This study addresses rapid production decline in the Luzhou Shale Gas Field caused by stress-sensitive artificial fractures. It develops a pressure-controlled production strategy through geology-engineering collaboration to balance single-well Estimated Ultimate Recovery (EUR) and economic returns. The goal is to support cost-effective large-scale development of deep shale gas. Stress sensitivity experiments and wellbore liquid-carrying analysis were combined. A geology-engineering numerical model simulated dynamic fracture conductivity decline under different production rates. The model quantified effective stress evolution, production pressure differences, and liquid-carrying thresholds. Internal Rate of Return (IRR) and EUR were used to optimize production strategies. Initial high production (110,000 m3/d) increased effective stress to 31 MPa, causing fracture conductivity loss and reducing EUR to 1.18 × 108 m3. Pressure-controlled production (70,000 m3/d) kept effective stress below 28 MPa, raising EUR to 1.33 × 108 m3. Considering stress sensitivity thresholds (20 MPa), proppant backflow limits (28 MPa), and critical liquid-carrying rates (52,000 m3/d), a three-year stabilized production plan (80,000, 64,000, and 51,000 m3/d) achieved an EUR of 1.34 × 108 m3 and IRR of 8.56%. Cumulative production in the first three years reached 48% of total EUR, 4% lower than conventional methods. The study introduces a novel three-year stabilized production regime integrating critical liquid-carrying and proppant backflow constraints. A physics-numerical modeling approach optimizes production strategies with technical-economic analysis. This geology-engineering collaboration framework balances well performance and profitability, offering a practical paradigm for deep shale gas development.