| 南海西部高温高压小井眼水平井钻完井储层保护技术研究及应用 |
| 投稿时间：2017-02-20 修订日期：2017-05-11 点此下载全文 |
| 引用本文：吴江,李炎军,张万栋,等.南海西部高温高压小井眼水平井钻完井储层保护技术研究及应用[J].钻探工程,2017,44(8):18-22.WU Jiang,LI Yan-jun,ZHANG Wan-dong,et al. Research and Practice of Reservoir Protection Technology in High Temperature and High Pressure Slim Horizontal Well Drilling and Completion in Western South China Sea[J]. Drilling Engineering, 2017,44(8):18-22. |
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| 基金项目:国家科技重大专项课题“莺琼盆地高温高压钻井液及固井技术研究”（编号：2016ZX05024-005-006） |
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| 中文摘要:南海西部东方13-1气田D7H井为国内海上第一口高温高压水平井，储层物性以中低渗为主，使用高固相含量的钻井液易堵塞油气泄流通道造成储层伤害，加之海上完井方式制约，高密度钻井液在井眼滞留时间达10 d以上，不可避免地会加剧储层伤害程度。为充分保障该井储层保护效果，室内开展了大量的优选评价实验，优选出适合海上高温高压小井眼水平井钻完井储层保护油基钻井液，分析了高密度钻井液污染储层的机理，研究了返排压差、返排时间与岩心渗透率恢复结果的关系，提出了增加返排压差、延长返排时间提高储层保护效果的措施。实验结果表明：高温环境下高密度钻井液污染岩心后，初始渗透率恢复值约85%，当污染时间达到15 d时，渗透率恢复值骤降至30%，表明钻井液在储层滞留时间越长储层污染现象越严重；相同驱替条件下，渗透率恢复值随时间的延长而提高并趋于稳定；增加岩心返排时的压差有利于提高渗透率恢复值，返排压差达到12 MPa时，钻井液体系的渗透率恢复值可提高到80%以上。现场应用表明，D7H井试井机械表皮系数为0，清喷产量6.0×105 m3/d，超出配产产量近3倍，储层保护效果良好，为后续海上高温高压气田实施水平井进行规模化开发提供了宝贵的借鉴意义。 |
| 中文关键词:高温高压 小井眼 水平井 气田 储层保护 |
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| Research and Practice of Reservoir Protection Technology in High Temperature and High Pressure Slim Horizontal Well Drilling and Completion in Western South China Sea |
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| Abstract:D7H well of Dongfang 13-1 of gas field in Western South China sea is the first offshore high temperature and high pressure slim horizontal well in China, its reservoir physical property is mainly of medium to low permeability, the drainage passage is easy to be blocked due to the use of the drilling fluid with high solid content, which causes reservoir damage; and being restricted by offshore completion method and up to 10 days retention time of drilling fluid in borehole, the extent of reservoir damage will inevitably be exacerbate. In view of this, a lot of indoor optimization evaluations were carried out, oil-based drilling fluid suitable for reservoir protection in offshore high temperature and high pressure slim horizontal well drilling and completion has been optimized. The pollution mechanism of high density drilling fluid is analyzed, the relationship among flow back pressure difference, flow back time and core permeability recovery results are studied and the measures to improve reservoir protection effect by flow back pressure difference increasing and flow back time prolonging are put forward. The experiment results show that after the core is contaminated by high density drilling fluid under high temperature, the initial permeability recovery value is about 85%, when the polluting time is up to 15 days, the permeability recovery value plunged to 30%, which shows that the longer the residence time of the drilling fluid in the reservoir, the more serious the pollution is; in the same displacement condition; along with the time prolonging, the permeability recovery value increases and becomes stable; the pressure difference increasing in flowback is conducive to increasing permeability recovery value, when flowback pressure difference reaches 12MPa, the permeability recovery value of drilling fluid system may be increased to more than 80%. The field application results show that the skin factor is zero in D7H well testing, production is 6.0×105m3/d, exceding proraton produciton nearly 3 times, good reservoir protection effects is received, which provides important reference for subsequent large-scale development of offshore high temperature and high pressure horizontal well. |
| keywords:high temperature and high pressure slim hole horizontal well gas field reservoir protection |
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