I’ve been diving into the nuances of proppant selection and how it affects fluid dynamics in various formations. In particular, I’m curious about how mesh size and density impact fracture conductivity in tighter geological settings. Has anyone found specific criteria or case studies that helped refine their approach?
Proppant size really does play a crucial role, especially in tighter formations. I remember using a finer mesh in a tough shale and it acted like trying to pour pancake batter through a straw — took some finesse! Have you looked into how specific case studies vary with the local geology, like those from the Bakken?
It’s all about balancing conductivity and cost, right? I’ve experienced better results using intermediate mesh sizes, especially when dealing with those tricky shale layers. @taylor_jensen47, have you looked into how well specific densities retain those fractures over time?