Optimization of deployment pattern parameters of horizontal well fracturing in tight oil reservoirs

This paper establishes a new numerical simulation model for the two-phase coupled flow in tight oil reservoir: the complex fractures in near-well region are described by a dual-porosity model, while those in far-field region are illustrated by a single-porosity model. Then, a pressure displacement system was created between the injection and production wells to effectively drain the reservoir stratum. After that, the productivity and seepage features of the wells were studied under different well patterns, while the fracturing parameters of injection wells were examined by the simulation model. The research results show that the injection at 100m away from the simulated reservoir volume (SRV) region has minimal impact on tight oil production; the injection wells should be deployed on the edge of the maximum drainage area, aiming to replenish the near-well zone with far-field fluid; more injection wells in the SRV region of tight oil reservoir does not mean better