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Products tagged with 'carbon steel'

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Picture for Corrosion Inhibition of Pipeline Steels Under Supercritical CO2 Environment
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Corrosion Inhibition of Pipeline Steels Under Supercritical CO2 Environment

Product Number: 51317--9153-SG
ISBN: 9153 2017 CP
Author: Yoon-Seok Choi
Publication Date: 2017
$20.00

In the present study, the performance of imidazoline-based corrosion inhibitor was evaluated by examining environmental effects on the corrosion rate and corrosion behavior of materials.
Picture for Corrosion issues in the conversion of vegetable and waste oils to produce biofuels
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Corrosion issues in the conversion of vegetable and waste oils to produce biofuels

Product Number: 51323-19308-SG
Author: Fouad Andari, Jean Kittel, François Ropital, Joana Fernandes, Laure Dodelin
Publication Date: 2023
$20.00

To limit the impact of greenhouse gas emissions on climate change, the use of conventional hydrocarbons needs to be reduced significantly. The global demand for biofuels is thus expected to grow during the present decade. Hydrogenated Vegetable Oil (HVO) is one of the predominant biofuels produced by converting lipidic feedstocks (vegetable oils, animal fats, waste cooking oils, …) through a conventional refinery hydrotreatment (HDT) process.
Picture for Corrosion of Carbon Steel and Alloys in Ammonium Chloride Salt
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Corrosion of Carbon Steel and Alloys in Ammonium Chloride Salt

Product Number: 51314-4007-SG
ISBN: 4007 2014 CP
Author: Kazuhiro Toba
Publication Date: 2014
$20.00

This study was conducted to determine the root cause of aggressive corrosion due to wet NH4Cl salt deposition in reactor effluent streams in hydroprocessing units. In addition corrosion resistance and behavior of carbon steel and alloys in high-concentration NH4Cl solutions were investigated.
Picture for Corrosion of Pipelines in a Crude Oil Storage Facility
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Corrosion of Pipelines in a Crude Oil Storage Facility

Product Number: 51323-19554-SG
Author: Václav Šefl, Tomas Prosek, Pavel Taraba
Publication Date: 2023
$20.00

In the literature, corrosion problems associated with crude oil are often categorized into several classes, based on the type of equipment and “distance” from a well. The upstream operations (drilling, pumping) transport crude oil mixed with significant amounts of water and gasses, midstream operations (transport and storage before refining) deals with much drier crude with most of the water and gasses removed and upstream corrosion problems are mostly caused by chemical composition of given specific fraction and high temperature. Corrosion problems in midstream operations are usually not as severe as during drilling and initial transport, however, this step is significantly longer.
Picture for Corrosion Susceptibility Assessment of Tank 241-AN-106 in Supporting Double-Shell Tank Corrosion Control at Hanford Site
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Corrosion Susceptibility Assessment of Tank 241-AN-106 in Supporting Double-Shell Tank Corrosion Control at Hanford Site

Product Number: 51323-18786-SG
Author: Sheewa X. Feng, Jason S. Page
Publication Date: 2023
$20.00

The chemical and radioactive waste at the Hanford Site is currently stored in 131 single-shell tanks and 27 double-shell tanks (DSTs). The DSTs were built between 1968 and 1986, and each has a capacity of about 1 million gallons. Figure 1 is one typical design of the DSTs. Double shell means that each tank consists of a primary tank within a secondary tank. The primary and secondary tanks are also known as liners, and both are made from carbon steel.
Picture for Development of a Corrosion Control Program for Liquid Radioactive Wastes Stored in Carbon Steel Waste
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Development of a Corrosion Control Program for Liquid Radioactive Wastes Stored in Carbon Steel Waste

Product Number: 51317--9688-SG
ISBN: 9688 2017 CP
Author: Bruce Wiersma
Publication Date: 2017
$20.00

Large underground, carbon steel tanks are used for interim storage of liquid radioactive waste. The current corrosion control program needs to be updated to account for the susceptibility to pitting corrosion of waste tanks due to the halide content of the secondary waste.

 
Picture for Development of a Versatile Continuous Application Based Corrosion Inhibitor to Mitigate Top-of-the-Line Corrosion under Both Sweet and Sour Operating Conditions
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Development of a Versatile Continuous Application Based Corrosion Inhibitor to Mitigate Top-of-the-Line Corrosion under Both Sweet and Sour Operating Conditions

Product Number: MECC23-19972-SG
Author: Jeremy Moloney
Publication Date: 2023
$20.00

Top-of-the-line corrosion (TLC) of carbon steel (CS) pipelines can be encountered during the transportation of wet gas under stratified flow conditions where temperature differences between the internal and external environments results in condensation of saturated vapors and water-wetted surface on the upper portion of the inside pipeline surface causing corrosion issues.1 Initially at least, the condensed water phase can be particularly corrosive with a low pH caused by dissolved acid gases (such as carbon dioxide and hydrogen sulfide) as well as organic acids in an unbuffered thin water film. Like bottom-of-the-line corrosion, TLC can be dominated by either carbon dioxide or hydrogen sulfide corrosion mechanisms.
Picture for Effect of Acetic Acid on Sour Corrosion of Carbon Steel
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Effect of Acetic Acid on Sour Corrosion of Carbon Steel

