Oil&Gas
Corrosion in upstream infrastructure is driven by a complex interplay of factors, including the partial pressures of CO₂ and H₂S, chloride concentrations, multiphase flow dynamics, and produced water chemistry. Accurately quantifying the influence of these variables on corrosion degradation is fundamental to improving predictive maintenance and asset integrity strategies across the upstream sector. This chapter introduces a suite of computational tools tailored for the oil and gas industry, beginning with a primary CO₂/H₂S corrosion model that serves as the technical foundation for subsequent modules, including specialized Internal Corrosion Direct Assessment (ICDA) models. Collectively, these tools provide a comprehensive framework for the rapid and accurate evaluation of corrosion rates, flow regimes, and other critical parameters essential to ensuring operational safety and equipment integrity.
This chapter presents a CO₂–H₂S corrosion modeling approach developed for oil and gas applications, incorporating multiphase flow behavior and pH prediction. The model is used to estimate corrosion rate, pH, flow regime, wall shear stress, and other parameters influencing internal corrosion. By integrating hydraulic and chemical conditions within a single analytical framework, the approach supports the evaluation of corrosion susceptibility under operating conditions relevant to upstream production. Use of this methodology supports informed design and operational decisions intended to manage CO₂/H₂S corrosion and maintain system integrity.