Abstract
Under the backdrop of growing global energy demand and the gradual depletion of conventional oil and gas resources, the efficient development of tight oil faces significant challenges due to the complex coupling of geological and engineering parameters. This study focuses on a typical fractured horizontal well in the Damin Tun Sag of the Liaohe Oilfield, aiming to elucidate the relative control of geological factors (matrix and fracture permeability, effective thickness) and fracturing parameters (main fracture conductivity, stage spacing, cluster spacing, fracture half-length, etc.) on well productivity and their dynamic evolution over time. A refined dual-porosity numerical model combined with single-factor sensitivity analysis and normalized impact factor ranking was employed, with model accuracy validated through history matching. Results reveal that productivity evolution can be divided into three stages: early high production dominated by fracture network fluid supply, mid-term rapid decline driven by matrix transition, and late gradual decline controlled by remote matrix. Geological factors, initially weak, become increasingly significant in the mid to late production stages. Main fracture conductivity consistently serves as the primary controlling factor, followed by stage and cluster spacing. The dominant controls shift from engineering parameters to geological properties as production progresses, reflecting the intrinsic evolution of the oil supply mechanism. This study clarifies the multifactor coupled control mechanisms and provides theoretical and quantitative support for optimizing fracturing design and integrated geological-engineering development, promoting a more refined and dynamic approach to tight oil exploitation.
