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Modified 13Cr (UNS S41426) (M13Cr) are advantageous as components for wellbores in oil and gas upstream units due to their high strength capabilities and tremendous corrosion resistance in sweet environments with minimal H2S levels. However, previous studies speculate disparities between an overestimation in the application limits for the 110 ksi grade material. Previous experimental results associate this to microstructural differences from varying heat treatments. The proprietary procedures used to manufacture, emphasize a lack of quality control among suppliers.
Modified 13Cr martensitic stainless steels (UNS S41426) are a class of materials used for operations involving natural gas production in sweet and moderately sour service conditions. Discrepancies between experimental results and field services have posed problems in identifying the window of service with experiments often overestimating these results. This false-positive is likely attributed to changes in passive film composition and stability with respect to temperature and H2S activity. Electrochemical tests were performed using a 1L autoclave holding 35 bar of CO2 gas with and without H2S at temperatures varied from 25 °C to 150 °C in salt brine solutions with a pH of 3.5. The point defect model approach is used in conjunction with potentiodynamic polarization and chronoamperometry to observe changes in cation vacancy diffusivity that contribute to strengthening and instability. These results indicate a critical point in temperature in the tests with only CO2, where resistance to pitting susceptibility is maximized due to a decrease in the cation vacancy diffusivity.
Traditionally, sour severity of high-pressure, high temperature (HPHT) oil and gas production wells were assessed by H2S partial pressure (PH2S): The mole fraction of H2S in the gas (yH2S) multiplied by the total pressure (PT). While PH2S is appropriate for characterizing the sour severity of wellbores operating at low total pressures (e.g., PT < 35 MPa) and/or for highly sour systems (e.g., yH2S > 1 mol%), PH2S usually over-predicts the actual sour severity of HPHT systems, leading to sub-optimal material selection options.
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The goal of the Paris Agreement is to limit global warming to below 2°C, preferably 1.5°C, compared to pre-industrial levels.1 While the world is slowly transitioning to more sustainable energy sources to reach this target, one of the ways to reduce the CO2 in the atmosphere is to capture it and store it in depleted gas fields. According to the IOGP1, the total number of CCS projects in Europe is 65 in 2022.2 The aim of these projects is to store around 60 MtCO₂/yr by 2030.
Martensitic Stainless Steel (SMSS) is widely used for downhole production tubing and liners in the Oil & Gas industry. Optimization of the tubular material chemistry, cleanliness and manufacturing route has delivered useful performance in H2S-containing environments (specifically SSC and stress corrosion cracking [SCC])3 resistance4,5,6. Some tubular accessories and most completion equipment require sizes not readily delivered by tubular product form. In these instances, bar stock material is a pragmatic choice.