AMPP Store - Products tagged with 'ssc'

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A Test Procedure To Evaluate ERW/HFW Pipe Seam Susceptibility To Embrittlement

Product Number: 51323-19135-SG

Author: Saad M. Al-Muaili, Mohammed A. Al-Anezi

Publication Date: 2023

$20.00

HFW pipes is considered a cost-effective pipe option for oil and gas pipeline projects. The HFW seam performance is always a concern, especially in challenging environments such as low temperature applications and wet sour services. One of the challenges include the seam properties to resist sulfide stress cracking (SSC) or hydrogen embrittlement (HE) when exposed to hydrogen charging environment such as a wet sour service.

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Development of High Strength grade and Cost Effective Super Martensitic Stainless Steel Solution for high CO2/H2S environment

Product Number: 51320-14715-SG

Author: Cécile Millet, Martien Deffo , Harold Evin, Guillaume Néel

Publication Date: 2020

$20.00

Super martensitic stainless steel (13Cr-5Ni-2Mo) provides high strength and CO2 resistance. It can be used at high temperature up to 180°C/356°F in high chloride environment. When the well temperature is above 180°C/356°F, Duplex grades 22-5-3 or Super Duplex 25-7-4 grades are commonly selected as per API 5CRA standard.
A new proprietary grade chemistry has been developed to provide improved strength up to 125ksi and higher pitting resistance while maintaining a tempered martensitic microstructure with low delta ferrite content and no detrimental phases or precipitates. Improvement of pitting resistance has been assessed through cyclic polarization curves. Higher sulfide stress cracking (SSC) and stress corrosion cracking (SCC) were assessed through NACE(1) TM 0177 method A 1 at ambient and high temperature. X-ray Photoelectron Spectroscopy (XPS) characterizations provide deep knowledge about passive film compositions underlining the beneficial effect of higher Mo within the grade.
This paper presents the benefit of the improved chemistry on sweet corrosion and sulfide stress cracking in severe downhole environment. It summarizes the effect of different parameters in both production and shut-in conditions to be considered to select cost effective material.

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Development Of The NACE “MR-01-75” And NACE “TM-01-77” Standards: Part I – Field Observations And Metallurgical Factors

Product Number: 51322-17525-SG

Author: Eric C. Caldwell, Brent W.A Sherar, Peter F. Ellis II, Russell D. Kane

Publication Date: 2022

$20.00

This is Part I of a two-part series intended to provide background and a rational justification or supporting rationale for requirements leading to the development and publication of NACE⁽¹⁾ MR 0175 and ISO⁽²⁾ 15156. Part I focuses on some of the metallurgical and processing requirements; specifically, Rockwell C 22 scale (HRC) limit, the various acceptable heat treatments and the 1wt% Ni limit for carbon and low alloy steels to minimize the threat of sulfide stress cracking (SSC) in H₂S containing environments. Part II describes the testing and rationale behind the use of accelerated laboratory test procedures and their development to differentiate metallurgical behavior in sour environments.

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Effect of H2S on the Corrosion and Cracking Behavior of Welded API 5L X65 Steel in Supercritical CO2

Product Number: 51321-16407-SG

Author: Shiladitya Paul

Publication Date: 2021

$20.00

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Effect Of H2S On The Performance Of Welded 13% Cr Steel In Supercritical CO2

Product Number: 51322-17886-SG

Author: Shiladitya Paul

Publication Date: 2022

$20.00

Carbon steels such as API 5L X65 are widely used oil and gas exploration, production and transportation service. However, these steels tend to corrode in the presence of wet CO2 and corrosion is more pronounced in the presence of dissolved salts and acids. Other metals, alloys and polymers also degrade in the presence of high pressure gaseous and supercritical CO2. The corrosion rate of carbon steels in some aqueous environments have been reported to be more than a few millimeters per year.9-10 The situation could be further exacerbated by H2S where cracking can be an issue for high strength steels.

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Effect of Laser Marking on Corrosion Performance of Metallic Materials in Different Environments

Product Number: 51321-16495-SG

Author: Thanh Nam Vu/ Karthik Krishnan/ Chad Glaesman

Publication Date: 2021

$20.00

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Effect Of Nb Addition And Processing Path On The KISSC Of A Low Alloyed OCTG Steel

Product Number: 51321-16696-SG

Author: Marc-Antoine Thual; Koen Bracke; Nuria Sanchez; Steven G. Jansto

Publication Date: 2021

$20.00

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Effect of Pre-pits on Localized Corrosion and Sulfide Stress Cracking Resistance of Duplex Stainless Steel UNS S32205 in Upstream Production Environments

