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In this work, a marine environment due to the presence of marine bacteria was exposed to three zinc-rich epoxy coated-steel samples with different carbon nanotube additions. The electrochemical activity was monitored by using open circuit potential and electrochemical impedance spectroscopy.
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The austenitic Ni-base Alloy 600 has been extensively used as structural material in primary water reactors (PWR). Despite good resistance against general corrosion in water-cooled nuclear power reactors, the material has been susceptible to stress corrosion cracking (SCC). These observations have led to ongoing discussions of the underlying embrittlement mechanism(s). Internal oxidation of the grain boundary (GB) at typical operating temperatures is one such mechanism, although debate continues on the exact mechanisms at play.
Alloy 600 (Ni-16Cr-9Fe) is well known to exhibit intergranular corrosion and intergranular stress corrosion cracking (IGSCC) upon exposure to high temperature water environments, including those found in service environments of pressurized water reactors (PWR). While the higher Cr content alloy 690 exhibits superior IGSCC resistance in these environments, alloy 600 is still in use at many light water reactor plants. Part of the difficulty in assessing alloy 600 performance is the significant variability in behavior from heat to heat, both from the standpoint of initial alloy chemistry and the subsequent thermomechanical treatment of the material.
At the time of a recent maintenance shutdown, cracking was discovered in the repads and parent material in the vicinity of several nozzles along the bottom of two in-situ production treater vessels. Some of the cracks were reported to be through-wall. The vessels were commissioned in 2009 and had been in service for about 13 years before the cracks manifested as through-wall.
Corrosion is defined as the degradation of a material or its properties due to a reaction with the environment and is one of the most common pipeline integrity threats for operators. External corrosion may be visually inspected during excavation; however, due to accessibility, additional non-destructive examination (NDE) methods must be utilized to identify the presence and severity of internal corrosion.
Understanding the chemistry and electrical properties of how corrosion occurs aids in mitigating the presence of corrosion, specifically internal corrosion.
The Permian Basin is an oil-and-gas-producing area located in West Texas and the adjoining area of southeastern New Mexico. The Permian Basin covers an area approximately 250 miles wide and 300 miles long and is composed of more than 7,000 fields (best represented in Railroad Commission of Texas production figures as districts 7C, 08, and 8A) in West Texas.1 The greater Permian Basin accounts for nearly 40 percent of all oil production in the United States and nearly 15 percent of its natural gas production.
Pipeline-D was built in 1997 and was used to transport crude to Gas-Oil Separation Plant-1 (GOSP-1). The pipeline continued operating until it was subjected to intermittent shutdown in 2009 when GOSP-2 was built. As part of the project, 900 meters were added to connect Pipeline-D to GOSP-2.