Abstarct: Recently, water-baxsed gas foams have emerged as a viable solution for sealing wellbore chokes and fractures, effectively preventing fluid loss in depleted reservoirs. Understanding the mechanisms controlling fluid loss is crucial for mitigating damage during drilling operations in depleted formations, thereby optimizing the application of these foams. Laboratory studies using micromodels can investigate the hypothesis of foam formation in sealing fractured networks, contributing to the reduction of fluid loss. This research focuses on evaluating the performance of a specific polymer gel—composed of bentonite, Lost Circulation Material (LCM), polyacrylamide (PHPA), and crosslixnker—under pressure and temperature conditions using a Pressure-Temperature Apparatus (PPA). The increase in temperature over time under pressure in the PPA indicates the thermal resistance and stability of the gel in harsh reservoir conditions. The ability to withstand pressures of 500 psi and temperatures up to 90°C for 30 minutes demonstrates the high potential of this gel for applications in depleted reservoirs. The study aims to optimize the formulation and conditions for utilizing these gels to control fluid loss. Initially, 7 grams of bentonite, 20 grams of LCM, and 25.5 grams of PHPA were mixed with 350 milliliters of water in a mixer at 2.5 RPM. After 15 minutes, 0.7 grams of crosslixnker were added and mixed for 5 additional minutes before curing in an oven. The resultant sample withstood 500 psi pressure in the PPA, indicating its suitability for further investigation. Results indicate a consistent increase in temperature with extended testing time in the PPA, confirming that the gel can endure up to 90°C after 30 minutes under pressure. The findings underscore the necessity for further research into solid additives such as clay, calcium carbonate, and silica, which enhance the properties of polymer gels. This research is timely, as fluid loss in fractured reservoirs remains a significant challenge in the oil and gas industry, leading to increased operational costs and potential well abandonment. In conclusion, enhancing the properties of polymer gels through the incorporation of solid additives presents a promising avenue for mitigating fluid loss during drilling operations. The optimization of these formulations holds the potential to significantly reduce economic losses while improving drilling efficiency in challenging reservoir conditions. Future studies should focus on the practical application of these findings in field conditions to validate their effectiveness in real-world scenarios.