This study demonstrates the complementary use two hydraulic fracturing models, ultra-fast and high-fidelity, to speed-up pressure history matching of field treatment data for a 2 well, 10 stage zipper sequence without compromising accuracy. Values of key parameters for field calibration are resolved using the ultra-fast model, by minimizing the error in ISIP for all wells and all stages, and transferred to the high-fidelity model, where a reduced number of stages may be analyzed, resulting in both models matching field observations of ISIP to within 10% without stage by stage calibration. While the standard practice has been to match a selected number of stages, the proliferation of multistage/multiwell stimulations require models to account for complex stress shadow interactions. This is accomplished with the ultra-fast model, while high-fidelity modeling confirms the validity of the parameters provided by the ultra-fast optimization on selected stages. The two models can thus be calibrated simultaneously, with the same amount of redundancy and the same range of variability of these controlling parameters, without the penalty of impractical computational time. In this work, simulating 10 in the high-fidelity simulator takes17 hours while the same simulation takes under 1 minute using the ultra-fast simulator. Without this scale of time savings, parametric optimization would be unrealistic. An additional benefit of the error minimization is the evaluation of fluid friction factors for the fluids used in the pumping schedule and the accurate prediction of pipe friction.
Hydraulic fracture modeling has become an integral part of development planning throughout unconventional plays around the world. Given the direct relationship between productive fracture surface area and well productivity described by Suarez-Rivera et al. 2016, methodologies to maximize propped, connected fracture surface area have become an essential part of the development planning toolkit. Numerous products are available to help guide operators and completions engineers toward the most effective stimulation designs and serve the function of maximizing propped, connected surface area in a given well. Some of these tools also allow for multi-well development scenarios that consider the time- and sequence-dependent nature of field operations. These tools have unique characteristics but in general require geo-mechanical and petrophysical inputs, most often derived from well logs.