AMPP Store - Products tagged with 'co2 corrosion'

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Corrosion Behavior of Martensite-Based Stainless Steels in Chloride Solutions Saturated with CO2 Containing Impurity Gases

Product Number: 51323-18908-SG

Author: Yuichi Kamo, Kenichiro Eguchi, Hiroyuki Takai

Publication Date: 2023

$20.00

Carbon Capture and Storage (CCS) is a countermeasure for the global warming issue, and the number of CCS projects has increased. One type of CCS is Enhanced Oil Recovery (EOR), in which CO2 is injected into oil or natural gas reservoirs. Because formation water, which usually has a high concentration of chloride, exists at the bottom of these reservoirs, the injection tubing will suffer corrosion when the formation water flows back to the tubing. Stainless steels have been applied as tubing materials for Oil Country Tubular Goods (OCTG), and showed excellent corrosion resistance under high temperature and high CO2 pressure conditions. Martensite-based stainless steels bearing 13 mass% Cr to 17 mass% Cr are one of these tubing materials and are also expected to be used in CO2 injection tubing.

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Corrosion Behavior of Zinc Cold Spray Coatings (ZnCr & ZnNb) in a Simulated Natural Gas Environment Containing H2O, CO2, and H2S

Product Number: 51324-20451-SG

Author: Zineb Belarbi; Richard E. Chinn; Ömer N. Doğan

Publication Date: 2024

$40.00

Internal corrosion and sulfide stress cracking (SSC) are problems for steel pipelines transporting natural gas or CO2 containing partial pressures of H2S higher than 0.3 kPa (0.05 psi). The objective of this work is to mitigate internal corrosion and SSC in steel pipelines transporting natural gas containing H2S using cold spray coatings. Two types of the cold spray binary metallic coatings (zinc chromium (ZnCr), zinc niobium (ZnNb)) were studied using electrochemical techniques: potentiodynamic polarization (PDP), linear polarization resistance (LPR), and electrochemical impedance spectroscopy (EIS). The evaluation of the corrosion resistance of cold spray coatings (ZnCr, ZnNb) was carried out in an environment containing 4 bar CO2 pressure, simulating the partial pressures that are found in gas transmission lines over a solution of 3.5 wt.% NaCl heated to 40 °C. To simulate sour conditions, a concentration of 0.003 M Na2S2O3.5H2O, which corresponds to H2S partial pressures around 0.079 bar (1.146 psi), was used. Post-corrosion surface characterization was performed using a scanning electron microscope (SEM) equipped with energy-dispersive X-ray spectroscope (EDS) and X-ray diffraction analysis (XRD). The data showed that the presence of 0.003 M Na2S2O3.5H2O shifted the corrosion potential to more anodic values and decreased the corrosion current density. Bothcoatings showed similar behavior after 1 hour of exposure in CO2/H2S environment, which indicated that similar electrochemical reactions were taking place on ZnNb and ZnCr. SEM images and EDS surface analyses for specimens showed a significant change in surface chemical composition of carbon steel coated with ZnNb and ZnCr, after 24 hours of immersion. No localized attack was observed. The EDS analysis and XRD results revealed the presence of zinc sulfide (ZnS).

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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.

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Corrosion reactions in simulated CO2 ship transport conditions

Product Number: 51320-14572-SG

Author: Morten Tjelta, Bjørn Helge Morland

Publication Date: 2020

$20.00

For certain CCS (carbon capture and storage) projects, ship transport of captured CO2 to the storage site may prove more optimal than pipeline transport. The CO2 will be transported under two-phase conditions at low temperature (-10 to -25 °C) and moderate pressure (1.7 – 2.7 MPa), which are quite different from the typical pipeline transport conditions (5 – 60 °C and 7 – 12 MPa). Corrosion under pipeline conditions has been relatively well studied, and several conditions (impurity mixtures) that results in formation of corrosive acids have been identified. In contrast, almost no research exists on corrosion under ship transport conditions when the CO2 contains impurities. The present work tested corrosion of carbon steel at -25°C in CO2 with different concentrations of H2O, H2S, O2, NO2 and SO2. The experiments demonstrated that certain combinations of impurities gave no chemical reactions and no corrosion, while other combinations resulted in formation of solids and corrosive components that attacked carbon steel. The mass loss corrosion rate was around 0.1 mm/y.

