A direct measurement of wall shear stress in multiphase flow—Is it an important parameter in CO 2 corrosion of carbon steel pipelines?

Li, Wei; Pots, Bernardus F.M.; Brown, Bruce; Kee, Kok Eng; Nešić, Srdjan

doi:10.1016/j.corsci.2016.04.008

Cited by 87 publications

(49 citation statements)

References 33 publications

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“…The detailed description of the thin channel flow cell (TCFC) used in the present study can be found in earlier publications. [29][30][31][32][33] In the present study, the test section was slightly modified by introducing a saturated Ag/AgCl reference electrode, flush mounted on the lid, directly opposite to the working electrode, as shown in Figure 1. The cell structure was used as the counter electrode.…”

Section: The Thin Channel Flow Cellmentioning

confidence: 99%

Technical Note: Electrochemistry of CO2 Corrosion of Mild Steel: Effect of CO2 on Cathodic Currents

2018

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The common understanding of aqueous CO 2 corrosion mechanism considers carbonic acid as an electroactive species. The direct reduction of carbonic acid on a steel surface is believed to be the cause of the higher corrosion rates of mild steel, as compared to that observed in strong-acid solutions with the same pH. However, in-depth quantitative analyses based on comprehensive mechanistic models, developed in recent years, have challenged this idea. In an attempt to provide explicit experimental evidence for the significance of direct reduction of carbonic acid in CO 2 corrosion of mild steel, the charge transfer controlled cathodic currents in CO 2 saturated solutions were investigated in the present study. The experiments were conducted on three different surfaces: Type 316L stainless steel, pure iron, and API 5L X65 mild steel, in order to examine the possible effect of alloying impurities on the kinetics and the mechanism of cathodic currents. The experimental polarization curves showed that at a constant pH, the charge transfer controlled cathodic currents did not increase with increasing partial pressure of CO 2 from 0 bar to 5 bar. This confirmed that the direct carbonic acid reduction was not significant at the conditions covered in the present study, and its sole effect was to buffer the hydrogen ion concentration.

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Section: The Thin Channel Flow Cellmentioning

confidence: 99%

Technical Note: Electrochemistry of CO2 Corrosion of Mild Steel: Effect of CO2 on Cathodic Currents

2018

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“…The tensile tests was conducted to measure the adhesion strength between the iron carbonate layer and the steel substrate, and the results were reported to be in excess of MPa [2,3]. In addition, the wall shear stress in gas-liquid flow typically seen in multiphase flow pipelines was measured directly by employing a loading element wall probe [4,5]. It was found that the wall shear stress arising from atmospheric flow was of the order of 10 2 Pa, which was not sufficient to dam-age iron carbonate layer.…”

Section: Introductionmentioning

confidence: 99%

Numerical simulation of carbon dioxide corrosion under flow conditions in an elbow

Chen

Wang

et al. 2019

Materialwissenschaft Werkst

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A computational fluid dynamics (CFD)‐based method combined with water chemistry and electrochemical reaction calculation is developed to investigate the effect of fluid flow on carbon dioxide corrosion in an elbow. The mass transfer of reactants and products influenced by flow during corrosion is revealed visually by distribution of main species concentration. The results show that the distributions of main species concentration and corrosion rate on the bare steel surface are in good accordance with the distribution of flow velocity. The maximum corrosion rate appears at the entrance on inner side wall of the elbow, and the corrosion rate decreases along the flow direction. Near the exit of the elbow, the secondary flow arises and enhances the mass transfer as well as the corrosion rate. According to the saturation value, the iron carbonate is more likely to precipitate at the inner side wall near the exit of the elbow. The model is validated by the good agreement between simulation results and published experimental data in prediction of hazardous corrosion region and the regional corrosion rate of the elbow.

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“…It was found that a higher slug frequency may increase the corrosion rate of pipelines, owing to a sharp increase in the local wall shear stress (Yang et al, 2010), which was viewed as an important parameter in corrosion (Wang et al, 2002;Zheng et al, 2008). A higher shear stress may enhance the local corrosion kinetics or damage the corrosion products (Schmitt et al, 2000;Li et al, 2016). It was also observed that a higher gas flow rate could reduce the pressure drop and lower the frequency of liquid slugs at a constant liquid velocity (Kang et al, 1999;Villarreal et al, 2006;Wang et al, 2015), thus reducing the corrosion risk.…”

Section: Oil-water-gas/solid Flowmentioning

confidence: 99%

“…The presence of crude oil in the CO 2 -EOR production system may poison the inhibitors (Gulbrandsen and Kvarekval, 2007;Horsup et al, 2010), reducing their effectiveness. Therefore, the evaluation of corrosion inhibitors in oil-water mixed fluids becomes critical for the practical inhibitor selection (Li et al, 2014(Li et al, , 2016Wang et al, 2019b). Presently, there is still lack of effective and applicable methods for the evaluation of corrosion inhibitors in oil-water mixed conditions (ASTM G202−12, 2016), which generally relies on a large-scale multiphase flow loop test (Salama and Brown, 2009;Cai et al, 2012;Wang and Zhang, 2016).…”

Section: Control Strategiesmentioning

confidence: 99%

Corrosion Control in CO2 Enhanced Oil Recovery From a Perspective of Multiphase Fluids

2019

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Carbon capture and storage (CCS) combined with CO 2-enhanced oil recovery (EOR), has been recently viewed as an economical and effective method for the reduction of carbon emissions. However, corrosion is a challenging issue in the whole chain process of CO 2-EOR production if water presents and mild steel pipeline is used. In this paper, the corrosion risk of pipeline at different stages of CO 2-EOR production is systematically assessed based on a detailed analysis of the fluid characteristics. According to the fluid state of CO 2 , water and crude oil, current understandings on the corrosion behavior of steel materials in multiphase flow conditions are reviewed. Furthermore, the intermittent water wetting phenomena and the fluid behavior of water droplets or clusters in an electrolyte/non-electrolyte emulsion are correlated with the steel corrosion performance, providing new insights into the corrosion phenomena. Besides application of corrosion resistant materials and corrosion inhibitors, tailoring of processing parameters, such as enhancing the water entrainment, shortening the water contact time, and reducing the solution corrosivity, is highly recommended as an effective method for corrosion control in aggressive CO 2-EOR production conditions. Based on these, some important future research topics on the corrosion in multiphase fluids are suggested.

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A direct measurement of wall shear stress in multiphase flow—Is it an important parameter in CO 2 corrosion of carbon steel pipelines?

Cited by 87 publications

References 33 publications

Technical Note: Electrochemistry of CO2 Corrosion of Mild Steel: Effect of CO2 on Cathodic Currents

Technical Note: Electrochemistry of CO2 Corrosion of Mild Steel: Effect of CO2 on Cathodic Currents

Numerical simulation of carbon dioxide corrosion under flow conditions in an elbow

Corrosion Control in CO2 Enhanced Oil Recovery From a Perspective of Multiphase Fluids

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