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CO2 corrosion of the internal walls of mild steel pipelines has always been a significant problem in the oil and gas industries. Different methods have been implemented to mitigate internal pipeline corrosion. The use of corrosion inhibitors provides advantages compared to other mitigation techniques as inhibitor treatment costs are seen to be lower and can be easily adjusted over time.
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Top-of-Line Corrosion (TLC) is a practical but costly problem for unprocessed natural gas transport. Utilizing multiphase pipelines instead of processing the well-fluids offshore has required massive modeling development to control hydrate formation and corrosion. At the inlet of the pipelines, the gas, and other well fluids have much higher temperatures than the pipelines' outside environment, e.g., cold ocean water or river water.
At the request of a fabricator and coater of steel pipe and structural members, the authors undertook an investigation of painted steel piles at a marine commerce terminal in coastal New England. This company was concerned when the owners suspected a potential corrosion problem with the steel piles, and we were asked to perform the investigation. The investigation included a review of relevant engineering specifications and other documents, an on-site field investigation, and laboratory analysis of samples collected.
Material selection to get “fit-for-purpose” alloys is an important task that corrosion engineers face in their daily work. Two common ways of attacking such a challenge is by testing different alloys in environments similar to the application in a laboratory environment or installing samples in actual operating equipment. In the latter, testing is usually time consuming and might require plant turnovers to get access to the equipment for sample installation.
Cavitation occurs in localized areas where there is a pressure drop across a structure; the water goes through a phase transition and forms water vapor. These vapor bubbles implode, resulting in high velocity micro-jets which impact adjacent surfaces. These impacts release shockwaves of energy, which cause microscopic particles of the surface material to flake off.1 Repeated micro-jet impact causes microfractures in the affected surfaces and leads to pitting.
The Effluent Treatment Facility (ETF) at the Hanford Nuclear Reservation site is a multi-waste treatment facility that removes radioactive and hazardous contaminants from various sources such as condensate wastewater generated by 242-A Evaporator campaigns, groundwater projects, solid waste disposal facilities, and other Hanford clean-up activities. It has been operational since December 1995 and will reach its original 30-year design life in 2025. The waste streams processed in the ETF are different from Hanford tank-farm wastes, in that the ETF wastes range to relatively higher chloride and sulfate concentrations, and lower nitrate and nitrite concentrations.
Steel is a common material for the construction of large infrastructures. It is a main constituent used for building of, offshore drilling platforms, steel cast dock, pipeline in seabed, coastal bridges and ship hulls. Corrosion of offshore structures is a serious matter in terms of degradation and deterioration of these structures in a corrosive electrolyte such as seawater, which could lead to fatigue cracks, brittle failure and unstable failure.
Cathodic protection is used in addition to organic coatings to ensure the integrity of offshore and onshore buried structures against corrosion. The cathodic protection efficiency is usually ensured by keeping the potential of the structure to be protected in a narrow range following standard recommendations such as ISO 15589-1 and/or NF EN 12954. For onshore buried structures, this potential range is limited by the protection potential Ep and the limit potential El.
During drilling operations, the components in the drill string including the bottom hole assembly (BHA) remains in permanent contact with the drilling fluid. Therefore, besides non-magnetic properties and high strength the corrosion resistance of the materials utilized for the BHA plays a decisive role specially in applications involving harsh environments. In fact, strain-hardened CrMn-austenitic steels commonly used in directional drilling technology show a high susceptibility to pitting corrosion and environmentally assisted cracking in drilling fluids with a high chloride (Cl-) content at elevated temperatures.
VDM Alloy 699 XA (UNS N06699, EN Alloy number 2.4842) is a new alloy, which was developed for applications in the petrochemical industry under metal dusting conditions between 400°C and 800°C. Important properties of a new material are corrosion resistance, such as to metal dusting, oxidation resistance, and workability versus high temperature strength, which are essential for industrial applications. Currently, there are material solutions which demonstrate good metal dusting resistance, but may have issues with workability. In addition, there are also minimum requirements concerning creep resistance. It is therefore of fundamental interest, in the context of alloy design, to develop materials that has these important properties and satisfies the needs of industrial users.
The manufacturing and field experience of high strength low alloy (HSLA) steel plates produced by Thermo-Mechanical Controlled Process (TMCP) are well defined in industry standards and literature. The TMCP method consists of a well-prescribed rolling pass schedule followed by accelerated cooling that leads to a fine-grain microstructure with the desired mechanical properties of the produced plates.Quite recently, this TMCP process resulted in detrimental local variations with hidden hardness variations on pipe ID, so-called Local hard Zones (LHZ).
The formation of inorganic scale deposits in numerous waters mediated industrial applications takes place by heterogeneous nucleation and crystal growth. These processes depend on the supersaturation of the solution in contact with respect to the depositing salt, on the characteristic features of the surface on which scaling takes place, temperature, fluid velocity and the presence of foreign substances. Despite the importance of the surface on which salts form, very few studies have focused on this issue.