Although low-permeability reservoirs possess abundant geological reserves and significant development potential, they generally exhibit issues such as low porosity, low permeability, and strong heterogeneity, making conventional development methods ineffective in efficiently mobilizing reserves. CO₂ flooding and displacement synergistic technology, with its significant advantages in enhancing recovery rates, has garnered widespread attention in recent years. However, existing studies are largely confined to core-scale experiments, which fail to accurately reflect the vertical and horizontal heterogeneity characteristics of reservoirs. Additionally, the dynamic evolution patterns of pressure fields and saturation fields during the flooding process remain poorly understood. This study focuses on a low-permeability reservoir, constructing a large-scale high-temperature and high-pressure two-dimensional physical plane model. Comparative experiments were conducted using three methods: natural depletion, synchronous injection-production, and asynchronous injection-production. Numerical simulations were also employed to explore the mechanism of action and the influence of key parameters of CO₂ injection-production synergy technology. The results show that the final recovery rate of the asynchronous injection-production method is 24.31% and 26.09% higher than that of the natural depletion and synchronous injection-production methods, respectively. The core mechanism lies in the reconstruction of the reservoir pressure field caused by the alternation of injection and production, forming a synergistic effect between displacement and oil production, thereby promoting the migration and mobilization of crude oil in low-permeability zones. Numerical simulation results further indicate that reasonable configuration of injection and production layers, well spacing, well pressure, and abandonment pressure are key to achieving synergistic enhanced production; in vertically heterogeneous reservoirs, the highest recovery rate is achieved when high-permeability layers are located at the top, while those in the middle are prone to gas cone formation due to low-permeability blocking; larger well spacing can delay gas breakthrough and expand the affected area; staging pressure must exceed miscible pressure to ensure complete miscibility; abandonment pressure is negatively correlated with recovery rate, with its critical value approaching crude oil saturation pressure. This study, under the CCUS framework, first utilized a large-scale two-dimensional physical model system to reveal the synergistic mechanism of CO₂ flooding and displacement in low-permeability reservoirs, proposed optimization principles for key development parameters, and provided theoretical basis and technical references for field trials and large-scale implementation.