A number of CO2 corrosion models can predict successfully the “worst case” corrosion rate but fail when more complex effects need to be included such as protective scale formation, water entrainment/wetting and the H2S effect. A comprehensive integrated CO2 / H2S corrosion – multiphase flow model package has been built that takes into account the effect of most important variables and processes in internal pipeline corrosion including the effects of H2S, water entrainment in multiphase flow, corrosion inhibition by crude oil components and localized attack.

In the text below it is described how the model can account for formation of iron carbonate and iron sulfide scales and predict their morphology as well as the effect on the corrosion rate. It is then shown how the model can successfully predict the critical velocity for entraining free water by the flowing oil phase as well as the effect of the key variables. The model has been extensively calibrated with laboratory data and compared with limited field data.

Subject
Water, Piping, Droplets, Corrosion rate, Metal surfaces, Iron sulfides, Flow velocity, Dispersion, Density, Corrosion scales, Corrosion modeling, Iron carbonate scale, Oil
Keywords:
CO2/H2S corrosion, water entrainment, water wetting, model, prediction
© 2005 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).
2005
Association for Materials Protection and Performance (AMPP)
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