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Flow characteristic of polymer solutions in porous media:Influence of the molecular weight and concentration

Petroleum 2023年第2期9卷 214-222页

作者： Yingjie dai Jia Li Li Li Yifei Liu Yuan Li Xiangyu Wang Xuguang Song caili dai Bin Yuan Key Laboratory of Unconventional Oil&Gas Development(China University of Petroleum East China)Ministry of EducationQingdao 266580China Shandong Key Laboratory of Oilfield Chemistry(China University of Petroleum East China)Qingdao 266580China Nanchong Vocational and Technical College Nanchong 637131China Oil&Gas Technology Research Institute of Changqing Oilfield Company Xi'an 710000China Sinopec Research Institute of Petroleum Engineering Fracturing&Acidizing and Natural Gas Production Research InstituteDongying 257000China Department of Chemical and Materials Engineering University of AlbertaEdmontonAB T6G 1H9Canada

The polymer solution flow in porous media is a central research topic related to hydraulic fracturing measures,formation damage and fracture propagation.Influenced by molecular weights and concentrations,various flow patterns of polymer in pores are presented,resulting in different filtration loss.In this work,the effectiveness of various polymer solutions for filtration loss was assessed by utilizing the core flooding experiment firstly.The result shows that lesser filtration loss normally is inextricably linked to solutions with high molecular weight and concentration.Subsequently,the flow behaviors of polymer solutions investigated by designed micro pore-throat structure and micro-particle image velocimetry(m-PIV)further confirmed the above result.It was found that the central convergent flow pattern benefiting from higher viscous force loss and less filtration loss was observed at high flow rates(0.5 mL/h),and higher molecular weight and concentration were more prone to convergent flow patterns.The viscosity force loss increases by about 4 times varying the molecular weight of polymer from 5×10^(6)to 18×10^(6)g/mol or the concentration from 0.05 to 0.3%.It interprets higher molecular weight and concentration in core studies and field observations with decreased filtration loss of HPAM.This work provides a theoretical foundation for the application of fracturing fluids as well as fresh perspectives on how to access the filtration loss of fracturing fluids.

关键词： Polymer solution Porous media Flow pattern m-PIV

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Facile and controllable synthesis of amino-modified carbon dots for efficient oil displacement

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Nano Research 2023年第5期16卷 6048-6056页

作者： Yining Wu Lisha Tang Mengjiao Cao Li Li Kai Liu Demin Kong Qingshan Zhao Xu Jin He Liu caili dai Shandong Key Laboratory of Oilfeld Chemistry School of Petroleum EngineeringChina University of Petroleum(East China)Qingdao 266580China Oil&Gas Technology Research Institute of Changqing Oilfield Company Xi’an 710000China State Key Laboratory of Heavy Oil Processing College of Chemistry and Chemical EngineeringChina University of Petroleum(East China)Qingdao 266580China PetroChina Research Institute of Petroleum Exploration&Development Beijing 100083China

Zero-dimensional(0D)carbon dots exhibit excellent potential as a new oil-displacing agent for unconventional reservoir development.However,the difficulty in size/surface properties control and unclear mechanism hinder their further applications.In this study,amino-modified carbon dots(am-CDs)for oil displacement were facilely synthesized through the rapid polymerization of D-glucose(D-Glc)and 3-aminopropyltriethoxysilane(APTES).The size of am-CDs could be precisely controlled by the reaction condition and quenching achieved by adjusting the pH value to neutral.The surface amine groups endow am-CDs with excellent hydrophilicity and dispersion stability.The 0.30 wt.%nanofluid based on am-CDs with an average size of 2.6±0.040 nm showed remarkable oil recovery efficiency(54.09%)without the addition of surfactant.The oil recovery efficiency of am-CDs is much higher than those of water flooding(30.25%),nano-SiO_(2) flooding(36.45%),and amino-free carbon dots(af-CDs)flooding(37.80%).Experimental and theoretical results reveal that am-CDs can be favorably adsorbed on the core surface to modulate the micro-scale wettability,changing the surface from oil-wet to relatively uniform water-wet.Meanwhile,am-CDs can effectively reduce the adhesion force between alkanes and sandstone surfaces,contributing to oil droplets peeling off and oil displacement.This study provides a new strategy for developing efficient carbon dots-based nanofluids for enhanced oil recovery.

