Hidraulica

Hydraulic fracturing in shale-gas reservoirs has often resulted in complex-fracture-network growth, as evidenced by microseismic monitoring. The nature and degree of fracture complexity must beunderstood clearly to optimize stimulation design and completion strategy. Unfortunately, the existing single-planar-fracture models used in the industry today are not able to simulate complex fracturenetworks.
A new hydraulic-fracture model is developed to simulate complex-fracture-network propagation in a formation with pre-existing natural fractures. The model solves a system of equationsgoverning fracture deformation, height growth, fluid flow, and proppant transport in a complex fracture network with multiple propagating fracture tips. The interaction between a hydraulic fracture andpre-existing natural fractures is taken into account by using an analytical crossing model and is validated against experimental data. The model is able to predict whether a hydraulic-fracture front crossesor is arrested by a natural fracture it encounters, which leads to complexity. It also considers the mechanical interaction among the adjacent fractures (i.e., the "stress shadow" effect). Anefficient numerical scheme is used in the model so it can simulate the complex problem in a relatively short computation time to allow for day-to-day engineering design use.
Simulation results from the newcomplex-fracture model show that stress anisotropy, natural fractures, and interfacial friction play critical roles in creating fracture-network complexity. Decreasing stress anisotropy or interfacialfriction can change the induced-fracture geometry from a biwing fracture to a complex fracture network for the same initial natural fractures. The results presented illustrate the importance of rockfabrics and stresses on fracture complexity in unconventional reservoirs. These results have major implications for matching microseismic observations and improving fracture stimulation design.