岩性油气藏 ›› 2018, Vol. 30 ›› Issue (4): 127–132.doi: 10.12108/yxyqc.20180415

• 石油工程 • 上一篇    下一篇

高凝油油藏自流掺稀冷采新技术与实践

窦松江1, 李炼民1, 石德佩2   

  1. 1. 中国石油大港油田分公司 勘探开发研究院, 天津 300280;
    2. 中国石油海外勘探开发公司, 北京 100085
  • 收稿日期:2018-02-01 修回日期:2018-05-03 出版日期:2018-07-21 发布日期:2018-07-21
  • 第一作者:窦松江(1966-),男,博士,教授级高工,主要从事国内外油气田开发地质方面的研究工作。地址:(300280)天津市滨海新区大港油田幸福路1278号。Email:dsj196612@sina.com。
  • 基金资助:
    中国石油天然气股份有限公司重大科技专项“大港油区大油气田勘探开发关键技术研究”（编号：2014E-06）资助

Application of new cold production technology through mixing light oil by commingling for high pour point reservoir

DOU Songjiang1, LI Lianmin1, SHI Depei2   

  1. 1. Research Institute of Exploration and Development, PetroChina Dagang Oilfield Company, Tianjin 300280, China;
    2. CNPC Oil-Gas Exploration and Development Corporation, Beijing 100085, China
  • Received:2018-02-01 Revised:2018-05-03 Online:2018-07-21 Published:2018-07-21

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摘要： 为解决高凝油油藏凝固点高、流动性差、常规技术开采经济效益低下等问题，采用井筒热传导、掺稀增液及降凝等技术，综合考虑地温、液量、掺稀比和生产制度等多种因素，形成了1套高凝油自流掺稀冷采新方法。结合矿场数据，对地层温度、液量、掺稀比及生产制度等参数在自流掺稀冷采过程中的敏感性进行了研究。结果表明：掺稀可以增加液量、提高原油温度，当液量大于60 m3/d时，便能保持较高的井口温度；掺入低凝油的比例超过60%时，混合原油的凝固点可大幅降低；动液面对温度损失的影响较大，当动液面低于1 000 m时，原油的井口温度可保持较高水平。在G油田的1口井中实施高凝油自流掺稀冷采开发技术，投产1年半以来，原来不具备开采条件的高凝油共计被采出3.16万m3。因此，针对高凝油与低凝油共生油藏，通过控制液量、掺稀比例以及优化生产制度等措施，能够实现自流掺稀冷采。该研究成果对同类型油藏的开发具有较好的借鉴意义。

关键词: 厚层气藏, 拟稳态产能, 打开程度, 非达西效应

Abstract: High pour point crude with the features such as high freezing point and poor flowing ability resulted in poor economic performance when producing in this kind of reservoirs, so a new cold production method through mixing light oil by commingling was developed for high pour point reservoirs, which integrates the techniques such as wellbore thermal conduction, mixing light oil to increase liquid production rate and lowering pour point and considers the factors of formation temperature, liquid production rate, mixing ratio and operating parameters of wells. The sensitivity of the above mentioned factors was also analyzed. The results show that liquid rate and wellhead temperature could be increased through mixing light oil and wellhead temperature would be high enough when liquid rate was above 60 m3/d. Pour point of crude would be decreased a lot when ratio of light oil over liquid rate was over 60%. Fluid level affected temperature loss apparently, and wellhead temperature would keep high if fluid level was deeper than 1 000 meters. The technology was applied in G oilfield and achieved good results that cumulative oil of 3.16×104 m3 in one producer which were unavailable by conventional method was produced within 1.5 years. The research shows that the method presented above could be used successfully in producing oilfields with both light oil and high pour point oil based on optimizing liquid rate, mixing ratio and operating parameters of producers, and it will be good reference for the development of the same kind of reservoirs.

Key words: thick gas reservoirs, pseudo-steady state deliverability, perforating degree, non-Darcy effect

中图分类号: 

  • TE38
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