Hydraulic Fracture Design Flaws- Proppant Selection

Abstract

Abstract Proppant selection has been discussed in previous works (Yang et al, 2012), as one of the most important elements in both the physical success of a hydraulic fracture and its economic optimization. This paper continues this in-depth discussion. The study presents the statistical usage of fracture technology in major locations in Texas. The geographic analysis is consistent and valuable: similar reservoirs in the same basin call for similar treatments. The research will particularly focus on the analysis of proper proppant selection. Texas completion and production data from the past several years, specifically on fracturing treatments in the Eagle Ford Shale and the Permian Basin, have been studied and summarized. The statistical analysis includes, but is not limited to: the fracture job size, proppant type, pay formations and the true vertical depth of the well. Important factors involved in fracture design are also represented: formation type, depth, reservoir permeability, closure stress, stress isotropy/anisotropy and post-treatment productivity. Studies show that natural sands are the appropriate proppants for reservoirs currently under exploration in the specified plays. However, while Premium Brown Sand and Premium White Sand are the recommended proppants, this study proves that by utilizing the Unified Fracture Design model, the Net Present Values of the treatments using Premium Brown Sand are superior to those using Premium White Sand. This is established not only because of the shallower depths (and therefore less crushing) but also because Premium Brown Sand creates similar EUR at a substantially lower completion cost. With the theory guidance of the Unified Fracture Design and extensive completion and production data analysis, this study can considerably help the oil and gas industry to effectively implement hydraulic fracturing designs.