Shale gas reservoirs, as representative reservoirs in the Sichuan Basin, have attracted widespread attention regarding development. Using gas reservoir numerical simulation to assist development has greatly improved the work efficiency of workers. However, traditional gas reservoir numerical simulation is widely criticized for its inability to effectively integrate with geological and engineering factors. In this study, we proposed a geological engineering integration method that considers pre-fracturing parameters. We further applied it to a typical well (N03) in a certain block of the Sichuan Basin. The reliability of the method was determined through historical fitting. Based on the N03 geological model, the optimization range of fracturing construction parameters in adjacent areas was determined with the goal of maximizing EUR. Recommended values for widely distributed construction parameter combinations of Class II reservoirs were provided through orthogonal analysis. The influence order of fracturing construction parameters is (1) sand addition strength, (2) cluster spacing, (3) construction displacement, (4) fracture fluid strength, and (5) horizontal segment length. Finally, we compared the simulated data with the actual case. The results showed that an integrated numerical simulation method including geological and engineering factors can comprehensively and accurately assist in reservoir development.

An integrated dynamic analysis and prediction method for shale gas reservoirs based on wellbore coupling has been developed, focusing on optimizing well production. This method integrates a three-dimensional geological model, a mechanical model, simulations of fracture propagation, and a numerical simulation in a gas reservoir to establish a continuous-flow model that links the gas reservoir, fractures, and wellbore after hydraulic fracturing. It enables comprehensive integrated production dynamic analysis and predictions. The process begins by trajectory modeling and attribute assignment. Subsequently, based on the regional tectonic map, contour lines are drawn, regional tectonic surfaces are established, segmentation and clustering are performed, and appropriate fracturing fluids and proppants are selected to simulate fracture network expansion. Finally, the integrated dynamic simulation model of the gas reservoir and wellbore is constructed using the Petrel RE module, considering the combined effects of wellbore flow and reservoir seepage. The model was developed from a single well and through three-dimensional geological modeling, the simulation of fracture propagation in hydraulic fracturing, and a numerical simulation. An integrated dynamic licensing and prediction methodology was established for a shale gas integration model with wellbore-gas reservoir coupling. Additionally, this study analyzes and establishes the optimal pressurization timing and regime for the pressurizer to enhance gas well production. The model was successfully applied for historical matching and dynamic predictions in a block in the southern Sichuan region, producing results closely aligned with the actual data, thus providing a robust tool for predicting the future production profiles of shale gas wells.

This study develops a particle-fiber-powder composite temporary plugging system and systematically investigates the dynamic plugging behavior of single-component, binary, and ternary formulations to elucidate the mechanisms governing plug formation and optimize material composition for diversion fracturing applications. Conventional temporary plugging materials often exhibit inadequate plug formation, limited pressure-bearing capacity, and poor plugging stability, compromising stimulation effectiveness in heterogeneous reservoirs. Experimental results show that neither the particle-only nor the particle-powder system can establish a stable load-bearing structure, resulting in poor plugging performance. In contrast, fiber incorporation fundamentally transforms weak particle bridging into a mechanically stable plug, with a distinct concentration threshold governing this transition. The addition of powder to the particle-fiber system further accelerates plug formation and enhances plug compactness by reducing pore connectivity. Among the formulations investigated, the ternary system containing 1 wt% particles, 0.5 wt% fibers, and 4 wt% powder exhibits the highest pressure-bearing capacity, achieving a maximum plugging pressure of 13.97 MPa, whereas increasing the powder concentration to 5 wt% produces the shortest plug formation time. Based on these findings, a synergistic plugging mechanism is proposed in which particles form the primary load-bearing skeleton, fibers reinforce and stabilize the particle framework, and powder densifies the pore structure to improve sealing integrity.