity measurement. Thin section analyses of post-test cores were conducted to evaluate shale-fluid interactions and the impact of fluid invasion and movement on shale stability. Test results show clear evidence of a reverse osmosis process out of the shale. The reverse osmosis increased when the difference between the water activity of the shale's pore fluid and the drilling fluid also increased. A water activity difference of >0.07, and the resulting pore-pressure drop (caused by the reverse osmosis), can subdue the impact of fluid invasion from drilling fluid to formation and led to a net decrease in downstream pressure. Reverse osmosis could cause downstream pressure below the initial value in a few minutes. A pore-pressure drop due to reverse osmosis may improve the stability of wellbore due to an increase in effective drilling fluid support. However, tests show that strong reverse osmosis could cause fracturing from over-dehydration of the shale. Tests also indicate that invasion along fractures increases pore pressure, even with a potential for strong reverse osmosis. Adjusting the water activity of drilling fluids to closely match that of the shale formations while minimizing fluid invasion along fractures and other fluid channels reduces wellbore instability.