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Caustic stress corrosion cracking (SCC) is known to occur in carbon steels under tensile stress and exposure to caustic solutions from 115°F to boiling temperatures. Alternating wet and dry conditions tend to increase SCC susceptibility. Localized overheating of the metal, such as solar radiation, heat tracing, steam outs and excursions should also be considered. Caustic SCC was first reported in 1980 when the top of a continuous kraft digester vessel blew off in Pine Hill, Alabama. It was found that the tensile residual stresses present in non-stress relieved carbon steel weld seams and the corrosive environment (caustic) were responsible for the cracking
Caustic stress corrosion cracking occurs in carbon steels under tensile stress and exposure to caustic solutions. In this paper, we present metallurgical analyses performed on a pipe-to-tee weld and a tee-to-flange weld that leaked during operation. The pipe was in treated LPG service in a saturated gas plant. Wet fluorescent magnetic particle inspection indicated the presence of crack-like indications parallel to the welds on the outside and inside surfaces of the pipe, with more crack branching being observed on the inside surface. SEM fractography revealed that the fracture surface of these cracks was predominantly intergranular, which was confirmed during metallographic examination as well. Several temperature spikes above the acceptable range for caustic SCC were also reported by the client. Based on these observations, it was concluded that the cracks occurred as a result of caustic SCC and initiated on the inside surface of the welds.
Major manufacturers of protective coatings, steel fabricators, painting contractors, galvanizers, and end users, were surveyed to identify surface preparation and coating application costs, coating material costs, typical industrial environments and available generic coatings for use within those environments, and expected coating service lives (practical maintenance time).
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There are hundreds of kilometers of above-ground carbon steel pipelines located in 32 in-situ oilsands facilities operated by 18 producers in Alberta Canada, with a total thermal oilsands capacity (operating) of 1.8 million barrels per day. A typical in-situ oilsands operation is for recovering bitumen located 75 meters or more below the surface, by the injection of steam.
H2S corrosion, also known as sour corrosion, is one of the most researched types of metal degradation in oil and gas transmission pipelines requiring a wide range of environmental conditions and detailed surface analysis techniques. This is because localized or pitting corrosion is known to be the main type of corrosion failure in sour environments which caused 12% of all oilfield corrosion incidents according to a report from 1996. Therefore, control and reduction of this type of corrosion could prevent such failures in oil and gas industries, and significantly enhance asset integrity while reducing maintenance costs as well as eliminating environmental damage.