The stimulation of the reservoir with hydraulic fractures entails the use of significant amounts of water from various sources that may present certain incompatibilities with the formation water, generating precipitates that damage the conductivity of the channels created by the hydraulic fracture and have negative repercussions in the production of the wells. For the fracturing of the tight reservoir Pozo D-129 located in the San Jorge Gulf Basin, water of diverse ionic compositions obtained in freshwater wells is used. When mixed with the formation water, which is chemically incompatible, it generates the formation of insoluble scale in the thermodynamic conditions of the well. A significant decrease of production was observed in a short period in fractured wells, consequently the probability of scale damage was analyzed using thermodynamic modeling to simulate the compatibility of formation water with fracture water. This study concludes that there is a high probability of scale formation for both CaCO3 and BaSO4. For this reason, different control and inhibition technologies were evaluated to control this chemical process. These evaluations include different inhibitors, chelators, encapsulators, scale solvents, with the aim of being incorporated into the fracturing fluid, with the purpose of privation. In order to correct possible damage caused by water incompatibility, combined treatments of HCl acid, solvents and scale inhibitors were carried out in the field to remove possible damage and guarantee its durability over time. An attempt has been made to identify the damage remediation effect through build-up tests in the treated well. The results are under evaluation with a significant recovery of the well production. On the other hand, the addition of scale inhibitors compatible with the fracture gel was preventively implemented to ensure correct stimulation of the reservoir.