Factors Influencing the CO2 Corrosion Pattern of Oil–Water Mixed Transmission Pipeline during High Water Content Period

After the oil field enters the high water content period, the oil–water mixed fluid in the mixing system will gradually change into the water-in-oil mixed fluid, while the dissolved CO2 causes the pH value of the mixed fluid to decrease. There is also a certain amount of bacteria in the output fluid...

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Bibliographic Details
Published in:Atmosphere 2022-10, Vol.13 (10), p.1687
Main Authors: Yang, Zhonghua, Shi, Lihong, Zou, Minghua, Wang, Changquan
Format: Article
Language:English
Subjects:
Bacteria
Calcium
Calcium ions
Carbon dioxide
Carbon steel
Carbon steels
CO2 partial pressure
Correlation
Correlation analysis
Corrosion
corrosion law
Corrosion prevention
Corrosion rate
Corrosion tests
Data analysis
Ethanol
Experiments
high water content
Laboratories
Magnesium
Mineralization
Moisture content
Oil
Oil and gas fields
Oil fields
oil–water mixed transmission system
Partial pressure
Pipelines
Pressure
Temperature
Water
Water content
Working conditions
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Summary:After the oil field enters the high water content period, the oil–water mixed fluid in the mixing system will gradually change into the water-in-oil mixed fluid, while the dissolved CO2 causes the pH value of the mixed fluid to decrease. There is also a certain amount of bacteria in the output fluid, with many factors leading to the intensification in the corrosion of the oil–water mixed system pipeline in the high water content period. To clarify its corrosion law, through the mixed transmission pipeline material, 20# carbon steel, in high water conditions under the action of different single factor dynamic corrosion rate experiments, along with the use of the SPSS method, were used to determine the corrosion of the main control factors. The results show that in the high water content period, the corrosion rate of the mixed pipeline 20# steel gradually increases with the increase in temperature pressure, CO2 partial pressure, SRB content, Ca2+ + Mg2+ content, and Cl− content. The corrosion rate with the CO2 partial pressure and SRB content changes show a strong multiplicative power relationship; with Ca2+ + Mg2+ content, Cl− content changes show a logarithmic relationship, the relationship degree R2 is above 0.98. Through SPSS data analysis software combined with experimental data for correlation degree analysis, it is concluded that the correlation magnitude relationship between each factor and corrosion rate is CO2 partial pressure > SRB content > Cl− content > Ca2+ + Mg2+ content > temperature pressure, which provides a theoretical basis for the corrosion protection of an oil gathering pipeline.
ISSN:2073-4433
2073-4433
DOI:10.3390/atmos13101687