Two of 19 wells were lost to carbonate scale in a high-temperature gas condensate field with commingled production. The problem was identified as tubing plugging. Plugging was caused by a 6-8 °C heating of water from the shallow interval when mixed with the hotter hydrocarbons from deeper formations. Even though there is a thermodynamic potential for scale precipitation within the reservoir, formation damage due to scale has not been positively identified so far, after up to 5 years production history. Thermal effects were important to understand this: Expansion cooling reduces the development of formation damage. These conclusions are explained quantitatively with thermodynamic and scale chemistry modeling of the field observations.

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