AMPP Store - Products tagged with 'sulfide stress corrosion cracking'

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11112 Difficulties inthe Use of NACE MR0175/ISO 15156

Product Number: 51300-11112-SG

ISBN: 11112 2011 CP

Author: Jeff Vatne and Regina Verdolin

Publication Date: 2011

$20.00

This paper will discuss some of the reasons why some Owner/Operators are choosing to invoke NACE MR0175-20021 instead of NACE MR0175/ISO 15156. Examples of exceptions taken will be examined. And cost issues involved in meeting MR0175/ISO 15156 will be presented.

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Evaluation Of The Suitability Of As Bent Super Duplex Stainless Steel UNS-S32750 Tubing For Refinery Sour Services

Product Number: 51321-16850-SG

Author: Yong-Joo Kim; Karen Picker

Publication Date: 2021

$20.00

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Fracture Failure Analysis of Type HL Sucker Rod in H2S-CO2 Environment

Product Number: 51320-14649-SG

Author: Jiangjiang Zhang, Zhiwen Yang, Wenguang Zeng, Dapeng Li, Yujie Guo, Xiuyun Wang, Qiuying Gao, Lei Zhang

Publication Date: 2020

$20.00

Recently, there have been several cracking failures of type HL carbon steel sucker rods with evidence of fatigue striation. In order to find out the reason for the fracture failure, the fracture morphology, material properties, loading and corrosion product of the failed type HL 35CrMoA sucker rod were analyzed, combined with the corrosion environment. The results show that the material properties of the failed 35CrMoA sucker rod meet the GB/T 26075-2010 standard requirements. Also the result of loading analysis shows that the loading is far from the fatigue limit stress. The type HL sucker rod’s yield strength is almost 1049 MPa and hardness is 35.2 HRC. In addition, the low in-situ pH and high H2S-CO2 partial pressure places the sucker rods in the Region 3 of sulfide stress corrosion cracking, which means the quenched and tempered sucker rod’s yield strength should not exceed 863 MPa and hardness should not exceed 30 HRC, according to the ISO 15156-2:2015 standard. It is concluded that the high hardness level of the type HL sucker rod led to sulfide stress corrosion cracking in the high H2S-CO2 partial pressure and low in-situ pH condition.

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Material Selection for CCUS Injection Well: A Case Study in North Sea

Product Number: 51324-21062-SG

Author: Luciana Lima; Cecile Millet; Diana Rodrigues Barrera; Guillaume Néel; Robert Conder

Publication Date: 2024

$40.00

Carbon capture utilization and storage (CCUS) are technologies aimed at capturing CO2 and preventing its subsequent emission. Though CO2 transport and injection for enhanced oil recovery (EOR) has been a common practice for the Oil and Gas industry for over 40 years, new challenges arise when the CO2 source is anthropogenic. Industrial CO2 stream composition will carry impurities such as NO2 (nitrogen oxides), SO2 (sulfur oxides), O2 (oxygen), H2S (hydrogen sulfide) that could affect material corrosion behavior. A complete testing program was undertaken to assess the main corrosion risks associated to the application: Sulfide Stress Cracking (SSC), Stress Corrosion Cracking (SCC), crevice and mass loss resistance. The results confirm the effects of impurities such as SO2, NO2 and oxygen on corrosion behavior. Carbon low alloyed steel (N80Q) material presented a higher corrosion rate, and it is not suitable for injection tubing but may be acceptable for casing materials when not permanently exposed to the CO2 stream. UNS S41426 (S13Cr) material needs special considerations for CCS application due the presence of some localized corrosion when exposed to a high saline water phase. UNS S31803 (22Cr) could be suitable for a less severe environment including additional testing, whilst UNS S32760 (25CrS) presented good corrosion behavior and is suitable for the application.

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Resistance of U-bend and Integral Finned Duplex Stainless Steel UNS-S32205 and UNS-S32750 to Sulfide Stress Corrosion Cracking

Product Number: 51322-18038-SG

Author: Karen Picker, Luiza Esteves, Yong-Joo Kim

Publication Date: 2022

$20.00

The use of Duplex Stainless Steels (DSS) in refinery sour environments is governed by ANSI/NACE MR0103/ISO 17945NACE “Metallic materials resistant to sulfide stress cracking in corrosive petroleum refining environments” which limits DSS base materials to be used in Hydrogen Sulfide (H2S) services to a maximum hardness of 28 HRC for materials with a PREN ≤ 40 and to a maximum hardness of 32 HRC for those materials with PREN > 40.¹ These hardness values are in line with the hardness requirements of solution annealed as produced straight tubes, but when the heat exchanger design requires the use of integral finning or u-bend tubes, these are subject to significant work hardening that results in as bent and as finned heat exchanger tubes with hardness measurement as high as 418 HV0.5 or 35.6 HRC which clearly exceeds the allowable limits stated above.

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Role of H2S In Localized Corrosion and Cracking of CRAs in Upstream Oil and Gas Applications

Product Number: 51317--9463-SG

ISBN: 9463 2017 CP

Author: Gareth Hinds

Publication Date: 2017

$20.00

Materials qualification testing of corrosion resistant alloys (CRAs) typically involves the use of simple pass/fail tests. Modification of existing standards is recommended for environments in which pit initiation is statistically improbable but pit propagation is rapid, e.g. low chloride/high H2S.

Products tagged with 'sulfide stress corrosion cracking'

11112 Difficulties inthe Use of NACE MR0175/ISO 15156

Evaluation Of The Suitability Of As Bent Super Duplex Stainless Steel UNS-S32750 Tubing For Refinery Sour Services

Fracture Failure Analysis of Type HL Sucker Rod in H2S-CO2 Environment

Material Selection for CCUS Injection Well: A Case Study in North Sea

Resistance of U-bend and Integral Finned Duplex Stainless Steel UNS-S32205 and UNS-S32750 to Sulfide Stress Corrosion Cracking

Role of H2S In Localized Corrosion and Cracking of CRAs in Upstream Oil and Gas Applications

Association for Materials Protection and Performance