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Effect of Trace Concentrations of H2S Introduced to Existing Sweet Corrosion Product Layers

Picture for Effect of Trace Concentrations of H2S Introduced to Existing Sweet Corrosion Product Layers
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A 2002 study estimated the annual cost associated with corrosion of gas pipelines to be around $5 billion. Corrosion of oil and gas pipelines continues to pose a major issue in the oil and gas industry due to the combination of brine produced with the oil and the type of acid gas present which can lead to significant internal corrosion. Oil and gas reservoirs can be separated into two categories, sweet and sour.

Product Number: 51323-19261-SG
Author: Adam Cutright, Bruce Brown, David Young
Publication Date: 2023
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$20.00
$20.00

Simulation of reservoir souring has been a neglected area of corrosion research. The procedure followed herein is to form a sweet corrosion product layer, introduce a low concentration of H2S in the gas phase (<100ppm) and allow the system to continue to evolve. The experimental apparatus used was a 2L glass cell with an impeller in the center and 5 samples spaced evenly around it to allow for in situ corrosion rate monitoring and extraction of specimens for surface analysis. In experiments involving Fe3C residues the general corrosion rate decreased when H2S was added to the system. FeS was detected on the samples with the Fe3C; it is postulated that a thin layer of FeS forms leading to the decrease in general corrosion rate. When the FeCO3 was challenged with H2S, the general corrosion rate increased. FeS was detected on the samples, but no significant change was observed in the FeCO3. However, it was electrochemically determined that the H2S impacted the FeCO3 sufficiently to allow the general corrosion rate to increase.

Simulation of reservoir souring has been a neglected area of corrosion research. The procedure followed herein is to form a sweet corrosion product layer, introduce a low concentration of H2S in the gas phase (<100ppm) and allow the system to continue to evolve. The experimental apparatus used was a 2L glass cell with an impeller in the center and 5 samples spaced evenly around it to allow for in situ corrosion rate monitoring and extraction of specimens for surface analysis. In experiments involving Fe3C residues the general corrosion rate decreased when H2S was added to the system. FeS was detected on the samples with the Fe3C; it is postulated that a thin layer of FeS forms leading to the decrease in general corrosion rate. When the FeCO3 was challenged with H2S, the general corrosion rate increased. FeS was detected on the samples, but no significant change was observed in the FeCO3. However, it was electrochemically determined that the H2S impacted the FeCO3 sufficiently to allow the general corrosion rate to increase.

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Uncontrolled microbial growth in oilfield systems leads to costly problems such as fouling, plugging,
corrosion and souring. It also directly impacts the safe operation, economic performance and
environmental compliance in all areas of production, transportation, refining and distribution. To reduce
the damaging effect of microbial growth; the oil industry typically uses a variety of toxic organic and
inorganic chemicals (biocides) to treat affected systems
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