AMPP Store - Products tagged with 'sour'

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07100 Sour Service Testing of High Strength TS Temper CuNiSn Alloy (UNS C72900)

Product Number: 51300-07100-SG

ISBN: 07100 2007 CP

Author: W. Raymond Cribb

Publication Date: 2007

$20.00

This paper documents the basic SCC and corrosion rate behavior of a new 150 ksi yield strength TS temper in Levels I, II, IV, V and VII environments. Microstructural observations, corrosion rate and resistance to SCC in full immersion proof ring static tensile tests are reported.

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51317-9113-Stress Corrosion Cracking Of A Duplex Stainless Steel

Product Number: 51317-9113-SG

ISBN: 9113 2017 CP

Author: Briony Holmes / Sam Mishael / Kasra Sotoudeh

Publication Date: 2017

$20.00

Results of the stress corrosion cracking tests showed that wrought UNS S31803 was not resistant to environmentally-induced cracking or corrosion in the test environment. A difference in surface finish did not have a significant effect.

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51318-11257-Sulfide Stress Cracking of Super 13Cr Martensitic Stainless Steel – Localized Corrosion and Hydrogen

Product Number: 51318-11257-SG

Author: Brian D. Chambers / Manuel Gonzalez / Yue Chen / Marc Wilms

Publication Date: 2018

$20.00

This paper provides an overview of the existing literature with regards to the understanding of cracking in molybdenum-containing 13Cr alloys and provides suggested paths of investigation.

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A Review Of Fit-For-Purpose Sour Tests Of Low Alloy Steels: Effects Of Buffer Chemistry And Purge Gas Composition

Product Number: 51321-16578-SG

Author: Brian Chambers / Manuel Gonzalez

Publication Date: 2021

$20.00

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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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Corrosion Inhibitor Film Stability Under High Gas Velocity Conditions of Subsea Wet Gas

Product Number: 51317--9247-SG

ISBN: 9247 2017 CP

Author: Bei Wang

Publication Date: 2017

$20.00

This paper details challenges of high pressure sour gas projects with high salinity and provides cases of field history, explanation regarding material selection framework and technical challenges during the design, execution and operating phases of sour service projects.

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Design Challenges for Material Selection in Sour and High Salinity Gas and Oil Production Facilites

Product Number: 51317--9244-SG

ISBN: 9244 2017 CP

Author: Pedro Rincon

Publication Date: 2017

$20.00

This paper addresses the challenges to provide example of engineering solutions through the use of corrosion resistant alloys and non metallic materials to maintain the integrity of flowlines and process equipment in severe sour service.

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Development of a Versatile Continuous Application Based Corrosion Inhibitor to Mitigate Top-of-the-Line Corrosion under Both Sweet and Sour Operating Conditions

Product Number: MECC23-19972-SG

Author: Jeremy Moloney

Publication Date: 2023

$20.00

Top-of-the-line corrosion (TLC) of carbon steel (CS) pipelines can be encountered during the transportation of wet gas under stratified flow conditions where temperature differences between the internal and external environments results in condensation of saturated vapors and water-wetted surface on the upper portion of the inside pipeline surface causing corrosion issues.1 Initially at least, the condensed water phase can be particularly corrosive with a low pH caused by dissolved acid gases (such as carbon dioxide and hydrogen sulfide) as well as organic acids in an unbuffered thin water film. Like bottom-of-the-line corrosion, TLC can be dominated by either carbon dioxide or hydrogen sulfide corrosion mechanisms.

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Downhole Sour Corrosion And Scale Deposition In Oil Wells

Product Number: 51322-17694-SG

Author: Tao Chen, Frank Chang, Feng Liang, Steven Hochanadel

Publication Date: 2022

$20.00

Sour corrosion and iron sulphide scale deposition are two common flow assurance issues encountered in oilfields. Sour oil wells typically produce crude along with produced water and a significant amount of acidic gases such as carbon dioxide and hydrogen sulfide. The high pressure and temperature conditions under the downhole tend to cause severe corrosion damage including metal loss and pitting, along with iron sulphide scale deposition. Iron sulfide deposition in sour wells is a corrosion induced scale problem. It potentially causes production decline, restricted well intervention, well shutdown, or even severe consequences towards to the abandoned wells.

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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.

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Investigation of Sulfide Stress Crack Propagation Using Sour Pipe Burst in Tubulars with Simulated Defects under Pressure

Product Number: 51324-20420-SG

Author: Brian Chambers; Bostjan Bezensek; Sebastian Cravero; Pedro Olivo; Octavio Albores

Publication Date: 2024

$40.00

Seamless oil country tubular goods (OCTG) with defined chemistry and toughness, e.g. API 5CT C110, are utilized as production casing in sour wells globally. These grades must withstand high pressures and mild sour conditions to maintain the integrity of the well and, as such, should resist both sulfide stress crack (SSC) initiation and potential propagation from defects in service. A laboratory study was conducted to assess the tendency of crack propagation from two defined types of defects, electro-discharge machined (EDM) notches and fatigue cracks, simulating potential as-delivered OCTG tubulars. The tubulars were subjected to a variety of test conditions including two temperatures, 4ºC and 24ºC, internal pressures ranging from 550 to 1,100 bar, and exposure to a modified NACE TM0177 Solution B equilibrated with 7% H2S/N2 gas purge. The applied pressure and depth of defects were used to determined applied stress intensity values, K, for each condition to compare tests with one another and to traditional small-scale evaluations per NACE TM0177 Method D, single edge notched tensile (SENT), and constant K compact tension (CT). The findings indicated that tendency towards SSC propagation was principally dependent on type of defect, temperature, and applied K. Threshold K values for SSC propagation from EDM-type defects were higher than determined from any of the small-scale evaluation methods. Fatigue pre-cracks were demonstrated to be more aggressive in promoting SSC propagation compared to EDM-type defects.

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The Development of Novel Corrosion Inhibitors for High Temperature Sour Gas Environments

Product Number: 51320-14591-SG

Author: Jody Hoshowski, Paul Barnes, Rolando Perez Pineiro, Alyn Jenkins, Tore Nordvik

Publication Date: 2020

$20.00

Mitigating oil and gas production with chemical inhibitors is challenging when high temperature (>120°C) and H2S is present. The high temperatures associated with deep wells and thermal recovery methods demand an advancement in conventional inhibitor technologies. Traditional organic inhibitors struggle to protect carbon steel assets lending them susceptible to localized corrosion in sour environments. These environments require inhibitors with a combined thermal stability and persistency to provide uniform filming and corrosion protection.

For high temperature corrosion applications imidazoline chemistry ranks highly as a chemistry likely to be able to mitigate corrosion at elevated temperatures. However, at temperatures between 120 and 150°C performance is very system specific while over 150°C performance can be severely limited. An extensive in-house screening program was undertaken which identified a generic chemistry (pyrimidine) that exhibited the required performance characteristics up to 175°C for a variety of field applications. Based on this work, several other materials exhibited performance benefits for alternate applications, for instance high temperature, deep water applications. Laboratory testing of the novel corrosion inhibitors at high temperatures, also highlighted the limitations of corrosion test methodologies for evaluating inhibitors under extreme conditions.

Products tagged with 'sour'

Association for Materials Protection and Performance