A unique data set was acquired in 2012–2013 during hydraulic fracturing operations in the Cana Field, Canadian County, Oklahoma. The Cana field produces from the Woodford shale using horizontal wells completed nine wells to a section. The data set was acquired during completion operations on the McCray 2–26H well and included the acquisition of distributed temperature sensing (DTS), distributed acoustic sensing (DAS), bottomhole pressure data, surface and downhole microseismic, tracer logs, and post-treatment production logs. Diagnostic fracture injection test DFIT data and other reservoir characterization information were also available from the subject and offset wells. The McCray 2–26H was completed with twelve hydraulic fracturing stages that had a variety of jet nozzle cluster spacings.
Using the available reservoir data, a hydraulic fracturing simulation model was built. The stress model was calibrated with DFIT data and other available log and core data. Once calibrated, standard pressure matches were developed for eleven of the twelve stages to determine what proppant concentration distributions looked like in the various fractures. After these standard pressure matches were developed, the DTS and DAS information acquired during the fracturing treatments was integrated into the fracture models. This information focused on percentage of proppant that was exiting each jet nozzle cluster at various times during the fracturing treatments. These percentages indicated that the exiting proppant was relatively equal between some jet nozzle clusters, while others showed significant variation in the amount any given cluster was taking at any given time. Some clusters remained relatively constant in the percentage exiting throughout the entire treatment (+/− 1% variation); while others showed large changes during the stages, up to 57%. The fracturing models in the eleven stages were then modified to incorporate these variations in proppant exiting any given cluster at various times during the treatments.
This paper discusses the differences observed in the modeling before and after incorporation of the DAS/DTS data. Overall integration of the other acquired data is also reviewed. This study required input from various technical disciplines, and provided valuable insight into detailed hydraulic fracture growth in a more mature unconventional reservoir. This insight has led to a better understanding of production and reserve recovery processes.