The galvanic corrosion behavior of magnesium alloy and Q235 steel system different Sc/Sa(negative / anode area ratio) in simulated solution of tank bottom water in Daxie oil depot was studied by immersion experiment, electrochemical test and micro morphology observation method. The impact of different Sc/Sa on corrosion rate was found out, which curve and expression were fitted. The results show that, the corrosion rate of magnesium alloy anode increases greatly with the increasing of Sc/Sa, but the increasing of corrosion rate for the negative part is not obvious. Based on the galvanic current image, the galvanic current fluctuates and decreases with time. When Sc/Sa is 1.0 or 2.0, the galvanic current decreases obviously, which does not decrease obviously when Sc/Sa is 0.5. The corrosion rate is calculated by galvanic current. It is demonstrated that the galvanic current, as well as the corrosion degree increases linearly with the increase of Sc/Sa.

Through the heat transfer analysis of the experimental loop of the insulated crude oil, the calculation model of the experimental loop temperature field of the insulated waxy crude oil was established.The internal temperature distribution of the pipeline and the variation of the temperature gradient of the inner wall of the pipeline were calculated.The effects of different ambient temperature,oil flow velocity and wax formation on the temperature field distribution of the pipeline were studied.The results showed that the greater the temperature difference between the oil temperature in the tube and the cooling water in the casing,the larger the average temperature gradient of the tube wall.The average temperature gradient of the pipe wall increased as the oil flow velocity increased,however,when the temperature gradient of the inner surface of the sediment deposit layer on the pipe wall was lower than the initial time, the magnitude of the decrease gradually decreased as the length from the inlet end increased.

Due to the effects of service environment, corrosion defects inevitably appear on pipeline surface, which will cause stress concentration and promote crack nucleation. In this study, a coupled stress and electrochemical multi⁃physical field model for predicting the morphological development of corrosion defects was established based on the finite element method. The time dependence of stress corrosion behavior and corrosion morphology of X70 pipeline steel in sea mud simulated solution were studied by using the established model via deformation geometry and dynamic mesh technology. The results showed that the mechanical⁃electrochemical effect played an important role in the nucleation of stress corrosion cracks. The smaller the width of corrosion defects, the greater the stress concentration, the negative shift of the electrode potential and the higher the corrosion rate. With the increase of the operating pressure, there was a large area of high stress concentration area in the bottom of the corrosion defect, and the area of metal loss caused by corrosion increased.