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Hydraulic fracturing, a production enhancement technique, is widely used in the development of unconventional oil and gas reservoirs. The formation of a complex network of hydraulic fractures that connect with natural fractures is crucial for hydraulic fracturing in unconventional reservoirs. However, the current understanding of vertical fracture propagation behavior under the influence of variations in the mechanical properties of interbedded rock is insufficient to meet the requirements for simulations of unconventional reservoirs under complex geological conditions. In this study, a three-dimensional discrete grid method was employed to establish a model of three-dimensional fracture propagation. Numerical simulations were conducted to investigate the vertical growth of fractures while considering the influence of bedding planes. The effects of formation factors (stress, Young's modulus) and bedding planes (cohesion, density) on the height growth of hydraulic fractures were explored. The results indicated that the interbedded stress contrast, Young's modulus contrast, and bedding planes collectively controlled the height growth of hydraulic fractures. The height of hydraulic fractures decreased with increasing minimum horizontal principal stress of adjacent layers. When the minimum horizontal principal stress of adjacent layers exceeded the vertical stress, hydraulic fractures gradually deflected into the horizontal plane. Adjacent layers with large values of Young's modulus promoted the height growth of hydraulic fractures, while adjacent layers with small values of Young's modulus inhibited the height growth of hydraulic fractures. The presence of bedding planes further suppressed height growth, and the degree of suppression was related to the cohesion and density of the bedding planes. Weaker cohesion and higher density resulted in greater suppression. The results of this study provide a reference for the design and optimization of hydraulic fracturing treatments in unconventional oil and gas reservoirs. [ABSTRACT FROM AUTHOR]

Temporarily plugging staged fracturing (TPSF) can effectively increase the complexity of fracture network in naturally fractured reservoirs. In different geological and engineering conditions, how to evaluate the stress interference of multiple fractures and interaction of natural fractures should be investigated further. To realize the temporarily plugging, new perforation elements were developed, and modified pore pressure cohesive zone (PPCZ) model was combined to simulate the interaction between hydraulic fractures and natural fractures. All simulated results are validated by comparing with analytical model. Results show that lateral fractures can really break through the suppression from previous fractures and enhance the complexity of fracture network when using TPSF. Then, case studies are presented to investigate the influence of cluster spacing, horizontal stress difference and number of perforation clusters. The results reveal that, when increasing the cluster spacing, fractures propagate uniformly and influence less; when the spacing reaches at a certain degree (40 m), the complexity of fracture network will not change. Higher stress difference results in simpler fracture network, which owns a straighter propagation trajectory. Further, more perforation clusters lead to stronger interference among multiple fractures, and more divergence and coalescence will take place. [ABSTRACT FROM AUTHOR]