The north sector of the North Kadi field at Mehsana is a brownfield with a primary recovery of only ~20% despite good permeability and active aquifer support due to high mobility contrast, with oil viscosity between ~50 to ~120 cP. Polymer flooding is formulated through 8 injector wells in an inverted spot pattern with 21 producers. The key risk involved is the loss of injectivity in polymer injector wells. A case study of two injector wells demonstrates successful mitigation measures employed for the injectivity improvement. The partially hydrolyzed polyacrylamide polymer solution is injected into the polymer injector wells. Injector wells lose injectivity over time, making it hard to keep injection pressure below the designed maximum operating pressure. Critical analysis of the trend of injectivity decline is carried to identify the root causes. A structured mechanism for various mitigation options like solvent treatment, oxidizer treatment, acidization, backwash and technical water squeezing, artificial pressure drawdown, and formation bottom cleaning near the wellbore is discussed. The quality of raw water used for the polymer preparation based on parameters like TSS, turbidity, TDS, and hardness is a key factor in the injectivity loss in the injection wells. In case of rapid decline in injectivity due to poor quality of water with high TSS, turbidity, TDS, and hardness content, solvent squeezing followed by acid stimulation proved optimal. During a gradual rise in injection pressure, while maintaining satisfactory water quality, acid stimulation in combination with oxidizer treatment such as Ammonium Persulphate (APS) proved beneficial. Injectivity maintenance in polymer injector wells has resulted in production gain of approximately 172 tons/day, reducing operational expenses significantly. Monitoring of polymer injector wells is critical, and diagnostic examinations are conducted regularly to assess the severity of the decline.