<p>Inorganic scaling is the adhesion of mineral solids precipitated from a supersaturated brine onto surfaces. In oil and gas production, especially from carbonate reservoirs such as those in the Brazilian pre-salt, it has emerged as a significant flow assurance issue. Scaling on production equipment—including sand-control screens, inflow control devices, downhole valve, and tubing—obstructs flow by reducing the effective open area, which increases head loss and, in severe cases, can lead to complete production blockage. Carbonate scaling is influenced by local pressure, temperature, and the presence of various ionic species at differing concentrations. Changes in the aqueous composition of CO₂ coupled with pressure drops, can alter the saturation index and precipitation rate, initiating scaling. Additionally, scaling is influenced by turbulence intensity, which affects the transport of crystals or chemical species towards the wall. This paper proposes an integrated method for modeling and simulating calcium carbonate scaling in a one-dimensional context. It employs a geochemical simulator coupled with a mass transport approach, designed for multiphase flow scenarios involving oil, gas, and water. The treatment of multiphase flow as a mixture or segregated flow system is determined through analysis of Reynolds and Froude numbers. Using this approach, the scaling rate on a pipe wall was simulated, demonstrating good agreement with field and literature observations. Specifically, the results show that scaling increases with flow rate, pressure drop, CO₂ degassing, and temperature.</p>