The reservoir for strong edge-bottom water flooding has significant reserves, but its recovery degree and development effect are often unsatisfactory. The factors that influence the residual oil secondary enrichment process, as well as the impact of development strategies through reservoir numerical simulation and field practice, have been subjected to rigorous examination. The GN152 block oil reservoirs in Gannan Oilfield, Zhanhua Sag, serve as examples. The results indicate that the fluid properties, petrophysical properties, and formation properties of strong edge and bottom water reservoirs have varying effects and degrees on the process of remain oil secondary enrichment. Among these factors, formation dip, reservoir thickness, oil-bearing strip width, permeability, formation water density, rock compression coefficient, and anti-rhythmic heterogeneity are favorable factors that affect the residual oil secondary enrichment process. When the reservoir permeability is less than 500 mD, the formation dip angle is less than 35°, the formation water density is less than 1.3 g/cm³, the reservoir thickness is less than 15 m, and the width of the oil-bearing strip is less than 400 m, significant changes occur in the compression coefficient, anti-rhythm change amplitude, and water invasion velocity (hydrodynamic gradient, pore fluid pressure variation amplitude) as well as other parameters. The shorter the secondary enrichment time of remaining oil, the faster the secondary migration of oil and water, the shorter the injection-production period, and the better the water displacement effect. This is the main factor that accelerate the secondary enrichment of remaining oil and the coupled injection-production displacement process. Based on the field practice of Gannan 152 Block and Gannan 2 Block, a secondary accelerated enrichment strategy of manually adjusted residual oil is proposed. This strategy mainly involves scaling reasonable injection-production well spacing and implementing outside-water injection to optimize well location, improve well pattern, and enhance individual well reserve control. After the adjustment, the unit's daily oil capacity increased from 143 t to 262.9 t. The water flooding control degree reached 91.1%, and the average recovery rate increased from 35.5% to 46%, resulting in a 10.5% increase and achieving good development results.