Effect of H2S on the Corrosion Behavior of Pipeline Steels in Supercritical and Liquid CO2 Environments

Choi, Yo Han; Hassani, Shokrollah; Vu, Thanh Nam; Nešić, Srdjan; Abas, Ahmad Zaki

doi:10.5006/2026

Cited by 26 publications

(39 citation statements)

References 17 publications

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“…These were performed by Brown et al [76] and Choi et al [97] and are summarised in Table 8. In the work of Brown and colleagues [76] , the general corrosion rate of carbon steel was evaluated in the presence of 200 ppm H2S and 500 ppm Apart from the two independent studies performed by Brown et al [76] and Choi et al [97] , there has been little consideration afforded to the effect of H2S in dense phase CO2 systems and its likely impact on carbon steel corrosion. This is especially from the view of localised corrosion (a form of corrosion known to be linked very strongly to the presence of H2S in oil and gas production systems).…”

Section: Co2-h2o-h2s Environmentsmentioning

confidence: 99%

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Barker

Hua

Neville

2016

International Materials Reviews

134

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Carbon Capture and Storage (CCS) has been highlighted as a potential method to enable the continued use of fossil-fuelled power stations through the abatement of carbon dioxide (CO2). A complete CCS cycle requires safe, reliable and cost effective solutions for the transmission of CO2 from the capturing facility to the location of permanent storage. In subsequent sections, early laboratory and field corrosion experience relating to natural dense phase CO2 transport for the purposes of enhanced oil recovery (EOR) are summarised along with more recent research efforts which focus on identifying the role of anthropogenic impurities in the degradation processes. For each system impurity, the reaction rates, mechanisms and corrosion product composition/morphology expected at the steel surfaces are discussed, as well as each component's ability to influence the critical water content required to initiate corrosion. Potential bulk phase reactions between multiple impurities are also evaluated in an attempt to help understand how the impurity content may evolve along a long distance pipeline.The likelihood of stress-corrosion cracking and hydrogen-induced cracking is discussed and the various corrosion mitigation techniques which exist to control degradation to acceptable 2 levels are reviewed. Based on the current research performed in the context of impure dense phase CO2 corrosion, issues associated with performing laboratory experiments to replicate field conditions and the challenges such limitations present in terms of defining the safe operating window for CO2 transport are considered.

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Section: Co2-h2o-h2s Environmentsmentioning

confidence: 99%

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Barker

Hua

Neville

2016

International Materials Reviews

134

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“…The structure morphology of corrosion products is very important for corrosion behavior. Many studies confirm that corrosion behavior of low‐alloy steel exposed to H 2 S/CO 2 condition depends on structure essence of corrosion products …”

Section: Resultsmentioning

confidence: 99%

Corrosion mechanism of low‐alloy steel used for flexible pipe in vapor‐saturated H₂S/CO₂ and H₂S/CO₂‐saturated brine conditions

Liu

Gao

et al. 2018

Materials & Corrosion

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Immersion experiment was used to elucidate the corrosion mechanism of low‐alloy pipeline steel exposed to vapor‐saturated H2S/CO2 and H2S/CO2‐saturated brine conditions in terms of microstructure, corrosion kinetics, corrosion products, surface/cross‐sectional morphology, and elemental distribution. The experimental results demonstrate that the microstructure of designed steel is tempered martensite, and the corrosion rate in H2S/CO2‐saturated brine condition is larger than that in vapor‐saturated H2S/CO2 condition. The main corrosion product in two corrosion conditions is FeS, which shows various crystal structures. The size of corrosion products formed in vapor‐saturated H2S/CO2 condition is smaller than that of corrosion products formed in H2S/CO2‐saturated brine condition, which contributes to the difference of water chemistry in two corrosion conditions. Cr‐rich compounds are primarily formed on the coupons surface of two corrosion conditions. The schematic models of corrosion mechanism in vapor‐saturated H2S/CO2 condition and H2S/CO2‐saturated brine condition are proposed based on experimental results.

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“…However, traces of CO 2 and H 2 S gas appeared in the production‐well when polymer flooding was implemented. Normally, dry CO 2 and H 2 S gases are not corrosive . But once they are dissolved in the production fluid of the formation water, the two gases become acidic .…”

Section: Introductionmentioning

confidence: 99%

Role of polyacrylamide concentration on corrosion behavior of N80 steel in the HPAM/H₂S/CO₂ environment

Dong

Zeng

et al. 2019

Materials & Corrosion

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The effect of polyacrylamide on corrosion behavior of N80 steel in the HPAM/H2S/CO2 environment was studied by using weight‐loss and electrochemical tests to simulate the environment of production wells in polymer flooding. The morphology and composition of corrosion scales were studied by scanning electron microscopy, energy dispersive X‐ray spectrometer, and X‐ray photoelectron spectroscopy. The results show that as the polyacrylamide concentration increases, the uniform corrosion rate of N80 steel decreases gradually. The safe service life of N80 steel grows along with the increase of the concentration of polyacrylamide. The corrosion scales of N80 steel in the HPAM/H2S/CO2 environment is split into two layers, an inner layer of O‐rich composed of FeCO3 and an outer layer of S‐rich consisting of FeS. Polyacrylamide adsorbs on the surface of N80 steel to form a protective network, which blocks contact between the metal and the solution and then inhibits the anodic dissolution of the metal. Moreover, the growth of polyacrylamide concentration increases the pH value of the solution and promotes the ionization of H2S, HS−, and H2CO3 in the solution.

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Effect of H2S on the Corrosion Behavior of Pipeline Steels in Supercritical and Liquid CO2 Environments

Cited by 26 publications

References 17 publications

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Corrosion mechanism of low‐alloy steel used for flexible pipe in vapor‐saturated H₂S/CO₂ and H₂S/CO₂‐saturated brine conditions

Role of polyacrylamide concentration on corrosion behavior of N80 steel in the HPAM/H₂S/CO₂ environment

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Effect of H2S on the Corrosion Behavior of Pipeline Steels in Supercritical and Liquid CO2 Environments

Cited by 26 publications

References 17 publications

Internal corrosion of carbon steel pipelines for dense-phase CO2transport in carbon capture and storage (CCS) – a review

Internal corrosion of carbon steel pipelines for dense-phase CO2transport in carbon capture and storage (CCS) – a review

Corrosion mechanism of low‐alloy steel used for flexible pipe in vapor‐saturated H2S/CO2 and H2S/CO2‐saturated brine conditions

Role of polyacrylamide concentration on corrosion behavior of N80 steel in the HPAM/H2S/CO2 environment

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Product

Resources

About

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Internal corrosion of carbon steel pipelines for dense-phase CO₂transport in carbon capture and storage (CCS) – a review

Corrosion mechanism of low‐alloy steel used for flexible pipe in vapor‐saturated H₂S/CO₂ and H₂S/CO₂‐saturated brine conditions

Role of polyacrylamide concentration on corrosion behavior of N80 steel in the HPAM/H₂S/CO₂ environment