Study on a Polymer Gel System for Deep Profile Control in High-Temperature and High-Salinity Reservoirs

Polymer gel profile control technology can effectively modify water flow channels in water-flooded oil reservoirs and enhance oil recovery. However, most polymer gel systems exhibit poor performance, such as low strength, not suitable for high-temperature and high-salinity reservoir conditions, leading to ineffective water shutoff. To address this challenge in complex formations of high-temperature, high-salinity fractured reservoirs, a temperature- and salt-tolerant polymer gel system with delayed crosslinking was developed based on the concept of slow hydrogen-bond crosslinking. Laboratory evaluations demonstrated that a gel system formulated with 0.4 wt% HPAM and 0.2 wt% PEI (HPAM/PEI) achieved a gel strength grade of G index. Even at 100 °C or a salinity of 200,000 ppm, the HPAM/PEI system maintained a gel strength grade of F, indicating excellent temperature resistance and shear stability. The slow hydrogen-bond crosslinking mechanism endowed the system with delayed gelation characteristics. Sandpack and core flooding experiments confirmed that the HPAM/PEI system could form high-strength gels in situ with low polymer retention. After treatment, the permeability of the core was reduced by over 99%, and the effective blocking duration exceeded 12 months. This study provides a theoretical foundation for applying the HPAM/PEI gel system in deep profile control and water shutoff in high-temperature and high-salinity reservoirs.