The development of a mechanistic-chemometrics model with multi-degree of freedom for pitting corrosion of HP-13Cr stainless steel under extremely oilfield environments

Zhang, Xiaochen; Hua, Yong; Liu, Bin; Li, Xuanpeng; Xie, Junfeng; Zeng, Guanxin; Zhang, Tao; Wang, Fuhui

doi:10.1016/j.corsci.2021.109237

Cited by 16 publications

(2 citation statements)

References 60 publications

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“…Hakon (Leth-Olsen, 2004) found that the formation of the corrosion product scales on 13Cr SS in formate fluids did not act as an effective barrier against corrosion, showing high-corrosion rates after several weeks of exposure, and the surface was covered by nonuniformed crystalline FeCO 3 , especially at 180 °C (Leth-Olsen and others, 2005). Although the formation of the FeCO 3 layer plays a dominant role in retarding the corrosion rate, the corrosion resistance of S13Cr SS corresponds to a complicated corrosion product scales formation and evolution process, and that the amorphous/nanocrystalline inner layer provides better corrosion protection than outer FeCO 3 precipitation [21][22][23][24][25] under the ultradeep well conditions [temperatures beyond 180 °C (Zhao et al, 2018;Yue et al, 2020aYue et al, , 2020bYue et al, , 2020cZhao et al, 2021a)]. The systematic study on the formation and evolution of the corrosion product scales on the S13Cr SS surface immersed in a formate fluid under HTHP condition, especially with the presence of aggressive substances such as sulfide or CO 2 is rare.…”

Section: Introductionmentioning

confidence: 99%

Formation and Evolution of the Corrosion Scales on Super 13Cr Stainless Steel in a Formate Completion Fluid With Aggressive Substances

Yue

Huang

et al. 2022

Front. Mater.

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The formation and evolution of the corrosion scales on the super 13Cr stainless steel (SS) surface after exposure in a formate completion fluid with the presence of various aggressive substances was investigated. The results indicate that the formation of Fe3O4 covered the surface of super 13Cr SS as the inner layer accompanied with outer scattered FeS. The corrosion rate was below 0.07 mm/year after 120 h of exposure in the formate fluid at 180°C under N2 environments; the presence of aggressive substances such as sulfide and CO2 in the formate fluid promoted the proceeding of anodic dissolution in the early period, and the ingress of CO2 progressively increased the general corrosion rate to 1.7 mm/year. For CO2-containing conditions, the formation of FeCr2O4 and Cr(OH)3 was detected in the inner corrosion product layers, and the precipitation of “sheet”-shaped iron carbonate (FeCO3) was detected as the outer layer. The accumulation rate of corrosion products increases by two orders of magnitude with the ingress of CO2, corresponding to thicker corrosion products, but the dissolution rate is still three orders of magnitude higher than when CO2 was absent.

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Section: Introductionmentioning

confidence: 99%

Formation and Evolution of the Corrosion Scales on Super 13Cr Stainless Steel in a Formate Completion Fluid With Aggressive Substances

Yue

Huang

et al. 2022

Front. Mater.

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“…Pitting Corrosion of T95 Steel in Liquid PhaseIn the liquid phase, CO 2 and H 2 S dissolve in the solution to produce the corrosive ions, including HS − , S 2− , CO 3 2−, and HCO 3 − ions[36,37]. The cathodic and anodic reactions in the solution are as follows[38].…”

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How to Choose the Suitable Steel of Wellhead, Wellbore, and Downhole Tools for Acid Gas Reinjection Flooding

et al. 2022

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The material selection of injection gas wells in acid gas flooding is the bottleneck of the successful implementation of the technical scheme. Through standard and literature research, the materials of the wellhead, wellbore, and packer for reinjection well in acid gas flooding are preliminarily established, and then the suitable materials are further screened by using the weight-loss and surface characterization method. Finally, a new type of packer is designed to optimize the wellbore material. The results show that 35CrMo (CR = 0.0589 mm/y) steel is used for wellhead materials, 625 alloy steel is selected as the sealing surface, and 625 or 825 alloys (with CR ≤ 0.0055 mm/y) steel is used for wellhead sealing material. The main material of the packer is 718 Alloy (with CR ≤ 0.0021 mm/y). The cost of T95 steel within 20 years (1263 ten thousand yuan) of service is much smaller than that of G3 alloy (1771 ten thousand yuan), but after 30 years of service, its cost is close to that of G3 alloy. A kind of downhole packer for acid gas reinjection is designed. Among them, G3 alloy steel tubing is used between the packer and the relief valve, T95 steel tubing is selected above the packer and below the safety valve, and the packer is set in the G3 steel tubing. The serious pitting corrosion of T95 steel in the liquid phase environment is due to the uneven deposition of FeS and FeCO3 on the steel surface.

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The Effects of Chloride Ion Concentration on the Pitting Behavior of 309L Cladding by Using Micro-Electrochemical Measurement and In Situ Optical Observation

Zhang

Guo

et al. 2021

J. of Materi Eng and Perform

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The development of a mechanistic-chemometrics model with multi-degree of freedom for pitting corrosion of HP-13Cr stainless steel under extremely oilfield environments

Cited by 16 publications

References 60 publications

Formation and Evolution of the Corrosion Scales on Super 13Cr Stainless Steel in a Formate Completion Fluid With Aggressive Substances

Formation and Evolution of the Corrosion Scales on Super 13Cr Stainless Steel in a Formate Completion Fluid With Aggressive Substances

How to Choose the Suitable Steel of Wellhead, Wellbore, and Downhole Tools for Acid Gas Reinjection Flooding

The Effects of Chloride Ion Concentration on the Pitting Behavior of 309L Cladding by Using Micro-Electrochemical Measurement and In Situ Optical Observation

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