Shell Canada Limited currently operates approximately 700 km of pipelines (2" to 16") in wet sour gas service. Although the majority of lines nave no history of internal corrosion failures, some lines have suffered serious corrosion. In these latter lines, corrosion has been predominantly caused by one of four corrosion mechanisms: 1) corrosion in the presence of high chloride formation water; 2) corrosion in the presence of sulphur/polysulphides; 3) corrosion in the presence of methanol; and 4) corrosion in the presence of low H2S/CO2 ratios. The parameters involved in these four mechanisms are discussed. As a better understanding of these mechanisms has been achieved, corrosion inhibition programs and design practices have been tailored to suit each situation. The corrosion inhibition programs, which are part of the overall corrosion control program are outlined. Results of inspection surveys and monitoring methods are also discussed to show the degree of success of the corrosion control programs.

Subject
Corrosion failures, Water, Piping, Sour gas, Pipelines, Condensates, Inspection, Gas velocity, Corrosion inhibitors, Methanol, Surveys, Chlorides, Hydrocarbons
© 1987 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).
1987
Association for Materials Protection and Performance (AMPP)
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