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Corrosion Behavior of Martensite-Based Stainless Steels in Chloride Solutions Saturated with CO2 Containing Impurity Gases

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Carbon Capture and Storage (CCS) is a countermeasure for the global warming issue, and the number of CCS projects has increased. One type of CCS is Enhanced Oil Recovery (EOR), in which CO2 is injected into oil or natural gas reservoirs. Because formation water, which usually has a high concentration of chloride, exists at the bottom of these reservoirs, the injection tubing will suffer corrosion when the formation water flows back to the tubing. Stainless steels have been applied as tubing materials for Oil Country Tubular Goods (OCTG), and showed excellent corrosion resistance under high temperature and high CO2 pressure conditions. Martensite-based stainless steels bearing 13 mass% Cr to 17 mass% Cr are one of these tubing materials and are also expected to be used in CO2 injection tubing.

Product Number: 51323-18908-SG
Author: Yuichi Kamo, Kenichiro Eguchi, Hiroyuki Takai
Publication Date: 2023
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$20.00
$20.00

In Carbon Capture and Storage (CCS), CO2 is gathered from various CO2 emitters and injected into underground storage sites. The captured CO2 contains impurity species such as O2, SOx and NOx, and the injection tubing will be in contact with formation water, which has a high concentration of chlorine. CO2 corrosion is a primary concern in the selection of the tubing material. Although martensite-based stainless steels are candidate tubing materials, few reports have examined their corrosion behavior in the presence of high pressure CO2, and especially CO2 that contains impurity components. In this document, the corrosion behavior of steels containing 13 % Cr to 17 % Cr was investigated. The corrosion rates of the 13CR steel were higher than the acceptance criterion of 0.127 mm/y, and pitting occurred under most test conditions. The Modified 13CR series showed lower corrosion rates than 13CR. Their corrosion rates were lower than 0.127 mm/y, and the steels were free from pitting under most test conditions. Even under some test conditions in which Mod. 13CR steels suffered pitting, the 15CR and 17CR steels were free from pitting and their corrosion rates were lower than 0.127 mm/y, indicating that 15CR and 17CR have superior corrosion resistance. Martensitic stainless steels can be considered viable candidate materials for injection tubing for CCS, and 15CR and 17CR steels have better corrosion resistance and would be applicable under severer corrosive conditions.

In Carbon Capture and Storage (CCS), CO2 is gathered from various CO2 emitters and injected into underground storage sites. The captured CO2 contains impurity species such as O2, SOx and NOx, and the injection tubing will be in contact with formation water, which has a high concentration of chlorine. CO2 corrosion is a primary concern in the selection of the tubing material. Although martensite-based stainless steels are candidate tubing materials, few reports have examined their corrosion behavior in the presence of high pressure CO2, and especially CO2 that contains impurity components. In this document, the corrosion behavior of steels containing 13 % Cr to 17 % Cr was investigated. The corrosion rates of the 13CR steel were higher than the acceptance criterion of 0.127 mm/y, and pitting occurred under most test conditions. The Modified 13CR series showed lower corrosion rates than 13CR. Their corrosion rates were lower than 0.127 mm/y, and the steels were free from pitting under most test conditions. Even under some test conditions in which Mod. 13CR steels suffered pitting, the 15CR and 17CR steels were free from pitting and their corrosion rates were lower than 0.127 mm/y, indicating that 15CR and 17CR have superior corrosion resistance. Martensitic stainless steels can be considered viable candidate materials for injection tubing for CCS, and 15CR and 17CR steels have better corrosion resistance and would be applicable under severer corrosive conditions.

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Corrosion testing of CRA in simulated CO2 injection well environments

Product Number: 51323-18993-SG
Author: Gaute Svenningsen, Bjørn Helge Morland
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The number of CCS projects (planned and in operation) is increasing, and project developers need to provide firm evidence that the proposed material is suitable for these applications.
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Corrosion Resistance Evaluation Of Super Duplex Stainless Steel In Supercritical CO2 Saturated Liquid Phase Containing Impurities O2 Or SO2

Product Number: 51322-17602-SG
Author: Daisuke Matsuo, Masayuki Sagara, Yuji Arai, Hisashi Amaya, Kyohei Kanki
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Carbon capture, utilization and storage (CCUS) is one of the key technologies to achieve the net-zero emission. One of the CCUS method is CO2 injection to depleted oil and gas wells or aquifers and storage (CCS). The CO2 emitted from fossil fuel-based powers and industrial plants are captured and transported to the injection point by ships or pipe line. Following that, the dense phase or supercritical phase CO2 will be injected to depleted oil and gas wells or aquifers through oil country tubular goods, for examples, seamless pipe.
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