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Dual Functional Corrosion Inhibitor Design And Testing For Top-Of-Line And Bottom Of Line Corrosion

Product Number: 51322-17787-SG

Author: Larry Chen, Nihal Obeyesekere, Jonathan Wylde, Michael Sim

Publication Date: 2022

$20.00

TOL corrosion is reported to occur in large diameter wet gas pipeline in stratified flow conditions
due to low fluid velocities1. With increasing distance from the inlet, the wet gas pipeline becomes
cooler as it loses heat to the environment. Such cooling causes water, hydrocarbon, and other
high vapor pressure species to condense on the pipe wall. The upper part of the pipe will
constantly be supplied with freshly condensed water while the less corrosive water saturated
with corrosion products will be drained along the pipe wall to the bottom of the line.

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Effect of Acetic Acid on Corrosion Product Layer Formation in Aqueous CO2 Environments

Product Number: 51323-19306-SG

Author: Sahithi Ayyagari, Bruce Brown, Srdjan Nesic

Publication Date: 2023

$20.00

Several studies have focused in the past on the precipitation mechanism of iron carbonate (FeCO3), which is the dominant corrosion product in CO2 environments observed in the oil and gas industry. The dissolved CO2 species undergo a series of chemical reactions and react with the oxidized iron ions forming FeCO3 as the primary corrosion product. In the past, the thermodynamics of each of these reactions have been thoroughly studied and modified by incorporating the effects of temperature and non-ideality.

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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.

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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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Effect Of H2S On CO2 Corrosion Of Mild Steel In HPHT Conditions

Product Number: 51321-16622-SG

Author: Yoon-Seok Choi/ Fernando Farelas/ Luciano Paolinelli/ Srdjan Nesic/ Ahmad Zaki B Abas/ Azmi Mohammed Nor/ Muhammad Firdaus Suhor

Publication Date: 2021

$20.00

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Effect Of Hydrophobic Interaction On Corrosion Inhibitor Efficiency

Product Number: 51322-17597-SG

Author: Susumu Hirano, Ayano Yasui, Hirotaka Mizukami, Tatsuya Sei, Toshiyuki Sunaba

Publication Date: 2022

$20.00

Corrosion inhibitors are used to prevent pipeline corrosion in oil and gas industry. The evaluation of corrosion inhibitors is one of the most important tasks for the corrosion engineers. Corrosion of the metal is suppressed by the inhibitor adsorption on the metal surface. Active ingredients of corrosion inhibitors are, in general, surfactants. A surfactant can adsorb on the internal metal surface of piping and makes a hydrophobic film preventing the contact of water with the metal surface.

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Effect of Minor Ce Additions on Corrosion Behavior of Experimental Pipeline Steel

Product Number: 51324-20450-SG

Author: Zineb Belarbi; Paul D. Jablonski; Ömer N. Doğan; Martin Detrois; Richard P. Oleksak

Publication Date: 2024

$40.00

Minor additions of rare earth elements (REEs) have been shown to improve various steel properties. In particular, Cerium (Ce), as a relatively abundant and inexpensive element, has received attention as a potentially beneficial minor alloying addition for a variety of steel applications, including pipeline materials. The objective of this work is to investigate the effect of Ce on corrosion performance of experimental pipeline steel. Electrochemical corrosion experiments were carried out on steel without and with 0.0057, 0.0164, and 0.0263 wt.% of Ce in 3.5 wt.% NaCl saturated with CO2 at 20 °C. For comparison purposes, X100 carbon steel specimens machined from an experimental pipe with a yield strength of 731 MPa were tested under the same conditions. The electrochemical techniques employed included: potentiodynamic polarization (PDP), linear polarization resistance (LPR), and electrochemical impedance spectroscopy (EIS). In addition, post-corrosion surface characterization was performed using scanning electron microscopy (SEM) equipped with energy dispersive X-ray spectroscopy (EDS). The corrosion of base metal without Ce was significantly lower (0.15 mm/y) compared to carbon steel X100 (0.9 mm/yr). The electrochemical results showed that adding Ce accelerates corrosion rates compared to base metal without Ce. No pitting corrosion of tested steel was detected.

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Effect Of Steel Microstructure And Corrosion Product Characteristics On Inhibition Performance Of Decanethiol Against TLC

Product Number: 51321-16581-SG

Author: Z. Belarbi/ F. Farelas/ D. Young/M. Singer

Publication Date: 2021

$20.00

Products tagged with 'co2 corrosion'

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