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51317--9780-Development of Test Methods and Factors for Evaluation of Oilfield Corrosion Inhibitors at High Temp

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Evaluation of corrosion inhibitors for high temperature (HT) upstream oilfield applications can be challenging. A series of laboratory testing methodologies were conducted to further elucidate the factors which affect laboratory corrosion inhibitor performance in high temperature conditions.

Product Number: 51317--9780-SG
ISBN: 9780 2017 CP
Author: Boyd Laurent
Publication Date: 2017
Industry: Chemical Inhibitors
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Evaluation of corrosion inhibitors for high temperature (HT) upstream oilfield applications can be challenging due to fixed fluid volume tests typically encountered in laboratory testing. A series of laboratory testing methodologies were conducted in order to further elucidate the factors which affect laboratory corrosion inhibitor performance in high temperature conditions. Under certain HT conditions inhibitor performance may be skewed due to testing effects which may occur in closed cell testing at HT such as Fe2+ saturation and/or scaling of the test fluids which may artificially lower the overall general corrosion rate. This testing program was designed to minimize these effects and ensure that corrosion inhibition in laboratory testing is identified solely due to performance of the inhibitor. For these studies corrosion measurements in stirred autoclaves were performed by linear polarization resistance (LPR) or with weight loss measurements in rotating cage autoclaves (RCA). Surface morphology of corrosion products scale deposition and effects of localized attack were evaluated by microscopic evaluations. Factors affecting inhibited and uninhibited general corrosion rates measured in laboratory test environments such as brine composition effect of scale inhibitor inclusion effect of metal surface area to fluid volume ratio and method of acid gas charging were evaluated.

Key words: High Temperature, Corrosion Testing, Corrosion Inhibitor Selection

 

Evaluation of corrosion inhibitors for high temperature (HT) upstream oilfield applications can be challenging due to fixed fluid volume tests typically encountered in laboratory testing. A series of laboratory testing methodologies were conducted in order to further elucidate the factors which affect laboratory corrosion inhibitor performance in high temperature conditions. Under certain HT conditions inhibitor performance may be skewed due to testing effects which may occur in closed cell testing at HT such as Fe2+ saturation and/or scaling of the test fluids which may artificially lower the overall general corrosion rate. This testing program was designed to minimize these effects and ensure that corrosion inhibition in laboratory testing is identified solely due to performance of the inhibitor. For these studies corrosion measurements in stirred autoclaves were performed by linear polarization resistance (LPR) or with weight loss measurements in rotating cage autoclaves (RCA). Surface morphology of corrosion products scale deposition and effects of localized attack were evaluated by microscopic evaluations. Factors affecting inhibited and uninhibited general corrosion rates measured in laboratory test environments such as brine composition effect of scale inhibitor inclusion effect of metal surface area to fluid volume ratio and method of acid gas charging were evaluated.

Key words: High Temperature, Corrosion Testing, Corrosion Inhibitor Selection

 

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