AMPP Store - Products tagged with 'co2 corrosion'

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Electrochemical Behavior Of Transmission Pipeline Steels In Supercritical Carbon Dioxide

Product Number: 51322-17592-SG

Author: Zineb Belarbi, Lucas Teeter, Richard E. Chinn, Margaret Ziomek- Moroz, Ömer N. Doğan

Publication Date: 2022

$20.00

High-pressure steel pipeline is a common, cost-effective method for transporting CO₂ from its point of capture to storage sites¹. In pipeline transport systems, CO₂ is mostly transported in its liquid or supercritical phase, depending on the operating pressure^2,3, which requires compression of CO₂ gas to a pressure above 80 bar (Figure 1) and avoid a two-phase flow regime in the steel pipelines. In the USA, the longest CO₂ pipelines, which transport more than 40 MtCO₂ per year from production point to sites in Texas, where the CO₂ is used for enhanced oil recovery (EOR), operate in the “dense phase” mode and at ambient temperature and high pressure.

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Field Study of Corrosion Inhibition Effect on Corrosion of Low Flow Velocity Gas Flowlinesunder CO2 Environments

Product Number: MECC23-20102-SG

Author: Muhammad Sohaib Khan; Mohammed S. Alqahtani

Publication Date: 2023

$20.00

Carbon Dioxide (CO2) corrosion of carbon steel (sweet gas corrosion) poses a serious problem in oil and gas production, since most used materials are low alloyed carbon steels, which are not corrosion resistant. Basically, the main aspects of CO2 corrosion are well known today, and the parameters are temperature, CO2 partial pressure, pH value, and flow velocity [1-2]. CO2 dissolves in brine to form an acidic solution that corrodes carbon steel equipment.

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Fitness-for-Purpose Research of OCTG for Underground Gas Storage Applications in H2/CO2 Environments

Product Number: 51320-14698-SG

Author: Yameng Qi, Zhonghua Zhang

Publication Date: 2020

$20.00

In China, some underground gas storages (UGS) would be built to reserve the gaseous coal gas (CO, H2, CO2, H2O, etc.). Gaseous hydrogen induced hydrogen embrittlement (HE) and CO2 corrosion could possess great threat to the safety of OCTG in UGS. Fitness-for-purpose research of OCTG materials is urgently expected to screen out the suitable material for tubing application in UGS.
HE resistance and CO2 corrosion of OCTG materials (C110, 3Cr-90S, 13Cr-110 and 13Cr-110S) were investigated by slow strain rate testing and weight loss tests in UGS environments containing CO2 and H2. SSRT results show that both elongation ratio and reduction in area ratio of C110, 13Cr-110 and 13Cr-110S were more than 80%, except for 3Cr-90S. In addition, 3Cr-90S and 13Cr-110 tested in H2/CO2 environments possessed embrittled regions and secondary cracks, respectively. Weight loss test results show that C110 and 3Cr-90S exhibited high corrosion rates, which were classified as severe corrosion followed by qualitative categorization of corrosion rates for oil production systems in NACE RP0775. For stainless steels (13Cr-110 and 13Cr-110S), the corrosion rates were very low (low corrosion). Combined with the above results, 13Cr-110S could be the suitable OCTG material for UGS containing gaseous coal gas.

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Guidance for Materials Selection and Corrosion Control in CO2 Transport and Injection for Carbon Capture and Storage

Product Number: 51322-17726-SG

Author: J. Sonke, S.J. Paterson

Publication Date: 2022

$20.00

The aim of this work is to identify an approach to materials selection and corrosion control that can address the specific requirements of a Carbon Capture and Storage (CCS) project. This work is largely based on the accumulated knowledge and expertise that has been published. Besides the direct guidance from this document, specific topics may require more detail that can be found in the references.

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Identification of Synergistic Interactions in Green Corrosion Inhibitor Mixtures by Molecular Modeling

Product Number: 51324-20368-SG

Author: Carlos M. Menendez; Oleg A. Mazyar; Sunder Ramachandran; Tracey Jackson

Publication Date: 2024

$40.00

The composition of corrosion inhibitors used in the Oil and Gas industry are predominantly based on multiple components. It is highly desired that all the components present in a corrosion inhibitor will interact synergistically. Synergistic corrosion inhibitor mixtures will improve performance and reduce the minimum effective inhibitor concentration, which is key particularly for subsea applications. Additionally, subsea applications in the North Sea, the Norwegian shelf and other areas of the world require corrosion inhibitors to follow strict environmental regulations. In this work, the application of molecular modeling by using the frontier orbital principle for the screening and selection of prospective green multicomponent corrosion inhibitors is reported. It is also shown how this quantum-chemistry based approach can expedite corrosion inhibitor development.

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Impact of CO2 Partial Pressure on Electrochemical Measurements at High Temperatures

Product Number: 51320-14584-SG

Author: Peng Jin, Carlos M. Menendez, Zhengwei Liu, Sunder Ramachandran

Publication Date: 2020

$20.00

Laboratory testing of corrosion inhibitors under high temperature high pressure (HTHP) conditions is challenging. HTHP testing has been traditionally performed in closed systems with fixed liquid/gas volume and testing results are usually influenced/compromised by the accumulation of ferrous ions and corrosion products. The aim of the work is to optimize corrosion inhibitor testing conditions at HTHP to generate results of better reliability. The corrosion of carbon steel by CO2 at HTHP was assessed using small working electrodes of large liquid volume-to-sample surface area in autoclaves. The effect of CO2 partial pressure was also investigated. The blank and inhibited corrosion rates were monitored by linear polarization resistance (LPR) and the morphology of coupon surface was measured by vertical scanning interferometry (VSI). The testing results were deemed to be more representative of the field service environment when the amount of ferrous ions and corrosion products was reduced due to the usage of small working electrodes.

