Dominant Factors Controlling Fracture Hit in Tight Reservoirs: A Case Study from Hydraulic Fracturing Development of Tight Oil in the Ordos Basin

As hydraulic fracturing technology for unconventional reservoirs becomes increasingly mature, the development mode of “large-stage multi-cluster small well spacing” has led to severe interwell interference issues. To address the insufficient research on the dominant controlling factors of fracture hits in tight reservoirs, this study established a heterogeneous geological model based on logging data from tight reservoirs in the Ordos Basin, simulating the effects of engineering and geological factors on fracture hits. The dominant factors influencing the degree of fracture hits were quantitatively evaluated. The results show that: (1) The primary controlling factors of fracture hits are well spacing, pore pressure, and permeability, which collectively account for 60.1% of the total influence; (2) The impact of well spacing on fracture hits exhibits a critical threshold—under current operational parameters, when well spacing exceeds 300 m, the degree of fracture hits decreases significantly. Under staggered fracture patterns, a larger stress differential results in reduced fracture hits due to stress shadowing effects; (3) Factors positively correlated with the degree of fracture hits include fluid viscosity, fluid volume, pump rate, natural fracture length, and pore pressure. This study clarifies the dominant factors governing fracture hits in tight reservoirs, providing theoretical support for small-spacing development strategies and contributing to enhanced unconventional oil and gas production.