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Corrosion Inhibitor Performance under High Temperature / High Salinity Sweet Conditions

Picture for Corrosion Inhibitor Performance under High Temperature / High Salinity Sweet Conditions
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It is well known that the inhibitor efficiency is encumbered by many variables such as temperature pressure pH flow speed and chemical composition of the production fluid. Salt content of formation water varies dependent on the location. Sometimes the salinity shows more than 10% by weight.The performance of several corrosion inhibitors was evaluated with an electrochemical measurement namely Liner Polarization Resistance (LPR) and weight loss coupons in autoclaves. Test solution was synthetic brines with Total Dissolved Solids (TDS) up to 17% by weight NaCl in this study. The test solution was aerated with CO2 at ambient temperature and pressure before testing between 60 and 100ºC.The inhibitors evaluated here had the temperature tolerance up to 100ºC. Corrosion inhibitors performed at low temperature better than high temperature condition. But some of them showed poor inhibitor efficiency in case of pre-corrosion with high salinity at high temperature condition. This study also confirmed the validity of ILSS (Inhibitor Likelihood Success Score) introduced by Crossland et al. and provided a useful information for inhibitor selection for pipelines in various field conditions.Several set up with/without pre-corrosion step was done to confirm the associated impact of corrosion testing procedure on the overall performance of the corrosion inhibitors. It seems that high salinity affects the inhibitor absorption competing with corrosion product. The pre-corrosion test is required step for a qualification of corrosion inhibitors for a high salinity field.

Product Number: 51319-12756-SG
Author: Susumu Hirano
Publication Date: 2019
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$20.00
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Picture for Pitting corrosion on high-Mn steel alloyed with Ni and Cr in low H2S high CO2 high temperature and high Cl- environment
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51318-10632-Pitting corrosion on high-Mn steel alloyed with Ni and Cr in low H2S high CO2 high temperature and high Cl- environment

Product Number: 51318-10632-SG
Author: Qiao Sun / Qingzuo Chen / Hang Chi / Yang He / Haobo Yu / Changfeng Chen
Publication Date: 2018
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Pitting corrosion of these steels in a high-temperature, high-CO2, low-H2S, and high-Cl- environment was investigated by scanning electron microscope (SEM), energy dispersive detector (EDS) and X-ray diffraction (XRD).

 
Picture for Fe3O4, FeCO3 or FeS - Which Corrosion Product Will Prevail at High Temperature in CO2/H2S Environments?
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Fe3O4, FeCO3 or FeS - Which Corrosion Product Will Prevail at High Temperature in CO2/H2S Environments?

Product Number: 51320-14413-SG
Author: Shujun Gao, Bruce Brown, David Young, Srdjan Nesic, Marc Singer
Publication Date: 2020
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Sweet (CO2) and sour (H2S) corrosion have continuously been a challenge in oil and gas production and transportation. Yet, some key issues are still not well understood, especially at high temperature production conditions. A CO2/H2S ratio of 500, which has been used (often inaccurately) to determine which corrosion mechanism is dominant, is probably even less valid at high temperature. The nature of the corrosion products forming at high temperature in CO2/H2S environments and their effects on the corrosion rate are not known. Finally, the impact on pipeline integrity of environmental changes between sweet and sour production conditions (simulating reservoir souring) has not been well documented. CO2, H2S, and CO2/H2S corrosion experiments were conducted at 120oC to investigate corrosion mechanisms and corrosion product layer formation at high temperature. The results show that the corrosion products were still clearly dominated by H2S under the pCO2/pH2S ratio of 550. Formation of Fe3O4, FeCO3, and FeS corrosion product layers had a direct impact on the measured corrosion rates and was dependent on the gas composition and on the sequence of exposure (CO2 then H2S and vice versa). Compared with H2S corrosion alone, the presence of CO2 could retard Fe3O4 formation in CO2/H2S mixture environment. No obvious change in steady state corrosion rate was observed when the corrosion environment was switched from CO2 to H2S and vice versa. 
Picture for 03128 SELECTING MATERIALS FOR AN OFFSHORE
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03128 SELECTING MATERIALS FOR AN OFFSHORE DEVE LOPMENT CHARACTERIZED BY SOUR AND HIGH SALINITY ENVIRONMENT

Product Number: 51300-03128-SG
ISBN: 03128 2003 CP
Author: Ardjan Kopliku, Lucrezia Scoppio
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