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AISI 420/410 Modified Martensitic Stainless Steel bar Stock Materials Sulphide Stress Cracking (SSC) Resistance in Mildly Sour Environments

Picture for AISI 420/410 Modified Martensitic Stainless Steel bar Stock Materials Sulphide Stress Cracking (SSC) Resistance in Mildly Sour Environments
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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.

Product Number: 51323-18759-SG
Author: Roberto Morana, Lee Smith, Perry Nice, Lucrezia Scoppio, Marc Müller, Karola Klenke, Roberta Prencipe, Luciana Intiso
Publication Date: 2023
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$20.00
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UNSiii S41000 and UNS S42000 martensitic stainless steels bar stock alloys are often selected for downhole completion equipment due to their good performance in oil and gas environments. In accordance with the ISOiv 15156 / ANSIv NACEvi MR0175 Part 31 guidelines, UNS S41000 and UNS S42000 quenched and tempered to 22 HRC have a maximum ppH2S limit of 10 kPa (1.5 psi). For H2S levels exceeding 10 kPa (1.5 psi), the most common selection is precipitation hardened nickel alloys. Martensitic stainless steels are desirable as the lowest cost oil and gas corrosion resistant alloys and knowing their corrosion performance application windows for well construction materials is critical to their safe application. Similarly, it is possible that more stringent specification of these grades could extend their utility to more severe environments, decreasing reliance on PH-Ni alloys which are expensive and increase the lead time for equipment. 

UNSiii S41000 and UNS S42000 martensitic stainless steels bar stock alloys are often selected for downhole completion equipment due to their good performance in oil and gas environments. In accordance with the ISOiv 15156 / ANSIv NACEvi MR0175 Part 31 guidelines, UNS S41000 and UNS S42000 quenched and tempered to 22 HRC have a maximum ppH2S limit of 10 kPa (1.5 psi). For H2S levels exceeding 10 kPa (1.5 psi), the most common selection is precipitation hardened nickel alloys. Martensitic stainless steels are desirable as the lowest cost oil and gas corrosion resistant alloys and knowing their corrosion performance application windows for well construction materials is critical to their safe application. Similarly, it is possible that more stringent specification of these grades could extend their utility to more severe environments, decreasing reliance on PH-Ni alloys which are expensive and increase the lead time for equipment. 

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Developing an Appropriate Heat Treatment Protocol for Additively Manufactured Alloy 718 for Oil and Gas Applications

Product Number: 51323-18793-SG
Author: M.R. Stoudt, M.E. Williams, J.S. Zuback, K.W. Moon, C.E. Campbell, C.R. Beauchamp, M. Yunovich
Publication Date: 2023
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Additive manufacturing (AM) is a transformative technology that has opened areas of design space that were previously inaccessible by enabling the production of complex, three-dimensional parts and intricate geometries that were impractical to produce via traditional manufacturing methods. However, the extreme thermo-mechanical conditions in the AM build process (e.g., cooling rates ranging from 103 K/s
to 106 K/s and repeated heating/cooling cycles) generate deleterious microstructures with high residual stresses, and extreme compositional gradients.
Picture for Optimizing Sour Gas Qualification Testing – Modeling the Effects of Temperature and Total Pressure on H2S Fugacity, Activity, and Solubility Coefficients
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Optimizing Sour Gas Qualification Testing – Modeling the Effects of Temperature and Total Pressure on H2S Fugacity, Activity, and Solubility Coefficients

Product Number: 51323-18762-SG
Author: Brent W.A. Sherar, Diana Miller, Hui Li
Publication Date: 2023
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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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Material Selection for Carbon Capture and Storage (CCS) Wells

Product Number: 51323-18760-SG
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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.
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