Repeat fracturing fracture propagation is ultimately controlled by changes in the direction and magnitude of the stress field, which are caused by changes in the pore pressure and temperature fields brought about by the dynamics of initial fracturing and well production. [PERSON] first put forth a two-dimensional coupled model in 1993 to determine the variables affecting fracture steering by computing the variations between the greatest and minimum horizontal primary stresses at different points in time [10]. By analyzing stress fluctuations around horizontal wells, [PERSON] developed analytical and numerical models to evaluate the parameters influencing hydraulic fracture extension [11]. [PERSON] examined how changes in the local stress field affect the timing of subsequent fractures by examining fracture behavior, wellbore interactions, and production metrics after initial fracturing [12]. To identify regions of stress field alteration that influence the direction of repeat fracture extensions and to examine the effects of reservoir non-homogeneity on stress field changes, [PERSON] created a two-dimensional coupling model [13]. [PERSON] studied refracturing and pressure field deflection in detail, and he proposed a coupled oil-water two-phase fluid-solid model to study the effects of hydraulic and natural fractures on the stress field and the interplay between injection and hydraulic fracturing [14]. To increase the distance of the re-fractured sections and hence maximize output, [PERSON] proposed that new fractures should be directed perpendicular to existing fractures before refracturing [15]. To improve the efficiency of repeat fracturing wells, [PERSON] used simulation technologies to examine pressure variations after fracturing and drainage, identifying the best times and temporary plugging locations [16]. These studies highlight the need to examine first fracture propagation and well production dynamics to evaluate stress field changes, as well as the significance of stress field reorientation before repeat fracturing and the establishment of ideal fracture timings. This work proposes a three-dimensional, completely coupled seepage field-stress field model as the basis for a fracture extension prediction approach for refracturing of shale oil horizontal wells. By combining the dynamic study of well production following initial fracturing with geomechanical simulation, the method methodically examines the impact of stress field deflection on the direction and length of fracture extension of refracturing, as seen in Figure 1. The technique first analyzes dynamic production data to identify the characteristics of the residual oil saturation distribution. Next, it inputs temperature field, pore pressure, and residual oil saturation data from various production periods into a coupled seepage field-stress field model to simulate the evolution of the stress field. Finally, it uses the reconstructed coupled model to perform numerical simulations of repeated fracture extension. The following three elements primarily demonstrate this study's innovation:  
(1) A numerical simulation framework for refracturing of horizontal shale oil wells with multi-field coupling is constructed for the first time. A fully coupled seepage-stress field model is created by combining the production dynamics of the initial fracturing and the distribution of residual oil with the three-dimensional heterogeneous geological and geomechanical models. This model offers a methodal way to uncover the mechanism of fracture steering and fracture propagation in refracturing. In addition, the developed numerical framework can be readily extended to simulate more complex scenarios involving multiple horizontal wells to study well interference, which will be the focus of our subsequent studies. (2) A creative stress field reconstruction approach based on dynamic production data is proposed, breaking beyond the conventional multi-field coupling technological path.