Block A has entered the stage of ultra-high water content development, showing the development characteristics of low injection and production speed, prominent low efficiency and ineffective circulation, and scattered distribution of remaining oil. It is difficult to further improve the development effect by relying on conventional adjustment techniques, and it is urgent to optimize the injection and production methods and explore new ways to improve the recovery rate. Three injection production methods were set up, including increasing water injection rate, increasing water injection rate+interval periodic water injection, and increasing water injection rate+injection production coupling. Microscopic flow visualization core displacement experiments were conducted to clarify the occurrence state, utilization mechanism, and utilization status of micro residual oil under different injection production methods. The optimal injection production method was completed, and reasonable injection production parameters were quantified by combining numerical simulation technology. Research has shown that adopting an injection production method that combines increased water injection rate with injection production coupling can effectively utilize micro cluster, porous, and columnar residual oil that cannot be displaced by conventional injection production methods, and maximize the degree of recovery; Reasonable injection rate of 0.06 PV/a, with a rotation injection production cycle of 3 months. After on-site testing, the water flow volume was expanded, the water absorption ratio of sandstone increased by 8.0 percentage points, the cumulative oil production increased by 23000 tons, the water content decreased by 3.6 percentage points, and the stage extraction rate increased by 1.88 percentage points, providing new ideas for improving the quality and efficiency of high water content reservoirs.