The Big Escambia Creek Field is a gas/condensate field located in the southeastern United States that began production in 1974. The gas produced by the field contains about 40 percent CO2 and 20 percent H2S and the aqueous phase can contain as much as 200,000 ppm chlorides. Initially, these conditions combined to make the production extremely corrosive. A number of research studies were conducted in the 1970's and 1980's to improve the understanding of the corrosion and to improve the methods of corrosion control.

This work summarizes the studies conducted, describes the corrosion control programs that were utilized to successfully control downhole corrosion and describes the changes in production conditions that has dramatically reduced the corrosivity of the production.

Subject
Sulfur, Corrosion failures, Corrosion rate, Iron sulfides, Pyrrhotite, Joints, Partial pressures, Corrosion scales, Tubing, Inhibitor treatment, Pyrite, Corrosion inhibitors, Hydrocarbons
Keywords:
sour gas corrosion, H2S corrosion, iron sulfide
© 2004 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).
2004
Association for Materials Protection and Performance (AMPP)
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