Failure Analysis of the Crack and Leakage of a Crude Oil Pipeline under CO2-Steam Flooding

Song, Chengli; Li, Yuanpeng; Wu, Fan; Luo, Jun; Li, Lifeng

doi:10.3390/pr11051567

Cited by 2 publications

(2 citation statements)

References 36 publications

(37 reference statements)

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“…Corrosion poses a serious threat, both externally and internally. External corrosion can result from factors such as oxygen and chloride in the external environment [6]. In contrast, internal corrosion may stem from substances such as hydrogen sulfide (H 2 S), carbon dioxide (CO 2 ), and organic acids present in the production fluid.…”

Section: Introductionmentioning

confidence: 99%

Addressing Hydrogen Sulfide Corrosion in Oil and Gas Industries: A Sustainable Perspective

Vakili,

Koutník,

Kohout

2024

Sustainability

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In the oil and gas industry, the corrosion attributed to hydrogen sulfide (H2S) is one of the most significant challenges. This review paper systematically investigates the diverse facets of H2S corrosion, including its sources, corrosion locations, mechanisms, and resultant corrosion products. Understanding different forms of H2S corrosion, such as stress-oriented hydrogen-induced cracking (SO-HIC), sulfide stress cracking (SSC), and hydrogen-induced cracking (HIC), provides a thorough comprehension of these phenomena. The paper discusses critical factors influencing H2S corrosion, such as temperature, flow rate, pH, and H2S concentration, highlighting their implications for sustainable practices in the oil and gas sector. The review emphasizes the significance of monitoring and mitigation strategies, covering continuous monitoring, applying corrosion inhibitors, selecting materials, and conducting thorough data analysis and reporting. Furthermore, the role of training in fostering a sustainable approach to H2S corrosion management is highlighted. This exploration advances the overarching goal of sustainable development in the oil and gas industries by providing insights into understanding, monitoring, and mitigating H2S corrosion. The findings presented here offer a foundation for developing environmentally conscious strategies and practices to guarantee the long-term viability and flexibility of refinery operations.

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Section: Introductionmentioning

confidence: 99%

Addressing Hydrogen Sulfide Corrosion in Oil and Gas Industries: A Sustainable Perspective

Vakili,

Koutník,

Kohout

2024

Sustainability

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“…Song et al [23] studied the impact of Cl − on the stress corrosion of cold-deformed 316 L austenitic stainless steel in an H 2 S environment and found that the stress corrosion sensitivity of metal increases with the increase in Cl − concentration. Song et al [24] established the stress corrosion model of stainless steel by carrying out a chloride stress corrosion cracking test. They found that the existence of stress makes the passive film surface in the stress concentration area richer in chloride ions, thereby reducing the thickness, integrity, and pitting resistance of the passive film, and that SCC is the most destructive of all corrosion types.…”

Section: Introductionmentioning

confidence: 99%

Study on Variable Stress Corrosion Susceptibility of Four Typical High-Strength Sucker Rods in High-Salinity Well Fluids

Zhang,

Li,

Zhu

et al. 2023

Processes

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To study the corrosion characteristics of high-strength sucker rods in high-salinity well fluids under alternating stresses, a single-factor stress corrosion test was designed. The slow strain rate tensile test (SSRT) was carried out for four kinds of high-strength sucker rods under different Cl− and HCO3− concentrations and with different service strengths, and the variable stress corrosion cracking susceptibility was analyzed. The results show that the elongation loss and absorbed work loss of the H-grade ultra-high-strength 4330 sucker rod after stress corrosion are greater than those of both the high-strength 4142 sucker rod and the high-strength 20CrMoA sucker rod. The elongation and absorbed work loss of the 30CrMoA and 20CrMoA sucker rods are less affected by the changes in Cl− and HCO3−. With the increase in use strength, the elongation and absorbed work loss of the high-strength sucker rod increase. The change in the surface of the sucker rod during the corrosion process is inconsistent with the actual elongation of the sucker rod and the absorbed work loss. It can be concluded that the stress corrosion cracking susceptibility of the sucker rod is not necessarily related to the tensile strength of the sucker rod. The 4330 sucker rod is not suitable for applications in wells with a high concentration of Cl−, but it is suitable for operation in alkaline conditions where corrosive media such as HCO3− and Cl− coexist. Under highly corrosive and highly mineralized conditions, the 30CrMoA sucker rod is less susceptible to stress corrosion. The stress corrosion cracking susceptibility of the 20CrMoA sucker rod is lower than that of the 4142 sucker rod. In high-salinity well fluids, the higher the use strength, the higher the stress corrosion cracking susceptibility of the high-strength sucker rod is. The test results for the weight-loss-based corrosion rate and plastic loss may contradict the determination of the corrosion susceptibility of the material under working conditions.

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Failure Analysis of the Crack and Leakage of a Crude Oil Pipeline under CO2-Steam Flooding

Cited by 2 publications

References 36 publications

Addressing Hydrogen Sulfide Corrosion in Oil and Gas Industries: A Sustainable Perspective

Addressing Hydrogen Sulfide Corrosion in Oil and Gas Industries: A Sustainable Perspective

Study on Variable Stress Corrosion Susceptibility of Four Typical High-Strength Sucker Rods in High-Salinity Well Fluids

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