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While performing cathodic protection surveys, carrier pipe and casing potential readings are typically recorded at the same test station location near the end of a casing. Comparing these potentials should reveal a difference between the cathodically protected pipe versus an unprotected and electrically isolated casing. The difference in potentials is one of available tests to determine whether a casing may be electrically shorted to the carrier pipe. The pipe-to-electrolyte and casing-to-electrolyte potential comparison is usually the initial “screening” method.
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The concept of using physics-based models for corrosion monitoring is still new although corrosion monitoring by use of hardware coupons and probes is well recognized. This paper describes the application in downstream related to crude unit overhead and demonstrates how the monitoring concept can be used and its benefits.
The corrosion process of carbon steel in the presence of silica sand deposit in chloride-containing solution at 30 °C was monitored by use of electrochemical noise (EN). Results demonstrated that electrochemical noise with recurrence quantification analysis is useful for monitoring localized under deposit corrosion.
All Zero-voltage ammeters, including the zero-resistance ammeter or the shunt-resistance ammeter, impose a small voltage between each of the electrodes and the coupling joint. An experiment studied the effect of the voltage imposed on the measured corrosion currents using a CMAS probe. Experimental results.
A large power transmitter completed a multiyear corrosion study to verify the corrosion rate models for zinc and steel. As a result of that study, a long term field corrosion monitoring program, at 125 sites, was initiated.
In this paper field data from preferential weld corrosion monitoring is presented, and compared with other techniques used for monitoring.
In this study, we retrieved multiple samples from several wells in an onshore oilfield and submitted them for 16S rDNA taxonomic analysis in two different laboratories. The results showed significant differences between laboratories.
Assessing the corrosion degradation of aboveground tank bottom plates is a critical challenge for the industry. Internal inspections are a useful way of assessing the integrity of assets but might severely impact normal plant operation. In 2006, Chang et al. conducted a study on storage tank accidents and concluded that 74% of reported accidents occurred in petrochemical refineries, and 85% of them had caused fire and explosions.
The intent of this document is to describe the major aspects of the sampling process, from specific sample identification, determination of analytical requirements, through sample point design, to sample collection. Consideration of these aspects is necessary for the development of robust and safe sampling programs, protocols, and procedures to facilitate indirect corrosion monitoring.
This document is to assist end users in the development of sampling programs. The guidance is structured to provide an awareness of the major aspects of program design, which if not addressed, may have a significant negative impact on the overall performance of these programs. While this document has been primarily developed with a focus on sampling for indirect internal corrosion monitoring; the basic concepts have a broader applicability and may be of benefit to those developing sampling programs in other areas or for other requirements.
Aboveground storage tanks (ASTs) are assets that contain valuable goods for the oil and gas industry. Consequently, monitoring and preventing loss of containment and extending the service life of those assets is a priority for the abovementioned industries. To monitor the degradation process of the tanks, ER probes are typically used to determine the corrosion rates. Corrosion rates can be used to forecast the service life of an asset by estimating the time at which the degradation reaches a critical thickness of the tank. If the corrosion rate is such that the critical thickness is expected to reach below the expected service life of the asset, the lifespan can be extended by corrosion mitigation methods.