Adaptability and Effect Evaluation of Temporary Plugging Fracturing Technology in the Chang 6 Reservoir of Area A

Abstract The reservoir in Area A are developed with synchronous injection and production. Waterflooding operations in specific reservoir units may induce elevated formation pressure concurrent with declining performance metrics in existing wells. This phenomenon arises from either micro-fracture network propagation or formation impairment, manifesting as depressed liquid levels, reduced flowing pressures, and diminished productivity indices for both fluids and hydrocarbons. Temporary fracture diversion technology proves effective for stimulating ultra-low permeability reservoirs. During implementation, engineered plugging particulates carried by fracturing fluids selectively invade original fracture-connected perforations and high-permeability zones. Through strategic accumulation within these zones, they establish impermeable filter cake barriers that redirect subsequent fluid stages toward underutilized reservoir regions. Under the condition of a certain horizontal bi-directional stress difference, secondary fractures will be generated, and then the fracture initiation orientation will be changed to create new fractures. To enhance production efficiency and maintain sustainable development in Area A’s oilfields, 44 well operations implemented temporary fracture diversion technology between 2022-2024. Field implementation outcomes confirm a 90.9% technical success rate with 7,723 tonnes of cumulative production gain, demonstrating significant production enhancement. This approach establishes critical technical support for exploiting ultra-low permeability reservoirs, particularly proving instrumental in sustaining long-term productivity of Area A’s Chang 6 formation.