In this paper, a case study is presented for a marine structure for which modelling has been used to predict the protection potentials over the life of the structure.
The aim of any digital transformation of integrity management and in particular corrosion control is the improvement of communication efficiency, planning efficiency and maintenance efficiency. Key issues are predictive maintenance and clarity of the information available so engineers can make informed decisions. Therefore it is not just a question of collecting more information but also the way that information is used and shared with the decision-makers.
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Equipment can have an important impact on the production at a refinery, petrochemical, or chemical plant. Change of equipment will often have a negative impact since it can disrupt the production with shutdowns, which will lead to production losses. In the long term, these short lifetimes for the equipment will cause many shutdowns, which will give a higher production cost. One example of equipment is the shell-and-tube heat exchanger.
Mineral wool has been widely used for several decades as the primary thermal insulation on piping and equipment to save energy, protect personnel, and reduce emissions. The products have been favored because they are non-combustible, cost effective, provide excellent (and reliable) thermal performance and are safe, easy, and efficient to install.
Corrosion resistant alloys (CRAs) are used for many pipeline and wellhead components associated with oil and gas production environments but may be considered too costly for longer crude oil and natural gas production lines. Mitigation of internal corrosion for these types of pipelines is normally carried out by batch treatment or continuous injection of corrosion inhibitors, especially the surfactant type of organic inhibitors, which are more economical than using a CRA.
Over the years there have been several different corrosion modelling software packages developed to provide predicted (estimated) corrosion rates for use in the oil & gas industries. Many are based on the original work of DeWaard & Milliams which provided a best-fit statistical model to corrosion rates measured in flow loop laboratory tests conducted at the IFE (Institutt For Energiteknikk) in Norway ; covering (initially) just partial pressure of CO2, temperature, liquid flow velocity and pH (typically as bicarbonate and dissolved CO2).
Mineral scale deposition resulting from waterflooding processes and chemical treatment operations is one of the common issues in upstream oil and gas production. It can lead to significant flow assurance problems as scaling in the reservoirs, wellbores, well casings, oil pipelines, and other production facilities may cause considerable equipment damage and production loss while interfering with corrosion management. Scale usually deposits as a combination of different mineral phases due to the changes in solution conditions such as the saturation level, temperature, pressure, and pH.
Back in 2018, we published a paper on a joint industrial R&D project, during which we performed detailed field measurements on selected pipeline segments in close vicinity to a High Voltage Direct Current (HVDC) transmission line during planned staged fault tests on the power line. Induced voltages on these pipelines were recorded during the HVDC staged fault process, which was conducted by the utility company. The measurement results from these tests were used for further validation or modification of an existing industrial guideline that focuses on the influence of HVDC power lines on metallic pipelines. Verification of future modeling results was another expected outcome of this study.
Multi-principle element alloys (MPEAs) represent a new alloy development philosophy, where the base alloy has significant atom fractions of several elements. Among MPEAs, high entropy alloys (HEAs) are defined as alloys containing 5 or more principle elements. In 2004 Cantor et al. introduced Fe20Co20Cr-20Ni20Mn20 (H4Mn20), a 5-element equimolar HEA. It was found that this alloy formed a single FCC solid solution and solidified dendritically.
Since geothermal reservoirs are a feasible energy source to replace fossil fuel supply, many technologies have been developed to take advantage of geothermal energy. Nevertheless, due to the chemical composition of hydrothermal fluids and temperatures, service conditions in geothermal facilities are demanding in many cases in terms of corrosion. Therefore, materials selection based on preliminary material qualification is essential to guarantee a secure and reliable operation of the facilities.
Alloy 600 and its weld alloys 182 and 82 are susceptible to Primary Water Stress Corrosion Cracking (PWSCC). Various mitigation techniques have been developed and qualified in recent years that aim to use compressive surface membrane stresses to prevent cracks from forming or to stop the growth of short cracks. As described in the parent article (“Part 1”), Ultra-High Pressure Cavitation Peening (UHPCP) developed by Framatome (previously AREVA NP) uses this approach to mitigate Alloy 600 andAlloy 182 locations against PWSCC.