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The recent development of ASTM D8370-22 provides a field-applicable technique for measuring impedance on protective coatings. The test method expands the use of electrochemical impedance spectroscopy (EIS) beyond the laboratory and standardizes the approach for various applications to polymeric coatings on conductive substrates, e.g., barrier coatings on steel structures. Example applications include condition assessments and quality control testing.
This research evaluates laboratory data collected in an environmental chamber using the new ASTM D8370 Field Measurement of Electrochemical Impedance on Coatings and Linings test method. The study simulates field testing conditions by placing the field potentiostat and sample within controlled environments, such as an environmental chamber. The experiments controlled for relative humidity (RH) and temperature independently across 14% RH to 100% RH and 35 F (2 C) to 115 F (46 C), respectively, to evaluate the effect of environment on impedance data. The coating systems evaluated were solvent-borne epoxy, 100% solids epoxy, polysulfide-modified epoxy, and solution vinyl. The results showed the strongest effect for temperature, with each coating type exhibiting impedance values changing inversely with temperature.
Alloy K-500 (UNS N05500) is concomitantly a centurial material and the very first precipitation-strengthened nickel-based alloy, then developed in the 1920s by the newly-formed International Nickel Company, or Inco. Derived from Monel 400 (UNS N04400) that was invented in 1901, Alloy K-500 shares many of the same corrosion and tribological characteristics. Being a pioneer alloy with so-called “stain-less” characteristics, AlloyK-500 also established itself as the first high-strength oilfield nickel alloy, having survived sour service conditions exceeding the capabilities of the low-alloy steels of the time. From early naval propeller shaft applications togeneral cross-industrial uses, Alloy K-500 has always been considered a corrosion-resistant alloy, or CRA. For instance, it has been included in the NACE MR1075 document right from the first 1975 edition.
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Natural gas pipelines are subject to internal corrosion. Internal corrosion of steel pipelines can cause natural gas leakage, leading to wasted energy, explosion hazards, and methane emissions. The U.S. Department of Transport reported numerous case histories of corrosion problems and failures in wet gas pipelines. The National Energy Technology Laboratory (NETL) performed an incident survey from 2010 through 2018 and found that 112 (12%) of these incidents in the U.S. transmission lines were caused by internal corrosion.
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.