Within the Oil & Gas industry high strength tubing alloys category 13-5-2, group 1 steels are typically used in HPHT fields containing CO2 and small amount of H2S. The alloy application limits have not been fully defined with respect to parameters such as chloride concentration, pH, temperature and H2S partial pressure. These parameters influence both localized corrosion resistance and Stress Corrosion Cracking (SCC) susceptibility.

The present work has been aimed at evaluating the SCC resistance of Alloy UNS S41426 grade 110 ksi (tubular).

The following environmental resistance topics are addressed:

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    Influence of load applied

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    Definition of working window in terms of temperature

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    Influence of brine composition

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    Test duration (1 month versus long term 3 months tests): evolution of crack initiation sites of a few microns observed after 1 month of exposure.

Furthermore, tubing steel performances have been compared with forged bar UNS S41425 grade 110 ksi, for selected cases.

Subject
Test methods, Materials, Sodium chloride, Stress cracking, Partial pressures, Tubing, Testing conditions, Steel, Brines, Corrosion resistance, Chlorides, Stress corrosion cracking, Chloride stress corrosion cracking
Keywords:
super martensitic stainless steel, SCC, chlorides, pH, H2S, CO2
© 2011 Association for Materials Protection and Performance (AMPP). All rights reserved. No part of this publication may be reproduced, stored in a retrieval system, or transmitted, in any form or by any means (electronic, mechanical, photocopying, recording, or otherwise) without the prior written permission of AMPP. Positions and opinions advanced in this work are those of the author(s) and not necessarily those of AMPP. Responsibility for the content of the work lies solely with the author(s).
2011
Association for Materials Protection and Performance (AMPP)
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