Corrosion Behavior of Tubing in High-Salinity Formation Water Environment Containing H2S/CO2 in Yingzhong Block
Abstract
:1. Introduction
2. Experimental Procedure
2.1. Material and Solution
2.2. Weight Loss Tests
2.3. SCC Testing
2.4. Characterization
3. Results and Analysis
3.1. Average Corrosion Rate
3.2. Corrosion Morphology Characteristics
3.2.1. Macroscopic Corrosion Morphology under PH2S = 0.53 MPa
3.2.2. Micro-Corrosion Morphology When PH2S = 0.53 MPa
3.2.3. Microscopic Corrosion Morphology under PH2S = 0.28 MPa
3.3. SCC in H2S-Containing Environment
3.4. Discussion
3.4.1. Corrosion Mechanism
3.4.2. Stress Sensitivity Analysis
4. Conclusions
- (1)
- In the simulated formation water environment with a high salinity of 292 g/L and H2S/CO2 corrosion gas, the average corrosion rate of the P110SS material gradually increases as the temperature rises from 80 °C to 180 °C, and when PH2S = 0.53 MPa and PCO2 = 0.17 MPa, the corrosion rate of P110SS can reach up to 0.99 mm/a.
- (2)
- In both liquid and gas phase environments, the morphology of the corrosion product film on P110SS varies due to the different states of the material that are in contact with the corrosive medium. In a gas phase environment, a locally rough and spotty-shaped corrosion product film is formed as a result of varying degrees of aggregation in the liquid film.
- (3)
- When the simulated test temperature gradually increases from 80 °C to 180 °C with a PH2S: PCO2 ratio of 0.53:0.17, the P110SS material shows no sensitivity to SCC when loaded with stress at 85% YSmin. However, as the temperature increases, the material becomes more susceptible to pitting corrosion. At high temperatures (180 °C), pitting occurs, but does not lead to cracking or fracturing of the material.
- (4)
- When the simulated test temperature is ≥120 °C, the P110SS material experiences extremely severe corrosion, Therefore, it is recommended to take appropriate anti-corrosion measures when using P110SS in an environment with a temperature of ≥120 °C.
Author Contributions
Funding
Institutional Review Board Statement
Informed Consent Statement
Data Availability Statement
Conflicts of Interest
References
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Cl− | Mg2+ | Ca2+ | K+ | Na+ | SO42+ | HCO3− | PH | Salinity |
---|---|---|---|---|---|---|---|---|
186 | 0.035 | 0.11 | 7.05 | 104 | 24.3 | 1.07 | 6.28 | 292 |
Items | Test Temperature (°C) | H2S Content (MPa) | CO2 Content (MPa) | Total Pressure (MPa) | Test Period (h) |
---|---|---|---|---|---|
Parameters | 80 | 0.53 0.28 | 0.17 | 10 | 168 |
120 | |||||
180 |
Ambient Temperature Elements | 80 °C | 120 °C | 180 °C | |||
---|---|---|---|---|---|---|
Gas | Liquid | Gas | Liquid | Gas | Liquid | |
O Wt% | 7.12 | 8.82 | 8.69 | 9.86 | 9.29 | 8.48 |
S Wt% | 29.09 | 10.21 | 32.49 | 18.64 | 29.41 | 32.47 |
Fe Wt% | 63.79 | 80.09 | 58.82 | 73.49 | 59.77 | 59.06 |
Items | Temperature/°C | H2S Content (MPa) | CO2 Content (MPa) | Test Cycle/h | State | Applied Stress |
---|---|---|---|---|---|---|
Parameters | 80, 120, 180 | 0.53 | 0.17 | 720 | Liquid | 85%YSmin |
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Zhao, X.; Liu, J.; Yao, B.; Li, C.; Xia, X.; Fu, A. Corrosion Behavior of Tubing in High-Salinity Formation Water Environment Containing H2S/CO2 in Yingzhong Block. Coatings 2023, 13, 1342. https://doi.org/10.3390/coatings13081342
Zhao X, Liu J, Yao B, Li C, Xia X, Fu A. Corrosion Behavior of Tubing in High-Salinity Formation Water Environment Containing H2S/CO2 in Yingzhong Block. Coatings. 2023; 13(8):1342. https://doi.org/10.3390/coatings13081342
Chicago/Turabian StyleZhao, Xuehui, Junlin Liu, Baisheng Yao, Cheng Li, Xue Xia, and Anqing Fu. 2023. "Corrosion Behavior of Tubing in High-Salinity Formation Water Environment Containing H2S/CO2 in Yingzhong Block" Coatings 13, no. 8: 1342. https://doi.org/10.3390/coatings13081342