Product Number: 51324-21031-SG

Author: Guru Prasad Sundararajan; V.T. Aruna; Marc E. Wilms; Navashree Surendran

Publication Date: 2024

$40.00

Components in upstream Oil and Gas production such as flowlines, storage vessels or injector pipelines which are made of duplex stainless steel UNS S32205 can undergo localized corrosion such as pitting or crevice corrosion when exposed to oxygen during shutdowns or turn arounds. Such unintended exposure to oxygen is related to poor maintenance or improper preservation and would normally require replacement of equipment. Further use of such pitted components can be considered but requires re-assessment of the pre-corroded material. Open-circuit Potential (OCP) and repassivation potentials (Erp) were measured on UNS S32205 in simulated flowline brines containing 150,000 mg/L Cl- at 110oC with pCO2 of 4.1 bara. The effect of pre-pits on bare and girth welded UNS S32205 was determined by creating artificial pits at OCP under oxygenated brine conditions and then switching the gaseous environment to sweet (CO2) conditions with continuous OCP monitoring. It was found that in oxygen-free CO2 production environments, existing pits did not grow. Sulfide Stress Cracking (SSC) resistance of pre-pitted solution annealed UNS S32205 specimens was determined through Slow Strain Rate Testing (SSRT) and Ripple Load Testing (RLT) at 90oC in concentrated chloride solutions. An electrochemical method was applied to create a single pit on the gauge surface. Comparison of SSRT and RLT results showed that SSRT is too aggressive for determining the pH2S limits. RLT of both pristine and pre-pitted UNS S32205 in concentrated chlorides with up to 0.3 bara pH2S did not show rupture, while selective attack of the ferrite phase was found (pit-depth < 30µm). RLT of notched UNS S32205 specimens were compared to that of pre-pitted specimens. Implications of these results on the limits recommended in ISO15156 / NACE MR0175 are discussed.

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Environmentally-Assisted Cracking (SSC And SCC) Of Martensitic Stainless Steel OCTG Material In Sour Environment In 5%Nacl And 20%Nacl Solution

Product Number: 51322-17563-SG

Author: Yuichi Kamo, Yusuke Mizuno, Yasuhide Ishiguro

Publication Date: 2022

$20.00

Martensitic stainless steels for OCTG materials are widely used in sweet and mild sour conditions. Environmentally-assisted cracking (EAC) is a major corrosion-related issue when using stainless steels as OCTG materials. The EAC in specific oil/gas well conditions with sour environments is defined as sulfide stress cracking (SSC) and stress corrosion cracking (SCC). The SSC is a type of cracking caused by hydrogen embrittlement, which is attributed to a cathodic reaction under acidic conditions, while SCC is associated with an anodic reaction. SSC testing for martensitic stainless steels for OCTG material is often carried out at or near ambient temperature under conditions simulating condensed water, and SCC tests are conducted at higher temperatures under conditions simulating formation water and/or the brine availability test.

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Failures with Duplex Stainless Steels (DSS) In Hydroprocessing REACs - Update on Latest API Survey

Product Number: MECC23-20094-SG

Author: Gerrit M Buchheim; David E Moore

Publication Date: 2023

$20.00

2205 Duplex Stainless Steel (DSS) UNS S31803 has been used in refinery hydroprocessing unit reactor effluent air coolers (REACs) since the mid 1980’s (1). 2205 was selected due to its good resistance to ammonium bisulfide (NH4HS) corrosion and perceived resistance to chloride stress corrosion cracking because it was an economical choice when compared to higher nickel alloy alternatives such as Alloy 825 or Alloy 625.

Many of these DSS REACs have remained in service successfully, with some in service for more than 30 years.

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HFW Pipe Seam Screening Test For Susceptibility To Hydrogen Embrittlement

Product Number: MECC23-20105-SG

Author: Saad M. Al-Muaili; Mohammed Al-Anezi; Khalid A. Babakri

Publication Date: 2023

$20.00

HFW pipes is considered a cost-effective pipe option for oil and gas pipeline projects. The HFW seam performance is always a concern, especially in challenging environments such as low temperature applications and wet sour services. One of the challenges include the seam properties to resist sulfide stress cracking (SSC) or hydrogen embrittlement (HE) when exposed to hydrogen charging environment such as a wet sour service.

Available for download

High-Pressure SSC Testing of TMCP Large-Diameter Pipeline Steel

Product Number: 51324-20855-SG

Author: Thomas Haase; René Rüter ; Christoph Bosch

Publication Date: 2024

$40.00

In the recent years concerns have been raised on the validity of 1 bar H2S testing to be representative of the full extension of SSC region 3 as currently defined in NACE MR0175 / ISO 15156-2. Within this work SSC four-point bend tests have been performed on base material and weld specimens from TMCP-based large-diameter pipes at exposure conditions in the range of 1-12 bar H2S partial pressure in the presence of different levels of CO2 up to 24 bar. The results are discussed based on microstructure and hardness of the tested pipes. Metallographic evaluation of the specimens to distinguish between SSC, grooves or stress-induced pits has been performed based on a recently published micrographic evaluation criteria chart. For this evaluation method, several examples are presented and discussed to contribute to the collection of data as a basis for damage feature evaluation. The results show that the tested TMCP-based large-diameter pipes are resistant to SSC at partial pressures of H2S above 1 bar, based on material parameters and test conditions. It is recommended to further investigate how the limits of SSC resistance depend on the quantity of CO2 present.

Products tagged with 'ssc'

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