Corrosion Behavior of API 5L X65 Carbon Steel Under Supercritical and Liquid Carbon Dioxide Phases in the Presence of Water and Sulfur Dioxide

Farelas, Fernando; Choi, Yo Han; Nešić, Srdjan

doi:10.5006/0739

Cited by 57 publications

(38 citation statements)

References 8 publications

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“…[4] This observation is attributed to the ability of O2 to react with SO2 and water to produce sulphuric acid (H2SO4), as will be discussed later. [27] and Farelas et al [86] could be regarded as being very high when compared with the proposed impurity limits outlined by the DYNAMIS project and Alstom in Table 4, which suggest a lower limit of 100 ppm.…”

Section: Anticipated Corrosion Rates In Co2-h2o-so2-o2 Environmentsmentioning

confidence: 99%

“…Investigators have shown that increasing SO2 concentration in dense phase CO2 results in an increase in general corrosion rate [4,83,86] and can also promote localised corrosion under FeSO3/FeSO4 deposits. [76] Some authors have also demonstrated a noticeable synergy existing between SO2 and O2 which results in the synergistic corrosion rate being greater than the sum of the individual corrosion rates from the presence of SO2 and O2 individually.…”

Section: Anticipated Corrosion Rates In Co2-h2o-so2-o2 Environmentsmentioning

confidence: 99%

See 1 more Smart Citation

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

131

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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: Anticipated Corrosion Rates In Co2-h2o-so2-o2 Environmentsmentioning

confidence: 99%

Section: Anticipated Corrosion Rates In Co2-h2o-so2-o2 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

131

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“…Both the work presented in this publication and the results of Farelas et. al., 12 indicate that mass loss results can be misrepresentative in terms of the threat posed to carbon steel exposed to impurity containing dense phase CO 2 .…”

Section: Corrosion Product Morphology and Compositionmentioning

confidence: 99%

“…These results, to a certain extent, are in alignment with the observation of Farelas et. al., 12 who performed experiments in liquid CO 2 at 25°C and 8 MPa in under-saturated containing 650 ppm water and identified that localized corrosion rates are significant in such systems. Mass loss measurements after 24 hours of exposure revealed general corrosion rates of 0 and 0.1 mm/year in the presence of 0.05 and 0.1% SO 2 , respectively.…”

Section: Corrosion Product Morphology and Compositionmentioning

confidence: 99%

Understanding the Influence of SO₂and O₂on the Corrosion of Carbon Steel in Water-Saturated Supercritical CO₂

Hua¹,

Barker²,

Neville³

2015

CORROSION

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The general and localized corrosion behaviour of carbon steel (UNS G15130) in water-saturated supercritical CO 2 conditions containing O 2 and SO 2 at 35°C and 8 MPa is evaluated with a view to the effect this may have on pipeline integrity during dense-phase CO 2 transport. The results indicate that crystalline FeCO 3 forms in the presence of solely water and CO 2 . However, the combined introduction of small concentrations of O 2 and SO 2 (as low as 20 and 2 ppm (mole), respectively) change FeCO 3 crystal morphology. Increasing the concentration of SO 2 to 50 and 100 ppm whilst maintaining O 2 content at 20 ppm resulted in the formation of FeSO 3 ·3H 2 O as well as FeCO 3 . In conjunction with the change in corrosion product chemistry and morphology, general corrosion rates of samples increased from 0.1 mm/year to 0.7 mm/year as a result of the rise in SO 2 content from 0 to 100 ppm (based on 48 hour experiments), whilst localized corrosion rates (determined from surface profilometry) rose from 0.9 to 1.7 mm/year. The research demonstrates that localized corrosion measurements are a fundamental requirement when determining the threat posed to carbon steel pipelines during dense-phase CO 2 transport, exceeding the uniform corrosion rate by nearly one order of magnitude under certain conditions. Additional tests involving solution replenishment over 48 hours indicated that the higher corrosion rates observed in the presence of SO 2 did not present the worst case scenario corrosion rates and highlight the importance of having a system where the process fluid is continuously replenished. The corrosion product morphology and chemistry was identified through a combination of scanning electron microscopy (SEM), energy-dispersive X-ray spectroscopy (EDX) and X-ray diffraction (XRD).

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“…The distribution of these components between the aqueous (brine) and CO 2 -rich phase and the interplay between solvation and confinement phenomena at solid-fluid interfaces are complex coupled processes [37]. Some aspects of the reactivity of acid gases have been investigated, such as alteration of well-bore cements by brines containing significant amounts of CO 2 and H 2 S [38,39] and corrosion of steel by CO 2 containing H 2 O and SO 2 [40]. However, current experimental data and molecularlevel simulations of these multi-component systems are insufficient for predicting fluidrock interactions in the bulk and confined CO 2 -rich phase.…”

Section: Acids In Binary and Multi-component Co 2 -Rich Fluidsmentioning

confidence: 99%

Conductivity Measurements on H2O-Bearing CO2-Rich Fluids

et al. 2014

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Recent studies report rapid corrosion of metals and carbonation of minerals in contact with carbon dioxide containing trace amounts of dissolved water. One explanation for this behavior is that addition of small amounts of H 2 O to CO 2 leads to significant ionization within the fluid, thus promoting reactions at the fluid-solid interface analogous to corrosion associated with aqueous fluids. The extent of ionization in the bulk CO 2 fluid was determined using a flow-through conductivity cell capable of detecting very low conductivities. Experiments were conducted from 298 to 473 K and 7.39 to 20 MPa with H 2 O concentrations up to *1,600 ppmw (mole fraction of water, x H 2 O &3.9 9 10 -3 ), corresponding to the H 2 O solubility limit in liquid CO 2 at ambient temperature. All solutions showed conductivities \10 nSÁcm -1 , indicating that the bulk solutions were essentially ion-free. This observation suggests that the observed corrosion and carbonation reactions are not the result of ionization in CO 2 -rich bulk phase, but does not preclude ionization in the fluid at the fluid-solid interface.

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Corrosion Behavior of API 5L X65 Carbon Steel Under Supercritical and Liquid Carbon Dioxide Phases in the Presence of Water and Sulfur Dioxide

Cited by 57 publications

References 8 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

Understanding the Influence of SO₂and O₂on the Corrosion of Carbon Steel in Water-Saturated Supercritical CO₂

Conductivity Measurements on H2O-Bearing CO2-Rich Fluids

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Corrosion Behavior of API 5L X65 Carbon Steel Under Supercritical and Liquid Carbon Dioxide Phases in the Presence of Water and Sulfur Dioxide

Cited by 57 publications

References 8 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

Understanding the Influence of SO2and O2on the Corrosion of Carbon Steel in Water-Saturated Supercritical CO2

Conductivity Measurements on H2O-Bearing CO2-Rich Fluids

Contact Info

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

Understanding the Influence of SO₂and O₂on the Corrosion of Carbon Steel in Water-Saturated Supercritical CO₂