The rapid integration of artificial intelligence into oil and gas exploration and development offers transformative opportunities within the context of the global energy transition. This article highlights the key advancements and challenges in artificial intelligence applications. Machine learning algorithms enable data-driven shale sweet spot prediction, overcoming the limitations of traditional methods by capturing complex controlling factors. Intelligent core image analysis, leveraging computer vision and foundation models, enables automatic mineral identification, pore analysis, and rock structure characterization, thereby providing a comprehensive framework for microscopic reservoir appraisal. Physics-informed neural networks address the limitations of purely data-driven reservoir simulation by embedding governing seepage equations into their loss functions, thereby ensuring physical consistency and improved generalization. Multimodal architectures significantly enhance unconventional shale gas production prediction by integrating geological heterogeneity with dynamic production behavior, leading to more accurate and stable forecasts. Collectively, these AI-driven approaches underscore the importance of combining domain expertise, multi-source data, and physics-aware modeling to achieve efficient and intelligent oil and gas development.

Temporary plugging and diverting fracturing technology is of utmost importance in stimulating fractured reservoirs. However, studies investigating the mechanisms of new fracture initiation and propagation during far-field temporary plugging and diverting fracturing have been scarce, and the optimal technique parameters are still unknown. To address this issue, a two-dimensional fracturing model is developed via the finite element method in this work, which simulates the temporary plugging effect using the equivalent viscosity temporary blockage method and the unrestrained growth of hydraulic fractures by globally embedding the cohesive element of zero-thickness. Then, some key parameters for far-field temporary plugging and diverting fracturing in fractured reservoirs are discussed and some interesting insights are given. Firstly, a lower-permeability plugging zone expedites the pressure increase within the fracture, thereby boosting the probability of achieving temporary plugging and diverting fracturing. The size of the plugging zone significantly impacts the pressure increase within the fracture. Secondly, the plugging position should be determined considering the density and arrangement of natural fractures in the layer, and the temporary plugging construction should be performed after maximizing the elongation of initial hydraulic fracture. Thirdly, an increase in fluid viscosity and injection displacement promotes the pressure rise inside the fracture. Nonetheless, the impact of injection displacement on temporary plugging and diverting fracturing surpasses that of fluid viscosity. Overall, the established model can inform the design of temporary plugging and diverting fracturing in fractured reservoirs.