Abstract
Severe localized corrosion of carbon steel tubing and flowlines in production wells from a high pressure steam drive occurred during the first 6 weeks of operation. Corrosion was attributed to carbon dioxide, with localization occurring at points of high turbulence. Corrosion rates declined rapidly aa the wellhead temperatures in the production wells increased from 38 to above 100 C, and the hydrogen sulfide content of the gas increased from a trace to 1-2%. The inhibiting effect of hydrogen sulfide is consistent with observations in other high carbon dioxide environments.
© 1997 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).
1997
Association for Materials Protection and Performance (AMPP)
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