Modelling of fracturing half-length and spacing in shale gas reservoirs

The growing energy demand coupled with depletion of regular hydrocarbon reserves have greatly increased the significance of shale gas reservoirs. This study examines the fracture half-length and spacing affects in shale gas-reservoirs interpreted through the pressure drop rates and the production rates. This work aims to comprehend the variables, such as Klingenberg effects, Knudsen diffusion, non-Darcy flow, and the dual porosity caused by a fractured system, that influence the flow-behaviour in reservoirs of shale gas. The most fitting mathematical model for shale gas reservoirs was chosen after careful consideration of the several suggested mathematical models. Additionally, to examine and model the ideal half-length and spacing of the shale gas reservoir, suitable parameters for the reservoir system and simulation model were developed. This section discusses how the matrix permeability and the natural fracture-networks affect the fracture parameters designs. The study revealed that the reservoir parameters have a significant influence on the fracture half-length designs as well as the fracture-spacing plans. Similarly, whilst both the matrix permeability and the natural-fracture permeability effect fracture-spacing, the fracture half-length is impartial to matrix-permeabilities.