Abstract: Addressing the critical contradiction between condensate oil recovery and peak regulation capacity during the conversion of condensate gas reservoirs into underground gas storage facilities, this study proposes a three-stage integrated method: "cyclic injection-production – collaborative recovery enhancement – gas storage operation". Focusing on the Dalaoba condensate gas reservoir, high-temperature and high-pressure physical simulation experiments were conducted to determine that the optimal timing for transitioning from cyclic injection-production to collaborative recovery enhancement occurs when the injected gas volume reaches 0.6 times the hydrocarbon pore volume (0.6 HCPV). The influence patterns of injection-production parameters on recovery performance during the collaborative phase were quantitatively characterized. The results indicate that employing a combined gas injection displacement-evaporation mechanism during the collaborative period effectively improves the condensate oil recovery factor. However, excessively lower pressure limit in a single cycle lead to a decline in cumulative recovery, and the recovery enhancement effect diminishes significantly after more than five injection-production cycles. Accordingly, the recommended procedure is as follows: after 0.6 HCPV of cyclic gas injection, implement five cycles of collaborative injection-production with a lower limit pressure of 40 MPa, followed by multi-cycle gas storage operation, ultimately achieving a cumulative condensate oil recovery factor of 70%. This research validates the effectiveness of the three-stage method in balancing efficient recovery and storage capacity development, clarifies key transition timing and parameter thresholds, and provides a basis for the collaborative optimization of "recovery enhancement and storage construction" in similar condensate gas reservoirs.