Recent design studies regarding deep Gulf of Mexico (GOM ) subsea flowlines have revealed many challenges, the most onerous being that once designed, installed and placed in operation, pipeline in-situ monitoring and integrity management are proving very difficult and expensive. The methods to do the work exist but the logistics and practices often present formidable questions, significant testing, and difficult justification. Such experiences have emphasised the need to identify, understand, develop, and corroborate critical relationships between corrosion mechanisms, and flow regimes, and tailor the predictions accordingly. In practice this often reduces to a consensus based acceptability and pragmatic interpretation of the effects of flow on general and localized corrosion. Most importantly the identification of positions, or sites, within the pipeline internal surface where maximum corrosion stimulus may be expected to occur, thereby allowing better understanding, mitigation, monitoring, and therefore more meaningful control over the full life cycle. Needless to say once corrosion problems arise under deep water pipeline applications, modifications or resolutions are extremely challenging and possibly cost prohibitive. This driver has however accelerated growth in the subject matter, largely by enforcing a better determination of corrosion through propensity and risk assessments at the detail design stage of pipeline projects. Case histories are discussed to illustrate the methodology, and potential commercial advantages.