张海山.超出海上油套管选材图版的防腐设计实验研究[J].表面技术,2016,45(5):111-117.
ZHANG Hai-shan.Experimental Research on the Anti-corrosion Design out of the Tube and Casing Material Selection Chart in the Offshore Oilfields[J].Surface Technology,2016,45(5):111-117
超出海上油套管选材图版的防腐设计实验研究
Experimental Research on the Anti-corrosion Design out of the Tube and Casing Material Selection Chart in the Offshore Oilfields
投稿时间:2016-01-25  修订日期:2016-05-20
DOI:10.16490/j.cnki.issn.1001-3660.2016.05.017
中文关键词:  腐蚀  油套管  CO2腐蚀  CO2分压  防腐设计  腐蚀速率  13Cr 钢  高温高压釜
英文关键词:corrosion  tube and casing  CO2 corrosion  CO2 partial pressure  anti-corrosion design  corrosion rate  13Cr steel  HTHP Autoclave
基金项目:
作者单位
张海山 中海石油(中国)有限公司上海分公司,上海 200335 
AuthorInstitution
ZHANG Hai-shan CNOOC China Limited-Shanghai, Shanghai 200335, China 
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中文摘要:
      目的 东海 A 气田开发储层流体中 CO2分压约 1.85 MPa,温度在 150 ℃左右。井下腐蚀环境已超出中海油选材图版的应用范围,因此应进行防腐模拟实验研究,为优选油套管材质提供依据。 方法 应用失重法在高温高压动态反应釜中进行高温高压动态腐蚀模拟测试,选择油气田开发中高防腐油套管常用的普通 13Cr、超级 13Cr、 22-25Cr 双相不锈钢 3 种材质试样,测试不同材质油套管井下的腐蚀速率。 结果 CO2分压 2.0 MPa 下, 130 ℃时 3 种材质均未发现局部点蚀,温度升至 150 ℃时,超级 13Cr和 22-25Cr双相不锈钢表现为均匀腐蚀,普通 13Cr材质出现了点蚀,点蚀速率为 0.6413 mm/a,明显超过了腐蚀控制线; 150 ℃下,随着 CO2分压的增加,腐蚀速率增加,但分压达到约 2.0 MPa 后,腐蚀速率增加减缓,并且出现下降趋势。 结论 从井底开发储层到地面,温度逐步降低,根据实验结果,东海 A 气田开发设计组合油套管的方式防腐,深部温度高于 130 ℃位置的油套管应用超级 13Cr材质,上部温度低于 130 ℃位置的油套管应用普通 13Cr 材质,以降低成本。
英文摘要:
      Objective The content of CO2 partial pressure of the development reservoir fluid on the Gas Field A in the East China Sea is about 1.85 MPa, and the temperature is about 150 ℃. The parameters of downhole corrosion environment are out of the application scope of CNOOC tube and casing material selection chart, therefore, corrosive simulation experimental research should be carried out, which provides the foundation for optimization of tube and casing material. Methods In the experiment, weight loss method was used to dynamically test the corrosion rates of different tube and casing materials under the downhole condition by HTHP Auto Clave. The material samples were ordinary 13Cr, super 13Cr and 22-25Cr duplex stainless steel, high anticorrosive tubing and casing, which are commonly used in oil and gas field development. Results The results of experiment showed that localized pitting wasn’t found in 3 kinds of material samples under the condition of CO2 partial pressure at 2 MPa and 130 ℃; when the temperature rose to 150 ℃, uniform corrosion characteristic was present for super 13Cr and 22-25Cr duplex stainless steel, pitting was present on ordinary 13Cr, and the pitting rate was 0.6413 mm/a, which significantly exceeded the corrosion control line. When the temperature was below 150 ℃, with the increase of CO2 partial pressure, the corrosion rate increased, but after CO2 partial pressure exceeded 2.0 MPa, the increase of corrosion rate became slow, and the trend of decline occurred. From the bottom of a well-developed reservoir to the ground, the temperature was gradually reduced. Conclusion According to the experimental results, the development of the Gas Field A in the East China Sea designs the means of combination of tube and casing in ordor to protect corrosion, super 13Cr materials should be used in the deep location at temperature higher than 130 ℃, while ordinary 13Cr should be used in the upper location at temperature below 130 ℃, which could realize the cost saving of tube and casing.
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