Product Number: 51317--9318-SG
ISBN: 9318 2017 CP
Author: Jon Kvarekval
Publication Date: 2017
$20.00

An experimental study of corrosion of carbon steel in the presence of H2S, CO2 and acetic acid has been carried out. H2S and CO2 partial pressures up to 10 bar each were applied, with temperatures of 25 and 90oC.
Picture for Effect of Acridine and Myristic Acid on CO2 Corrosion During Intermittent Oil/Water Wetting
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Effect of Acridine and Myristic Acid on CO2 Corrosion During Intermittent Oil/Water Wetting

Product Number: 51323-19192-SG
Author: Neda Norooziasl, David Young, Bruce Brown, Marc Singer
Publication Date: 2023
$20.00

Pipelines are the most effective way to transport oil and natural gas, particularly for their bulk transmission over long distances. Corrosion in oil and gas pipelines occurs because of the presence of dissolved corrosive gases, such as CO2 and/or H2S, in reservoir derived brine, and contact between this brine and the steel surface. The oil phase by itself does not cause corrosion and can even inhibit corrosion.
Picture for Effect of Chloride on the SCC Behavior of Carbon Steel Welds Exposed to Concrete Pore Water under Anoxic Conditions
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Effect of Chloride on the SCC Behavior of Carbon Steel Welds Exposed to Concrete Pore Water under Anoxic Conditions

Product Number: 51323-19029-SG
Author: B. Kursten, R. Gaggiano
Publication Date: 2023
$20.00

In all nuclear power generating countries, high-activity, long-lived radioactive waste is an unavoidable by-product of the contribution of this energy to the global electricity generation. Disposal in deep, stable geological formations is, at present, the most promising option accepted at an international level for the long-term management of these wastes. Geological disposal relies on a combination of engineered (man-made) barriers and a natural barrier (the host rock), in order to prevent radionuclides and other contaminants ever reaching concentrations outside the container at which they could present an unacceptable risk for people and the environment.
Picture for Effect of Dissolved Oxygen on Carbon Steel Corrosion and Particulate Formation. Part 1: Rotating Cylinder Electrode Experiments
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Effect of Dissolved Oxygen on Carbon Steel Corrosion and Particulate Formation. Part 1: Rotating Cylinder Electrode Experiments

Product Number: 51324-20718-SG
Author: K. J. Evans; J. Vera; C. Mendez
Publication Date: 2024
$40.00
The dissolved oxygen concentration (DOC) in seawater injection systems is typically maintained near 10 to 20 ppb. However, these systems can experience DOC excursions that temporarily rise into the 100 to 1000 ppb range. The use of carbon steel piping in some systems is known to result in elevated corrosion rates during upset periods in which DOC increases. However, the particles that are generated from corrosion products during upset conditions are not well characterized or understood. The importance of understanding corrosion-generated particles relates to the plugging of the injection lines, which can lead to costly work-overs of the injection well. The main objective of this work is to examine the impact of DOC excursions on steel corrosion and iron-based particulates that form as a result of corrosion. A rotating cylinder electrode (RCE) electrochemical setup was implemented in conjunction with a particle analyzer instrument to make these correlations in real-time under controlled hydrodynamic conditions. Dissolved oxygen and pH were also continuously monitored throughout the tests. All testing was performed in a seawater simulant brine at 32°C. The key findings from the testing can be summarized accordingly: (1) particle sizes in the 20 to 30 µm range tended to concentrate when the DOC was raised to 1000 ppb; (2) localized corrosion was able to develop on the steel electrodes due to breakdown of a semi-protective film that formed over time; (3) DOC excursions may lead to irreversible increases in the baseline corrosion rate after dissolved oxygen is reduced back to low levels (e.g., 20 ppb).
Picture for Effect of Elevated Temperatures (30-80°C) on CO2 Corrosion after Intermittent Oil/Water Wetting
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Effect of Elevated Temperatures (30-80°C) on CO2 Corrosion after Intermittent Oil/Water Wetting

Product Number: 51324-20967-SG
Author: Neda Norooziasl; David Young; Bruce Brown; Marc Singer
Publication Date: 2024
$40.00
The main goal of this research is to electrochemically determine the influence of temperature elevation (30 °C - 80 °C) on the wetting state and corrosion behavior of mild steel during intermittent oil/water wetting. The results obtained in separate experiments demonstrated that the corrosion mitigation effect of an oil phase (LVT-200 model oil) containing myristic acid (surface-active compound representing naturally occurring oxygen-containing compounds in crude oils) on CO2 corrosion decreased with temperature after intermittent wetting. The influence of the same temperature range on interfacial properties during intermittent oil/water wetting such as oil/water interfacial tension (IFT) and oil-in-water contact angle were also investigated. For model oil containing myristic acid, the IFT value was unchanged with temperature and could not be correlated to the corrosion rate. In the presence of the oil phase, the surface became more hydrophilic at 55 °C, which diminished the adsorption and persistency of the oil layer and decreased the corrosion mitigation effect. The effect of temperature on IFT and contact angle can depend on the nature of oil and surface-active compound.
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