Many geologic techniques have historically been developed to quantify geologic parameters inherent to the rock matrix. This was the case since in conventional reservoirs matrix storage and permeability are key hydrocarbon deliverability metrics that geoscientists and engineers fundamentally rely on. In unconventional shale reservoirs fracture permeability (both natural and induced) largely dictates well performance. This suggests that the modern geoscientists "tool kit" requires innovated techniques which begin to bridge the gap between various geoscience and engineering disciplines.
This study strives to investigate natural fracture effects on well deliverability, focusing on innovative multidisciplinary methods which have been developed to explore complex hydraulic and natural fracture interactions. Examples from the Eagle Ford in La Salle County Texas will illustrate how regional structural models, wellsite and produced gas data, core, FMI log data, buried array microseismic and completions flowback data can be used to predict the positive and negative productivity effects associated with various fault/fracture interactions. These effects will be quantified via correlation to various productivity metrics; both defined by produced and expected hydrocarbon volumes as well as outputs from rate transient analysis.