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NACE SP0169 Control of External Corrosion on Underground or Submerged Metallic Piping Systemsの改訂

Evaluation of environment-assisted cracking susceptibility of a grade X100 pipeline steel

The corrosion wear behaviors of two aluminum bronzes, Cu-14Al-X and QAl9-4, in 3.5% NaCl solution were investigated on a pin-on-block reciprocating tester. It was found that the wear loss of the bronzes in 3.5% NaCl solution was lower than that in water and in air, i.e., it exhibited “negative” synergy between corrosion and wear. To understand the corrosion wear mechanism of the bronzes, the corrosion rate and polarization curves of Cu-14Al-X and QAl9-4 in 3.5% NaCl solution were determined. The worn surfaces of the specimens were examined, and the wear tracks were measured using scanning electron microscopy. The corrosion patinas formed on the specimen surfaces were studied with x-ray photoelectron spectroscopy and electron probe microanalysis. The corrosive solution was shown to play an important role in cooling of the specimen surfaces during the wear, thus preventing the specimen’s surface hardness from being reducing, induced by frictional heat during the sliding wear. On the other hand, the bronzes suffered from dealloying corrosion; a noble copper subsurface and patina formed on the specimen surface in the corrosive solution, which had a passive function for further corrosion. The noble copper subsurface experienced strain hardening during the corrosion wear, resulting in an increase of the surface hardness and thus an increase in wear resistance.

Corrosion wear behavior of Al-bronzes in 3.5% NaCl solution

The review presented herein is regarding the stress corrosion cracking (SCC) phenomena of carbon steel pipelines affected by the corrosive electrolytes that comes from external (E) and internal (I) environments, as well as the susceptibility and tensile stress on the SCC. Some useful tools are presented including essential aspects for determining and describing the E-SCC and I-SCC in oil and gas pipelines. Therefore, this study aims to present a comprehensive and critical review of a brief experimental summary, and a comparison of physicochemical, mechanical, and electrochemical data affecting external and internal SCC in carbon steel pipelines exposed to corrosive media have been conducted. The SCC, hydrogen-induced cracking (HIC), hydrogen embrittlement, and sulfide stress cracking (SSC) are attributed to the pH, and to hydrogen becoming more corrosive by combining external and internal sources promoting cracking, such as sulfide compounds, acidic soils, acidic atmospheric compounds, hydrochloric acid, sulfuric acid, sodium hydroxide, organic acids (acetic acid, mainly), bacteria induced corrosion, cathodic polarization, among others. SCC growth is a reaction between the microstructural, chemical, and mechanical effects and it depends on the external and internal environmental sources promoting unpredictable cracks and fractures. In some cases, E-SCC could be initiated by hydrogen that comes from the over-voltage during the cathodic protection processes. I-SCC could be activated by over-operating pressure and temperature at flowing media during the production, gathering, storage and transportation of wet hydrocarbons through pipelines. The mechanical properties related to I-SCC were higher in comparison with those reviewed by E-SCC, suggesting that pipelines suffer more susceptibility to I-SCC. When a pipeline is designed, the internal fluid being transported (changes of environments) and the external environment concerning SCC should be considered. This review offers a good starting point for newcomers into the field, it is written as a tutorial, and covers a large number of basic standards in the area.

Analysis of the Physicochemical, Mechanical, and Electrochemical Parameters and Their Impact on the Internal and External SCC of Carbon Steel Pipelines.

The effect of microstructure on the stress-strain behaviour of pipeline steels was studied. Slow strain rate (2×10-6 s-1) tests were conducted on grade X65 and X100 steels in silicone oil and hydrogen carbonate/carbonate solution. The as-received grade X100 steel at 75°C showed serrated stress-strain curves. The magnitude of the serrations depended upon the strain rate and test temperature. Annealing at 600°C or above removes the serrations, but this increased the susceptibility to transgranular cracking in hydrogen carbonate/carbonate solution at potentials below −800 mV (sce). The removal and reformation of banding in pipeline steels were also studied. Ferrite/pearlite becomes aligned during the hot rolling stage of pipe manufacture and causes directionality in crack propagation and mechanical properties. Heat treatments were carried out which show that banding in grade X65 and X100 can be removed above 900°C. This depends on homogenisation of carbon which also depends on temperature, time, and cooling rate.

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R.N. Parkins

Papers

Stress corrosion cracking of high-pressure gas transmission pipelines