Numerical Simulation of Channel Fracturing Technology in Developing Shale Gas Reservoirs

Abstract

HiWay flow channel fracturing, as a paradigm shift in hydraulic fracturing, was introduced by Schlumberger in 2010. The difference between new and conventional technology is the scattered multi-layer proppants which can concentrate loose proppants into fibered pillars in order to provide broader flow pathways in fractures. Although numerous experimental and theoretical research have been conducted in the last decade, limitations still exist. In this study, we investigate the performance of the technique in improving shale gas productivity via integrating channel fracture models into the open-source framework, MATLAB Reservoir Simulation Toolbox (MRST). Firstly, a new mathematical model is derived to determine the permeability and conductivity of channel fracturing by the shape changes of pillars in fractures. Secondly, the verification and validation cases are conducted via comparing with a reference model and oilfield data, respectively. Thirdly, the sensitivity analysis studies the key factors that may influence production, including the length and distribution of natural fractures, and the concentration of proppants. The comprehensive analysis results show that the proppant concentration is an important parameter that can be optimized based on the properties and conductivity tendency tested in a lab. In the field case study, the simulation results are compared with shale gas production data from the well Heim 2H in Hawkville field. The simulator matches the field data successfully in a stabilized period where the production is not affected by the screen out and flowback. The performance of the simulation model is very encouraging in its ability to predict gas production.