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Impact of Impurities on the Corrosion of CO2 Dense Phase Transmission Pipelines

Product Number: MECC23-20236-SG

Author: Mohammed Yousif; Ayman Musaad; Usman Ali; Ali Alhajeri; Faisal M Al-Abbas

Publication Date: 2023

$20.00

A dense phase or supercritical CO2 pipeline is a crucial state in the oil and gas sector, particularly when it comes to enhanced oil recovery (EOR) and carbon capture and storage (CCS)1. The process of CCS involves three stages: capture from sources (e.g., cement factories and power plants), transportation process, and storage. Generally, these pipelines carry CO2 from different industrial facilities to geological formations.

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In Situ Atomic Force Microscopy Study Of Microstructure Dependent Inhibitor Adsorption Mechanism On Carbon Steel

Product Number: 51322-17739-SG

Author: H. Wang, B. Brown, S. Nesic, A. Pailleret

Publication Date: 2022

$20.00

Corrosion resistant alloys (CRAs) are used for many pipeline and wellhead components associated with oil and gas production environments but may be considered too costly for longer crude oil and natural gas production lines. Mitigation of internal corrosion for these types of pipelines is normally carried out by batch treatment or continuous injection of corrosion inhibitors, especially the surfactant type of organic inhibitors, which are more economical than using a CRA.

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Influence of Impurity Adsorption and Condensation on the Initial Corrosion Mechanism of CO2 Transport Pipeline Steel

Product Number: 51323-19066-SG

Author: Minghe Xu, Yoon-Seok Choi, Srdjan Nesic

Publication Date: 2023

$20.00

CO2 captured from different sources for carbon capture and storage (CCS) will contain impurities. Although it is technologically possible to treat CO2 to near 100% purity in the gas conditioning process, it is preferable to have fewer rigid specifications to reduce both operational and capital costs. From a corrosion point of view, SOx, NOx, H2S, and O2 are considered to be the most aggressive impurities.

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In-situ Study of Iron Carbonate Formation Kinetics and Pseudo-passivation of Carbon Steel in Aqueous CO2 Environments

Product Number: 51324-20667-SG

Author: Joshua Owen; Richard C. Woollam; Francois Ropital; Annette Kleppe; Sabrina Marcelin

Publication Date: 2024

$40.00

This study introduces the design and implementation of a bespoke electrochemical flow cell in combination with in-situ Synchrotron Radiation-X-Ray Diffraction measurements (SR-XRD). The system enables high precision, real-time, in-situ measurements of iron carbonate (FeCO3) evolution on carbon steel in a flowing environment, as well as providing real-time, in-situ corrosion rate measurement through an integrated three-electrode cell. The custom cell is used to examine FeCO3 formation kinetics in a carbon dioxide (CO2)-containing aqueous environment, particularly in instances where the ‘pseudo-passivation’ phenomenon is reported to occur. Linear polarization resistance and anodic polarization measurements were performed in combination with the SR-XRD measurements to establish a detailed understanding of FeCO3 formation in real time and its relation to the corrosion behavior of carbon steel. It was observed that ‘pseudo-passivation’ occurred in conjunction with the growth of a highly protective FeCO3 layer under all conditions evaluated. Magnetite (Fe3O4), an oxide layer often attributed to the onset of ‘pseudo-passivation’, was not observed in these conditions, despite the high limits of detection of the technique.

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In-Situ Synthesis Of Corrosion Product-Polymer Composites On Carbon Steel For Enhanced Erosion-Corrosion Protection In CO2 Corrosion Environments

Product Number: 51322-17717-SG

Author: Dilshad Shaikhah, Bruce Cowe, Wassim Taleb, Anne Neville, Maalek Mohamed-Said, Richard Barker

Publication Date: 2022

$20.00

Hydrocarbons still remain as a fundamental contributor towards meeting the worldwide demand for energy, despite the growth of other alternative sources such as renewable and nuclear options. Due to low cost and availability, carbon steel, remains as the most commonly used material for pipelines in down and upstream activities within the oil and gas industry. However, carbon steel is not an exceptional metal alloy from the perspective of internal corrosion resistance. The economical cost for its degradation and related failures represent 10% to 30% of the maintenance budget in petroleum industry. It is therefore crucial that the corrosion of such a susceptible steel is managed and controlled accordingly.

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Investigating The Effect Of H2S And Corrosion Inhibitor On The Corrosion Of Mild Steel Under High Pressure CO2 Conditions

Product Number: 51322-17943-SG

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

Publication Date: 2022

$20.00

Over the past decade, there has been increasing interest in the corrosion behavior of carbon steels in supercritical CO₂ conditions. Unlike the case of carbon capture and storage (CCS) where small amounts of water are present, the exploitation of fields with high pressures of CO₂ needs to consider the presence of formation water, which presents strong corrosivity. It has been reported that the aqueous corrosion rate of carbon steel at high CO₂ pressures (liquid and supercritical CO₂) without protective FeCO₃ corrosion product layers is very high (>20 mm/y) due to the high concentrations of corrosive species such as H⁺ and H₂CO_³.^1-5 Steels with low Cr contents (i.e., 1% Cr and 3% Cr) have shown no beneficial effect in terms of reducing the corrosion rate to admissible values.6 Therefore, controlling corrosion in these cases usually involves the use of corrosion resistant alloys (CRAs) or corrosion inhibitors (CI). Adequate protection of carbon steel was achieved by applying CI in high pressure CO₂ environments.⁶

Products tagged with 'co2 corrosion'

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