Corrosion Rate Prediction of String in CO2 Injection Well
Using CO2 flooding to improve oil recovery in low permeability and high water cut oilfields has become an important technology to cope with climate change under the background of double carbon.However,the corrosion failure of CO2 injection well string occurs frequently.Studying the corrosion mechanism of the string in the CO2 environment and predicting the corrosion rate of the string is an important way to ensure safe production.In this paper,the electrochemical analysis of CO2 injection well string corrosion is carried out.The correlation between pressure,temperature,pH value,water content,ion concentration and other factors in the corrosion failure of the string is considered.The corrosion rate prediction model of P110 tubing under CO2 corrosion environment is optimized,and the corrosion rate of the example well string is predicted,and the measured value of the oil field is compared.The results show that in the process of CO2 injection,the corrosion degree of the well section above 1500 m is small,and the corrosion mainly occurs in the well section of 1300～1700m.The corrosion is serious at about 70℃,and the corrosion rate can reach 0.3 mm/a.The corrosion rate is greatly affected by water content and wellbore temperature,and the corrosion prediction results are in good agreement with the field measured corrosion.
corrosion ratetubingCO2 injection wellforecasting model
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