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Picture for Applicability of Martensite-Based Stainless Steels for CO2 Injection Tubing

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Applicability of Martensite-Based Stainless Steels for CO2 Injection Tubing

Product Number: 51324-20636-SG

Author: Yuichi Kamo; Kenichiro Eguchi; Hiroyasu Ebina; Hiroyuki Takai; Takamasa Kawai

Publication Date: 2024

$40.00

This paper discusses the risks to the integrity of tubing material used in Carbon Capture and Storage (CCS). One risk is the formation of condensed water at the wellhead, which can lead to corrosion. FEM analysis of the waterlcontaining CO2 flux in the well indicated that the risk of corrosion due to condensed water was very low. Another risk is cooling of the tubing by cold CO2 when the temperature of CO2 is drastically decreased by the JoulelThomson effect. A cooling experiment in which cold nitrogen gas was applied to a steel pipe showed that the temperature of the steel did not decrease to the temperature of the cold gas, indicating that the cooled area was limited to the surface of the steel. The Charpy impact test demonstrated that martensitelbased stainless steels have good lowltemperature toughness. Corrosion of the steel pipe at the bottom hole, where it comes into contact with formation water, is also a risk to the material integrity. Corrosion tests of the steels in SO2 and NO2 contaminated conditions showed that not only S25CR but also modified 13CR (Mod. 13CR), 15CR, 17CR steels have good corrosion resistance in terms of the corrosion rate, resistance to localized corrosion and resistance to SCC under the SO2 and NO2 contaminated conditions.

Picture for Corrosion of Stainless Steel Alloys in Fresh Water Simulating Condensed Water in Contact with Supercritical CO2- An Electrochemical Study

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Corrosion of Stainless Steel Alloys in Fresh Water Simulating Condensed Water in Contact with Supercritical CO2- An Electrochemical Study

Product Number: 51324-20621-SG

Author: Suresh Divi; Bruce Craig; Adam Rowe

Publication Date: 2024

$40.00

There has been a recent and significant surge in projects for injection of supercritical CO2 (SC-CO2) into saline reservoirs due to enhanced financial incentives. This has created a rush to permit projects without the necessary data to make informed decisions regarding the corrosion resistance of materials for well completions. Of urgent need is a better understanding of the corrosion performance of alloys for injection tubing and well equipment exposed to the injectate above the saline aquifer contact zone. An electrochemical study was performed to simulate contact of SC-CO2 containing some impurities with fresh water consistent with water condensing from the CO2 phase. The simulated condition represents a pH of 3 typical of water in contact with CO2 at greater than 73.8 bar and 31oC. A range of alloys were tested, including 13Cr, 17Cr, 22Cr, and others. Weight loss corrosion and pitting attacks were measured. The results of this study can be used for life prediction only in the cases where there is no localized corrosion to support material selection decisions for well equipment based on upsets and well shut-in during the life of SC-CO2 injection.

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