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High flow velocity can have negative impact on the integrity of the oil and gas production equipment. This negative impact can manifest by the reduction of Corrosion Inhibitor (CI) efficiency: the higher the flow velocity, the lower the CI efficiency. The negative impact can also manifest by the occurrence of liquid erosion corrosion phenomena.
High flow velocity can have negative impact on the integrity of the oil and gas production equipment. This negative impact can influence the efficiency of Corrosion Inhibitor (CI). It is well established that the higher the flow velocity, the lower the CI efficiency. Another detrimental effect of flow velocity is the possible occurrence of erosion-corrosion phenomena, where the bare metal will be continuously exposed to the corrosive environment, and thus corroding much faster than in low flow velocity conditions. The C-factor, as derived from API RP 14E equation, is used as criteria to limit the flow velocity to avoid such severe phenomena. This criterion is dependent on fluid corrosiveness, efficiency of the inhibition and the presence of solid particles. The Company uses a software, an in-house developed tool, to predict and evaluate the risk of erosion-corrosion for different oil and gas production equipment. Typical parameters influencing the corrosiveness of the fluid (water phase composition, CO2 content in the associated gas, pressure, temperature), the production data (GOR, BSW) and the geometry of the equipment are considered when evaluate the likelihood of erosion-corrosion occurrence. Two case studies are presented, both concerning multiphase subsea production pipelines in service on our offshore assets. As per COMPANY strategy this equipment is periodically inspected via In Line Inspection (ILI) Technology, with the aim of assessing its status. The results of these inspections are analyzed from a corrosion management point of view. Considering real production data and operating conditions, the in-house software was used to evaluate the corrosiveness of the produced fluid and the occurrence of erosion-corrosion phenomena. The predicted corrosion rates are then compared with the ones measured by inspection tools (ILI & non-intrusive thickness monitoring). This analysis is used further on to re-define the corrosion mitigation program.
In this paper, the CP current distribution with changing resistivities and the area of influence required to meet effective CP criteria, is studied. The results indicate that the tank pad electrolyte resistivity plays a significant role in achieving uniform CP current distribution. The paper also explores the use of Vapor Corrosion Inhibitor (VCI) and its effect on electrolyte resistivity and the resulting CP current distribution.
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AC interference studies have become increasingly popular in an industry where shared right of ways have increased and there has been a better understanding of how AC interacts between pipelines and powerlines that are collocated with each other. While modeling software for AC interference studies have been developed since the 1990s, advancement in AC interference processes have occurred as more has been learned over the years. When performing an AC interference study there are three steps that need to be completed: field data collection, modeling, and mitigation design. Within this paper, we can compare a project from ten years ago to a project from today to understand the developments that have been made over the course of time to improve the way we develop our mitigation designs.
Carbon steels such as API 5L X65 are widely used oil and gas exploration, production and transportation service. However, these steels tend to corrode in the presence of wet CO2 and corrosion is more pronounced in the presence of dissolved salts and acids. Other metals, alloys and polymers also degrade in the presence of high pressure gaseous and supercritical CO2. The corrosion rate of carbon steels in some aqueous environments have been reported to be more than a few millimeters per year.9-10 The situation could be further exacerbated by H2S where cracking can be an issue for high strength steels.