RE:Technical QuestionsHey Johnson85, there is a couple things I was thinking it could be but the most common is plugging with sand where there is narrowing within the frack interval. You want the sand that’s injected to stay in the formation to support the fractures created but some always comes back with the water during flowback/cleanup and testing. It builds up along the upstream side of the restriction and eventually partially or fully obstructs the flow. Viking says wax but I have my doubts but I suppose is possible (we will eventually find out). Either way fixable and one of the normal challenges that can be encountered, thats why it wasn’t mentioned.
At a high level gel fracks are combination of chemicals including a gelling agent to form a viscous gel like solution that keeps the proppant (sand) evenly distributed in the solution quite well but because of a higher viscosity has trouble penetrating smaller fracture spaces. A slick water frac doesn't use a gelling agent but uses a friction reducing chemical (hence the name slick water) as well ad potentialy other chemicals which is much less viscous than gel fracs and can penetrate small fracture spaces better but the proppant (sand) isn’t as well distributed. For the Yayli well VLE tried a gel frac because they have used it before on some of their conventional wells I believe so they were comfortable with it so gave it a shot. It wasn’t the best frac for the formation and couldn’t unload the well when they flowed it back probably because the small gel frac wasn’t that successful and then the coiled tubing unit was too small to help it out. Hopefully the formation isn’t damaged and they can go back to it.