文章摘要
耐温耐盐稠油降粘体系的研制与应用
Development and application of viscosity reducing system with temperature and salt tolerance
投稿时间:2018-08-06  修订日期:2018-09-21
DOI:
中文关键词: 渤海稠油油田  耐温耐盐  乳化降粘  低界面张力  动态驱油  采收率
英文关键词: heavy oil in Bo Hai  temperature resistance and salt tolerance  emulsification viscosity reduction  low interfacial tension  dynamic oil displacement  recovery ratio
基金项目:国家科技重大专项“规模化多元热流体热采工程技术示范”(项目编号2016 2X 05058-003-009)
作者单位E-mail
吴春洲 中海油田服务股份有限公司油田生产事业部 wuchzh2@cosl.com.cn 
   
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中文摘要:
      渤海某稠油油田原油粘度大,胶质沥青质含量高,地层水矿化度较高,且油井完井方式为常规完井(管柱耐温≤120℃),热采吞吐温度受限,效果一般。为提高稠油常规井开采效果,室内研制了热采吞吐用耐温耐盐稠油乳化降粘体系CY-02,该体系由磺基甜菜碱类两性表面活性剂LHSB、非离子表面活性剂(以改性聚醚类为主要成分)组成,正交实验确定其最佳配比为2:1。考察了该化学体系的静态性能(耐温耐盐性、乳化降粘性能、乳液稳定性、界面张力、润湿性)和动态驱油效果。实验结果表明,该体系耐温≥120℃,NaCl容忍度>40000(mg/L),CaCl2容忍度>1500(mg/L);体系120℃老化24h后仍具有良好的界面性能,在油水比7:3时,可形成稳定的乳状液,50℃下的体系降粘率达98.8%;低含水率下亦不发生反相乳化;体系与原油的界面张力为10-2mN.m-1数量级;体系与煤油浸润后的模拟岩心之间润湿角为10°,可使岩石表面由油湿转变为水湿;120℃下动态驱油实验表明,该稠油降粘体系驱油比单独水驱,采油速度更快,最终采收率提高10.65%。通过在渤海某稠油油井的现场施工,该稠油降粘体系取得了良好的应用效果。
英文摘要:
      In a heavy oil field in Bohai, the viscosity of the crude oil, the content of the asphaltene is high, the formation water salinity is too high, and the well completion mode is conventional completion (the column temperature of tube is less than 120 ℃)。 The thermal recovery and puff temperature is limited, the effect is general. In order to improve the thermal recovery effect of heavy oil conventional wells, the emulsified and viscosity reducing system(CY-02) of thermal recovery and puff is screened in laboratory. The system consists of sulfonyl betaine amphoteric surfactant LHSB and nonionic surfactant (modified polyether ). The optimum ratio is 2:1. The static properties of the chemical system (resistance to salt, emulsification, viscosity, emulsion stability, interfacial tension, wettability) and dynamic oil displacement were investigated. The experimental results show that the system is more than 120℃, NaCl tolerance >40000 (mg/L) and CaCl2 tolerance >1500 (mg/L). The system still has good interfacial properties after aging for 24h at 120℃. The system can form stable emulsion at the time of oil and water ratio 7:3, the viscosity reduction rate of the system at 50℃ is 98.8%, and the anti phase emulsification does not occur at low water content. The interfacial tension with crude oil is 10-2mN.m-1 order of magnitude; the wetting angle between the system and the simulated core of kerosene is 10 degrees, which can make the rock surface change from oil wet to water wet, and the dynamic oil displacement experiment at 120℃ shows that the oil displacement system of the heavy oil is more than the separate water flooding and the recovery rate is increased by 10.65%. Through on-site construction of a heavy oil well in Bohai, the heavy oil viscosity reduction system has achieved good application results.
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