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51312-01573-Research on Corrosion Inhibitors for Acid Stimulation

Picture for Research on Corrosion Inhibitors for Acid Stimulation
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Product Number: 51312-01573-SG
ISBN: 01573 2012 CP
Author: Evgeny Barmatov
Publication Date: 2012
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$20.00
$20.00
Formation treatment with matrix acids for stimulation in carbonates or for dissolution of fines is an established method in the Oil & Gas industry. Either organic acids like citric or acetic acid or mineral acids like HCl or HF are injected into the well at concentrations up to 28wt%. Acid injection periods are usually ?24 hours and in many treatments the acid is injected during a period of 4-8 hours. However certain situations may require longer injection periods. In the absence of a corrosion inhibitor the generalised corrosion rate increases exponentially with acid concentration and temperature. The generalised corrosion rate can be reduced to an acceptable level by adding appropriate concentrations of inhibitor products but in certain situations localised corrosion (e.g. pitting) is observed and this is more difficult to predict. Overall it is essential to add corrosion inhibitors to matrix acidizing fluids in order to protect and prolong the useful lifetime of the hardware present in the well. Currently inhibitor packages demonstrate high efficiency with carbon steels and at temperatures below 150C. However there is a need for high temperature corrosion inhibitors that also protect high alloys in the presence of acid. We will present an overview of commonly applied acid corrosion inhibitors and compare published data with data measured in-house. Furthermore we will highlight the common pitfalls associated with the evaluation of acid corrosion inhibitors.
Formation treatment with matrix acids for stimulation in carbonates or for dissolution of fines is an established method in the Oil & Gas industry. Either organic acids like citric or acetic acid or mineral acids like HCl or HF are injected into the well at concentrations up to 28wt%. Acid injection periods are usually ?24 hours and in many treatments the acid is injected during a period of 4-8 hours. However certain situations may require longer injection periods. In the absence of a corrosion inhibitor the generalised corrosion rate increases exponentially with acid concentration and temperature. The generalised corrosion rate can be reduced to an acceptable level by adding appropriate concentrations of inhibitor products but in certain situations localised corrosion (e.g. pitting) is observed and this is more difficult to predict. Overall it is essential to add corrosion inhibitors to matrix acidizing fluids in order to protect and prolong the useful lifetime of the hardware present in the well. Currently inhibitor packages demonstrate high efficiency with carbon steels and at temperatures below 150C. However there is a need for high temperature corrosion inhibitors that also protect high alloys in the presence of acid. We will present an overview of commonly applied acid corrosion inhibitors and compare published data with data measured in-house. Furthermore we will highlight the common pitfalls associated with the evaluation of acid corrosion inhibitors.
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51314-3945-Corrosion Testing of Stimulation Acidizing Packages on High Strength Corrosion Resistant Tubing Alloys for High Pressure Deep Water Wells

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Picture for Materials and Corrosion Risk Mitigation Associated with Flowback of Acid Stimulation Fluids
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Materials and Corrosion Risk Mitigation Associated with Flowback of Acid Stimulation Fluids

Product Number: 51317--8917-SG
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Acid stimulation is a growing practice in the deep water subsea environment. Two acids were tested, one of hydrofluoric and acetic acids and another of hydrofluoric, hydrochloric, and acetic acids. Results and outlines recommendations for different alloys are presented.
Picture for Corrosion Inhibitor Testing in Dense Phase Hydrocarbon Systems
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51312-01567-Corrosion Inhibitor Testing in Dense Phase Hydrocarbon Systems

Product Number: 51312-01567-SG
ISBN: 01567 2012 CP
Author: Rolf Nyborg
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