There can be significant corrosion management challenges resulting from planned CO2 Enhanced Oil Recovery (EOR) projects in relation to new & existing oil & gas production infrastructure, covering existing production wells, subsea pipelines and offshore process facilities.

The CO2 EOR project presented will involve water alternating gas (WAG) injection into an existing reservoir via new injection wells. It is planned that 1 to 3 years of seawater injection will be followed by gas injection, at 5000 psig (345 barg), of up to 41 mmscfd (1.16 Msm3/d) of CO2 rich gas (80 mol%) into the mature reservoir. Reservoir modelling indicates that within 18 to 24 months water and CO2 breakthrough will occur, initially at the new producing wells, but eventually this will occur at existing producing wells also. The CO2 rich (up to 50 mol%) and high water cut (up to 80%) production fluids will be transported via existing subsea pipelines to offshore processing facilities for separation and export.

The different corrosion management options for elevated CO2 and produced water operating conditions were reviewed to develop a range of corrosion control / material selection options for new delivery pipelines, injection wells, and producing wells, and additional corrosion control (with associated corrosion monitoring and inspection requirements) for existing production flowlines, and process equipment.

Subject
Water, Corrosion rate, Predicted corrosion rate, Pipelines, Inspection, Corrosion assessment, Corrosion modeling, Fluids, Corrosion inhibitors, Carbon steel, Corrosion protection, Corrosion monitoring, Oil
Keywords:
supercritical carbon dioxide, elevated carbon dioxide, CO2 enhanced oil recovery, integrity assessment, corrosion prediction models, high pressure laboratory corrosion testing
© 2016 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).
2016
Association for Materials Protection and Performance (AMPP)
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