Corrosion In multiphase flow systems: The impact of high Co₂ and low water conditions

Corrosion in multiphase flow systems presents a persistent threat to the integrity of oil and gas pipelines, especially under complex operating conditions. This paper investigates internal corrosion mechanisms in environments characterized by high carbon dioxide (CO₂) levels and low water content—a combination traditionally perceived as less corrosive due to water’s essential role in electrochemical degradation. Contrary to conventional assumptions, this study reveals that corrosion can still initiate and propagate under low-water conditions, particularly through the presence of condensed water films and micro-phase separation. The paper provides a detailed analysis of how corrosion manifests in such systems, considering key factors such as flow regime, wall shear stress, and the localized accumulation of aqueous phases. Special attention is given to the formation and stability of iron carbonate (FeCO₃) scales, which may act as protective barriers or, under specific conditions, degrade into porous, ineffective layers. The interplay of temperature, pressure, and hydrocarbon composition is also examined, highlighting how these variables influence both the likelihood and severity of corrosion in transitional flow regimes. Advanced modeling techniques are employed to improve corrosion rate predictions, accounting for intermittently wetted surfaces and the dynamic behavior of fluids in stratified or slug flow patterns. Laboratory experiments and field data are integrated to validate these models and refine risk assessment tools. The study concludes with recommendations for corrosion monitoring and mitigation in systems where traditional water-dependent models may underestimate risk. These findings contribute to a more nuanced understanding of CO₂ corrosion and support the development of targeted, cost-effective corrosion management strategies in dry or semi-dry pipeline environments