A significant number of the offshore gas projects planned for the North West shelf of Australia present corrosion and flow assurance challenges (paraffin wax, hydrates and scale). Temperatures at the wellhead may be as high as 140°C, which combined with carbon dioxide levels of 10–20 mol % could lead to aggressive, acidic gas corrosion of the infrastructure and pipelines. The water depth, temperature and operating conditions of these pipelines may result in hydrate formation and subsequent blockages (particularly during shutdowns). Many of the projects have a base case specifying the use Mono Ethylene Glycol (MEG) to suppress hydrate formation in the pipelines. In the majority of these systems, the MEG is regenerated either at satellite platforms or onshore processing plants after which it is resupplied to the injection point offshore (i.e. a re-circulating glycol system). This basis of design requires a different approach towards chemical selection than a once through system due to the possible impact of the corrosion inhibitor (and other chemicals) on the glycol regeneration system. This paper details the corrosion challenges of these systems and describes the testing required to: Develop corrosion inhibitors that will reduce the potential for severe corrosion; and, Meet the requirements for use in re-circulating glycol systems.