Multistage
hydrofracturing of horizontal wells is one of the key
technologies for deep tight oil and gas resource exploitation. The
stable and parallel propagation of multiple fractures formed by multistage
perforation cluster fracturing is conducive to the formation of a
developed fracture network. However, in the actual process of rock
fracturing in deep tight reservoirs, owing to the influence of many
factors, such as fracturing sequence, perforation cluster space, reservoir
heterogeneity, and stress shadow effect, the three-dimensional (3D)
fracture network that propagates unsteadily of multiple fractures
is often formed. This has become an important problem limiting artificial
transformation and in optimizing fracture networks. In view of the
above difficulties, a 3D finite element–discrete element model
considering fluid–solid coupling and fracturing fluid leak-off
effect is proposed to simulate hydrofracturing, and an effective medium
model to describe heterogeneous reservoir rock mass is established.
Several typical fracturing sequences (sequential, alternate, simultaneous,
and two improved alternate scenarios), perforation cluster spaces
(100, 75, 50, and 25 m), and heterogeneous reservoir conditions were
analyzed. The spatial unstable propagation, stress field interference,
and evolution behavior of the pressure fracture network were simulated,
and the quantitative results of the dynamic propagation shape, fracture
propagation area, and spatial volume of the pressure fracture network
were obtained. The numerical results show that when the perforation
cluster space decreases, the stress shadow effect between hydraulic
fractures intensifies, and the 3D fracture exhibits unstable propagation
and spatial deflection. Compared with sequential and simultaneous
fracturing, all types of improved alternate fracturing can effectively
reduce the stress interference between fractures, fracture deflection,
and form the developed fracture network area. Compared with the homogeneous
reservoir model, the heterogeneity of the reservoir rock mass becomes
an important factor that limits the propagation of the fracture network.
These results can provide a basis for understanding the mechanisms
of stress-dependent unstable dynamic propagation of 3D multiple hydraulic
fractures of improved fracturing sequences in heterogeneous reservoirs.