This paper describes the challenges associated with chemical treatment of liquid loaded, gas condensate in subsea pipelines and the importance, of not only performance but also stability in glycol regeneration processes downstream. Untreated field produced fluids were used in all foamer production formulation and testing. Standard column sparged testing was used as initial screening, followed by a modified method to mimic the response to increase in dosage and concentration of chemical in the fluids to be unloaded. The product was designed to be compatible with capillary string for subsea injection, and with the glycol carrier fluids that it would be injected with. It also had to be thermally stable to withstand the glycol regeneration process that the fluids passed through on the topside process after the pipeline reaches surface. Product formulation on field fluids resulted in a chemical foamer that resulted in thick foam but with quick collapse time and half-life, which limits any possible carry over into the production process. The product was found to be thermally stable at 170°C and would not cause any contamination of the glycol regeneration process. Production application in the field is expected in second quarter of 2016, and all results will be shared in this paper. Product was formulated with blend of sulphonated quaternary ammonium compounds and polymers, in conjunction with high boiling point glycols to withstand high temperatures and function as good foaming agents in mixed water/hydrocarbon systems.