Corrosion behavior of SM 80SS tube steel in stimulant solution containing H2S and CO2

Yin, Z. F.; Zhao, Wanhua; Bai, Zhongxiang; Feng, Yaorong; Zhou, Wentao

doi:10.1016/j.electacta.2007.12.039

Cited by 120 publications

(58 citation statements)

References 14 publications

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“…A representative microstructure of the target steel is shown in Figure 1. sulfide on the steel surface during the sour corrosion process can be either protective or non-protective [12,13]. It has been reported that the formed corrosion product layer during the corrosion of API X52 is significantly composed of iron sulfide and various oxides, which enhance the protective properties of the film [4].…”

Section: Materials Preparationmentioning

confidence: 99%

Corrosion Behavior of API X100 Steel Material in a Hydrogen Sulfide Environment

Okonkwo

Shakoor

Benamor

et al. 2017

Metals

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Abstract:Recently, the API X100 steel has emerged as an important pipeline material for transportation of crude oil and natural gas. At the same time, the presence of significant amounts of hydrogen sulfide (H 2 S) in natural gas and crude oil cause pipeline materials to corrode, which affects their integrity. In this study, the effect of H 2 S concentration on the corrosion behavior of API X100 in 3.5% NaCl solution is presented. The H 2 S gas was bubbled into saline solutions for different durations, and the corrosion tests were then performed using potentiodynamic polarization and electrochemical impedance spectroscopy (EIS). X-ray photoelectron spectroscopy (XPS), X-ray diffraction (XRD), atomic force microscopy (AFM), and scanning electron microscopy (SEM) techniques were used to characterize the corroded surface. The results indicate that the corrosion rate of API X100 steel decreases with increasing H 2 S bubbling time due to the increase in H 2 S concentration in 3.5% NaCl solutions. It is noticed that an accumulation of a critical amount of hydrogen in the metal can result in hydrogen-induced crack initiation and propagation. It was further observed that, when the stress limit of a crystalline layer is exceeded, micro-cracking of the formed protective sulfide layer (mackinawite) occurs on the API X100 steel surface, which may affect the reliability of the pipeline system.

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Section: Materials Preparationmentioning

confidence: 99%

Corrosion Behavior of API X100 Steel Material in a Hydrogen Sulfide Environment

Okonkwo

Shakoor

Benamor

et al. 2017

Metals

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“…The energy dispersive spectroscopy (EDS) map indicated O-rich products inside the circle, implying that the main corrosion products were Fe 2 O 3 and FeOOH. C and S were identified at the margin of products, which could be from FeCO 3 [26][27][28] and FeS [29][30][31]. Therefore, CO 2 corrosion and H 2 S corrosion also occurred in the downhole environment as the following equations.…”

Section: Corrosion Morphologiesmentioning

confidence: 99%

Corrosion behavior of the expandable tubular in formation water

Gao

Dong

et al. 2015

Int J Miner Metall Mater

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Abstract:The corrosion behavior of expandable tubular materials was investigated in simulated downhole formation water environments using a series of electrochemical techniques. The corrosion morphologies in the real downhole environment after three months of application were also observed by stereology microscopy and scanning electron microscopy (SEM). The results show that, compared with the unexpanded sample, the area of ferrite increases dramatically after a 7.09% expansion. The expanded material shows a higher corrosion current in the polarization curve and a lower corrosion resistance in the electrochemical impedance spectroscopy (EIS) plot at every studied temperature. The determined critical pitting temperatures (CPT) before and after expansion are 87.5°C and 79.2°C, respectively. SEM observations demonstrate stress corrosion cracks, and CO 2 corrosion and H 2 S corrosion also occur in the downhole environment. Due to additional defects generated during the plastic deformation, the corrosion performance of the expanded tubing deteriorates.

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“…Repeated major failures caused by FAC still occur frequently, as they did in the 1980s and 1990s (Dooley, 2008). While a number of studies have been conducted on FAC in CO 2 environments with carbon steels and alloys using different applications and control measures (Barker, Hu, Neville, & Cushnaghan, 2012;Nesic, 2012;Yin, Zhao, Bai, Feng, & Zhou, 2008), there are no detailed reports about FAC in CSG pipeline infrastructure and counter measures in both single and multiphase flow conditions. The research undertaken here investigates the influence of water chemistry, hydrodynamic and material factors on FAC of carbon steel in CSG-a high bicarbonate brine environment.…”

Section: Statement Of Original Authorshipmentioning

confidence: 99%

“…On the other hand, Avendano-Castro et al (2009) examined the corrosion rate of a carbon steel pipeline weld in aqueous brine solution containing H 2 S, and found that the corrosion rate increased as temperature increased. Research on corrosion behaviour of SM80SS tube steel in a simulated solution containing CO 2 and H 2 S by Yin, et al (2008) showed that the corrosion rate increased from 40℃ to 100℃ and decreased significantly at 150℃ under FAC. They further explained that the effect of temperature depends on whether the solubility of the salt forming the protective oxide is exceeded or not.…”

Section: Temperaturementioning

confidence: 99%

“…The widely used expression for mass loss is mg/dm²/day (mdd) and mils penetration per year (mpy). Yin, et al (2008) and Kondo, et al (2011) both used weight loss tests to determine corrosion rate. The samples are weighed before and after immersion tests and the corrosion rate can be calculated in mm/yr, according to equation …”

Section: Corrosion Rate Measurement By Weight Lossmentioning

confidence: 99%

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Flow-Assisted Corrosion in Coal Seam Gas Infrastructure

Eyu¹

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Corrosion behavior of SM 80SS tube steel in stimulant solution containing H2S and CO2

Cited by 120 publications

References 14 publications

Corrosion Behavior of API X100 Steel Material in a Hydrogen Sulfide Environment

Corrosion Behavior of API X100 Steel Material in a Hydrogen Sulfide Environment

Corrosion behavior of the expandable tubular in formation water

Flow-Assisted Corrosion in Coal Seam Gas Infrastructure

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