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A 22-year-old liquid line experienced an unexpected failure due to internal corrosion after adding the production from one well. Investigation included ILI records, operating pressures and temperatures, oil pressure / volume / temperature (PVT) data, possible flow regimes, failure analysis reports, and mitigation practices.
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Simulation and modeling of corrosion processes is an area of research that has seen significant growthin recent decades, with technological advancements drastically reducing the time required to solve theequations that underpin real-world physics. Predicting the behavior of a system computationally, whendone accurately, provides great benefit complementing experimental testing to further explain what ishappening within the corrosion process. There have therefore been multiple predictive models producedover the years to achieve this aim. Within the realm of carbon dioxide (CO2) corrosion, Kahyarian et al.
The Supercritical Carbon Dioxide Corrosion Test Facility is equipped with 3 high-temperature, high-pressure vessels and a gas-phase Fourier transform infrared spectrometer (FTIR) for simultaneous in situ monitoring of key contaminants. This paper outlines the capabilities of this new National Institute of Standards and Technology facility.
Corrosion of carbon steel is the most prominent reason for pipeline failure in a range of industries, from oil and gas transportation to water treatment facilities and nuclear waste storage. Under-deposit corrosion occurs in low fluid flow rate environments, when particulate matter (such as sand and clay) settles on the bottom of transportation pipelines. The presence of deposits results in a diffusion barrier, which significantly alters interfacial solution chemistry compared with that of the bulk.