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Corrosion And Stress Corrosion Cracking Behavior Of Super 13Cr Martensite Stainless Steel In CO2-Saturated High Temperature And High Pressure (HT/HP) Downhole Environments

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Corrosion is one of the major issues in oil and gas production, as well as geothermal energy due to the aggressive environments, such as high temperatures and pressures.1, 2 Material selection for downhole tubing is therefore paramount importance to ensure well integrity. Thus, the selected materials must be corrosion resistant, cost-effective, reliable, and have the required strength for such arduous conditions.

Product Number: 51322-17559-SG
Author: Zezhou Wen, Richard Barker, Jiong Qian, Anne Neville, Qiang Zhong, Yong Hua, Chun Wang
Publication Date: 2022
Industries: Corrosion Monitoring and Control , Coatings
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The service environments in deep/ultra-deep oilfields are particularly corrosive due to the high temperatures, chloride contents and CO2 partial pressures, which pose significant challenges to the integrity of tubing materials. In this research, we investigate the corrosion and stress corrosion cracking behavior of Super 13Cr martensitic stainless steel (S13Cr MSS) exposed to formation brine at 200°C with a 5.2 MPa CO2 partial pressure through immersion tests and slow strain rate (SSR) tests. The corrosion products composed of amorphous Cr(OH)3 and Cr2O3 were identified, which acted as a barrier to slow down the corrosion process at the material interface. The general corrosion rate of S13Cr MSS in a simulated downhole environment was 1.70 mm/y in the first 5 hours then decreased to 1.37 mm/y after 20 hours immersion and the general corrosion rate of 1.04 mm/year was recorded over 7 days exposure. Meanwhile, the pitting rate was high (2.27 mm/year) and the corresponding pit depth was 1.30 μm after 5 hours of exposure. After 7 days, the pitting rate was reduced to 0.37 mm/y. The results of SSR tests indicate that the fractures of S13Cr MSS initiated from the pits and were characteristic of ductile behavior at 200°C. Moreover, the stress corrosion cracking susceptibility of S13Cr MSS increased for the pre-corroded sample, suggesting that the increase in the level of stress concentration is due to the decrease in radius to depth ratio of pits during the corrosion progress. 

The service environments in deep/ultra-deep oilfields are particularly corrosive due to the high temperatures, chloride contents and CO2 partial pressures, which pose significant challenges to the integrity of tubing materials. In this research, we investigate the corrosion and stress corrosion cracking behavior of Super 13Cr martensitic stainless steel (S13Cr MSS) exposed to formation brine at 200°C with a 5.2 MPa CO2 partial pressure through immersion tests and slow strain rate (SSR) tests. The corrosion products composed of amorphous Cr(OH)3 and Cr2O3 were identified, which acted as a barrier to slow down the corrosion process at the material interface. The general corrosion rate of S13Cr MSS in a simulated downhole environment was 1.70 mm/y in the first 5 hours then decreased to 1.37 mm/y after 20 hours immersion and the general corrosion rate of 1.04 mm/year was recorded over 7 days exposure. Meanwhile, the pitting rate was high (2.27 mm/year) and the corresponding pit depth was 1.30 μm after 5 hours of exposure. After 7 days, the pitting rate was reduced to 0.37 mm/y. The results of SSR tests indicate that the fractures of S13Cr MSS initiated from the pits and were characteristic of ductile behavior at 200°C. Moreover, the stress corrosion cracking susceptibility of S13Cr MSS increased for the pre-corroded sample, suggesting that the increase in the level of stress concentration is due to the decrease in radius to depth ratio of pits during the corrosion progress. 

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Product Number: 51322-17580-SG
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Corrosion Control In Water Injection Pipelines

Product Number: 51322-17692-SG
Author: Jonathan Marsh
Publication Date: 2022
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Dubai Petroleum (the Operator) operates five offshore oil fields in the Emirate of Dubai (Fateh, South West Fateh, Falah, Jallilah and Rashid), in addition to various onshore gas production, storage, distribution and import facilities, and LNG import facilities. The assets within these offshore fields consist of approximately 80 platforms of various sizes, comprising central bridge linked processing facilities in Fateh and South West Fateh, and outlying normally unmanned wellhead production platforms. These platforms are linked by a network of over 150 subsea pipelines, of which over 30 are presently operational sea water injection pipelines.
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