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Oil and gas production in a CO2 saturated environment is known to lead to corrosion due to dissolved carbonic acid. However, when the conditions are favorable, a protective FeCO3 layer can also form which reduces the material degradation of the underlying steel by up to ten or a hundred times.1 The formation of FeCO3 is possible via the reaction shown in equation 1.
Iron carbonate (FeCO3) is a carbon dioxide (CO2) corrosion by-product known to provide corrosion resistance to carbon steel in specific environmental conditions. Nonetheless, it suffers from both chemical dissolution and mechanical damage when the pH is low and when subjected to particle impingement, respectively. This work aims at understanding whether incorporating two amino acids, mainly cysteine and glycine help improve either the reduction in corrosion rate or the mechanical properties of FeCO3. In addition to their corrosion inhibition properties, it is anticipated that incorporating such organic moieties directly into the FeCO3 layer as it grows should have a positive effect on properties such as the modulus, in turn making the layer less prone to internal stresses and disbandment. Our results show that both amino acids incorporate within the FeCO3 matrix and affect the hardness and modulus of the hybrid layer. Moreover, cysteine is able to reduce localized corrosion attack in such environments.
Coating degradation on Army ground systems represents a significant maintenance cost and effort. The objective of this proposed work is to develop a predictive model for coating degradation and subsequent substrate corrosion on Army ground assets. Provided with a better understanding of the root causes, steps can be taken to reduce corrosion impacts on Army materiel.
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Development of new oil and gas fields is likely to involve sour reserves to an increasing degree. Sourproduction often brings about difficulties in terms of asset integrity, related particularly to corrosionmitigation. Employing corrosion resistant alloys implies a considerable escalation in investment costs. On this basis the use of carbon steel and CO2/H2S corrosion inhibition remains a highly desirableoption.
External corrosion on offshore O&G platforms is one of the biggest threats to asset integrity and its management is a large operational expense. Many operators now implement risk-based assessment (RBA) programs where all equipment is assessed periodically with the aim to reduce operational costs while maintaining integrity. Regulatory codes for offshore platforms in the GoM require a visual inspection of all pressure equipment and piping every five-years. In practice, this can equate to approximately 20% of equipment being inspected per year on a large-sized offshore platform (i.e., a topside weight of around 10,000 tons), with a rolling five-year inspection plan to balance the inspection workload evenly through time.