Multifractured horizontal
wells have gained significant attention
within the petroleum industry for commercial development. Despite
considerable developments of transient pressure analysis or flow rate
behaviors for horizontal wells in naturally fractured reservoirs,
some significant problems are yet to be resolved, including high heterogeneity
of reservoirs, pressure sensitivity of hydraulic fractures, and non-Darcy
flow effect, which may occur during the production life. This paper
presents a more pragmatic mathematical model for multifractured horizontal
wells in naturally fractured reservoirs based on the fractal system,
the theory of permeability modulus, and the time-fractional calculus
correspondingly as an extension of the classic trilinear flow model.
This new model comprises three modules: high heterogeneity of the
reservoir based on the fractal system, the permeability modulus typically
showing the pressure sensitivity of hydraulic fractures, and the anomalous
diffusion describing non-Darcy flow turbulence. This investigation
evaluates a trilinear dual-permeability dual-porosity flow model,
with the dual-porosity model for the unstimulated outer reservoir
flow region, the dual-permeability model for the stimulated inner
reservoir flow region, and the permeability modulus for the flow region
of hydraulic fractures. The comprehensive sensitivity analysis conducted
indicates how the key parameters, such as fractal dimension, hydraulic
fracture permeability modulus and conductivity, interporosity flow
coefficient, storativity ratio, etc., affect the transient pressure
behaviors, along with their reasons for the change in behavior. Application
to a field case study further demonstrates the validity of the mathematical
model, and the results presented may play a guiding role in well test
interpretation.