H2S is corrosive to downhole and topside oil and gas production facilities. Its presence in natural gas is also limited to very low levels due to sales specifications. Its concentration in the reservoir sometimes increases with time due to the phenomenon known as reservoir souring. One way to control the levels of H2S and mitigate its effects in oil and gas production facilities is to inject non-regenerative liquid H2S scavengers at suitable points in the system with the expectation of having the H2S concentration reduced below target levels before the fluid reaches certain points. Therefore, the scavenging capacity and kinetics need to be considered when selecting an H2S scavenger for specific applications.

This paper presents results from an extensive test program conducted to evaluate the effect of different parameters (e.g., H2S concentration, scavenger concentration, water cut, type of hydrocarbon) on both the H2S scavenging capacity and kinetics of several chemical products at conditions simulating a specific field application.

Subject
Water, Composition, Alkalinity, Hydrogen concentration, Scavenging, Kerosene, Solubility, Charts, Acidity, Liquids, Kinetics, Brines, Oil
Keywords:
Chemical Treatment, Hydrogen Sulfide, H2S Scavenger, Laboratory Methods
© 2023 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).
2023
Association for Materials Protection and Performance (AMPP)
You do not currently have access to this content.