The Ansai Block, located in the central-eastern Ordos Basin, is characterized by low-porosity, low-permeability reservoirs with complex geological structures, posing significant development challenges. This study established a three-dimensional petrophysical parameter distribution model encompassing reservoir porosity, permeability, Young's modulus, Poisson's ratio, and in-situ stress. Additionally, a theoretical fracture propagation model was developed that couples fluid seepage, mass conservation, fracture deformation, and proppant transport to accurately simulate the dynamic propagation of complex fracture networks. Through analysis of fracturing effects in typical wells(e. g., Well Hao 22-2), perforation locations, fracture morphology, and fracture conductivity were quantitatively evaluated. The results indicate that under high stress difference conditions, hydraulic fracture lengths range from 135 to 168 m, propped fracture lengths range from 80.6 to 112.0 m, while fracture heights range from 49.8 to 70.0 m. However, vertical fracture height control was inadequate, with multiple fracture segments overlapping, thereby restricting the stimulated reservoir volume. For Well Yan 1317-2, perforation intervals were optimized to 3 642~3 644 m and 3 593~3 595 m, utilizing deep-penetration perforation and CO₂ fracturing techniques. By reducing the number of perforations to 32 and increasing the single-perforation flow rate to 0.33 m³/min, inter-segment stress differences were overcome, thereby enhancing fracture complexity and net pressure. This study provides a theoretical foundation and practical guidance for the efficient development of low-porosity, low-permeability reservoirs in the Ansai Block. It also offers valuable reference for unconventional reservoir development under similar complex geological conditions and promotes the application of CO₂ fracturing technology in support of China's “dual carbon” goals.