目的 明确长庆油田CO2驱采出环境下腐蚀影响因素对碳钢油管柱腐蚀性能的影响规律，结合腐蚀环境优化匹配合适的防腐措施。方法 通过失重法，利用高温高压釜模拟油田环境，得到材料的腐蚀速率，并结合扫描电子显微镜或背散射电子能谱，对试验后腐蚀产物膜形貌和腐蚀膜层横截面微观形貌进行分析。结果 在模拟油田CO2驱采出环境井筒温度为80 ℃的条件下，当p(CO2)在0~5 MPa范围逐渐增大时，N80/J55管材无明显点蚀现象，且平均腐蚀速率呈直线增大趋势，最大腐蚀速率达到5.87 mm/a；当试验体系逐渐进入超临界CO2环境（即p(CO2)≥7 MPa）时，N80/J55管材的平均腐蚀速率先减小后逐渐增大；当p(CO2)= 10 MPa时，管材的最大腐蚀速率达到6.74 mm/a。XRD物相分析得出，腐蚀产物膜主要由碳酸亚铁组成。试验溶液中加入200 mg/L的改性TG512缓蚀剂，可有效缓解管材腐蚀。当试验溶液介质含油率≥70%时，N80/J55管材的平均腐蚀速率≤0.022 mm/a，且平均腐蚀速率逐渐趋于平缓。结论 在模拟油田CO2驱采出液含油率<70%的环境下，N80/J55油管均为严重腐蚀，必须采取有效防腐措施才能使用。改性TG512高效缓蚀剂可有效减缓管材的腐蚀，缓蚀率达98.2%，满足油田需求。控制采出液中含水率低于30%，将会减缓井筒的腐蚀。

The work aims to clarify the influence rule of corrosion factors on the corrosion performance of carbon steel tubing string in CO2 flooding production environment of Changqing Oilfield and optimize and match appropriate anti-corrosion measures according to the corrosion environment. The corrosion rate of the material was obtained by weightlessness method in the simulated oilfield by high temperature autoclave, and scanning electron microscopy (SEM) or backscattering electron spectroscopy (BSES) were used to analyze the morphology of the corrosion product film and the cross section of the corrosion film. When the wellbore temperature was 80 ℃ and p(CO2) gradually increased in the range of 0~5 MPa, there was no obvious pitting corrosion in N80/J55 pipe, and the average corrosion rate increased linearly, with the maximum corrosion rate of 5.87 mm/a. The average corrosion rate of N80/J55 pipe decreased first and then increased gradually when the test system entered supercritical CO2 environment, i.e. p(CO2)>7 MPa. When p(CO2)=10 MPa, the maximum corrosion rate reached 6.74 mm/a. XRD phase analysis showed that the corrosion product film was mainly composed of ferrous carbonate; Adding 200 mg/L modified TG512 corrosion inhibitor to the test solution effectively alleviated the corrosion of the pipe; When the oil content of the test solution medium was more than 70%, the average corrosion rate of N80/J55 pipe was less than 0.022 mm/a, and the average corrosion rate gradually tended to be gentle. N80/J55 tubing is severely corroded in the simulated oil field when the oil content of CO2 flooding production fluid is less than 70%. Effective anti-corrosion measures must be taken before the tubing is used. Modified TG512 high-efficiency corrosion inhibitor can effectively slow down the corrosion of tubing materials and the corrosion inhibition rate is 98.2% in conformity with the needs of oil field. Controlling the water content of produced fluid below 30% will slow down the corrosion of wellbore.