关键词： carbon dots amino-modification polymerization enhanced oil recovery adhesion force

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洛河组砂岩用新型无固相冻胶注浆体系

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油田化学 2024年第2期41卷 229-237页

作者：李嘉鸣吕东方赵金忠赵光戴彩丽中国石油大学(华东)石油工程学院山东青岛266580

洛河组砂岩采动地层涌水频繁,严重影响了矿井安全生产。针对传统注浆体系面临渗滤效应严重和成胶性能不可控,难以实现裂隙出水有效调控的技术难题,通过分析5种天然典型岩心样品(含砾砂岩、巨粒砂岩、粗粒砂岩、中粒砂岩、细粒砂岩)的矿... 详细信息

洛河组砂岩采动地层涌水频繁,严重影响了矿井安全生产。针对传统注浆体系面临渗滤效应严重和成胶性能不可控,难以实现裂隙出水有效调控的技术难题,通过分析5种天然典型岩心样品(含砾砂岩、巨粒砂岩、粗粒砂岩、中粒砂岩、细粒砂岩)的矿物组成及微观形貌,明确了孔隙微观赋存特征,构建了低成本、稳定性优异的无固相冻胶注浆体系。通过物理模拟驱替实验研究了冻胶注浆体系的注入性和封堵性能,通过核磁共振在线驱替实验研究了注浆封堵前后岩心中的孔隙分布变化特征。结果表明,孔隙直径小和孔喉连通性差是造成传统注浆体系难以顺利注入和深部运移的地质原因。由于渗滤效应的存在,传统注浆体系的固化封堵效果明显低于理论设计。以0.5%~0.6%聚丙烯酰胺、0.6%~0.7%有机胺类单体交联剂、0.07%~0.08%酚类单体交联剂和0.2%~0.3%有机酸类调节剂为原料,构建了低成本、无固相、易深部注入的新型冻胶注浆体系。该冻胶注浆体系可实现48h内成胶,180d内未见明显脱水,长期老化稳定性优异。冻胶注浆体系的注入性良好,持续冲刷岩心后的压力衰减率为7.85%~20.95%,封堵率为82.04%~92.19%。冻胶注浆体系通过占据大孔道或裂缝空间,增大渗流阻力,迫使后续流体转向,实现出水层有效封堵。该研究成果可为洛河组砂岩注浆堵水施工提供新思路。

关键词：洛河组砂岩低渗透无固相冻胶注浆封堵

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稠油冷采用冻胶分散体调驱体系的相互作用机制

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石油与天然气化工 2024年第2期53卷 71-77页

作者：杨宁戴彩丽邹辰炜谢忠旭刘逸飞赵光中国石油大学(华东)石油工程学院重质油全国重点实验室非常规油气开发教育部重点实验室

目的旨在有效解决稠油化学冷采过程中降黏剂窜流现象严重、油藏动用效率低的问题，支撑稠油绿色高效开发。方法基于稠油冷采降黏剂高效降黏洗油与冻胶分散体调剖剂储层调控的协同效应，采用复配方式构建了稠油冷采用冻胶分散体调驱体... 详细信息

目的旨在有效解决稠油化学冷采过程中降黏剂窜流现象严重、油藏动用效率低的问题，支撑稠油绿色高效开发。方法基于稠油冷采降黏剂高效降黏洗油与冻胶分散体调剖剂储层调控的协同效应，采用复配方式构建了稠油冷采用冻胶分散体调驱体系，测试其基本性能，并使用界面扩张流变仪以及流变仪，考查了体系的界面流变特性和剪切应力特性。结果体系由质量分数为0.06%～0.12%的冻胶分散体和质量分数为0.05%～0.15%的降黏剂组成，为粒径均一的低黏流体，能够降低界面张力并乳化稠油，降黏率达到95%以上。体系中降黏剂在油水界面的吸附行为决定了体系的乳化降黏能力，降黏剂通过吸附在冻胶分散体的表面提高了体系的聚结稳定性，并考查了组分含量及油藏条件对以上过程的影响。结论构建了一种兼具储层调控和高效降黏能力稠油冷采用冻胶分散体调驱体系，探明了体系中各组分间的相互作用机制，为稠油化学冷采提供了技术支持。

关键词：稠油冷采冻胶分散体乳化降黏界面流变特性固-液相互作用

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笔谈:矢志能源报国的教育家精神

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中国石油大学学报（社会科学版） 2024年第2期40卷 8-18页

作者：方华灿印兴耀戴彩丽蔡宝平姚成郡中国石油大学(华东) 山东青岛266580

2023年9月9日,习近平总书记致信全国优秀教师代表时,深刻阐释了中国特有的教育家精神:“心有大我、至诚报国的理想信念;言为士则、行为世范的道德情操;启智润心、因材施教的育人智慧;勤学笃行、求是创新的躬耕态度;乐教爱生、甘于奉献... 详细信息

2023年9月9日,习近平总书记致信全国优秀教师代表时,深刻阐释了中国特有的教育家精神:“心有大我、至诚报国的理想信念;言为士则、行为世范的道德情操;启智润心、因材施教的育人智慧;勤学笃行、求是创新的躬耕态度;乐教爱生、甘于奉献的仁爱之心;胸怀天下、以文化人的弘道追求。”我国石油高等教育已经走过70年创业发展的辉煌历程,为新中国石油工业培养了大批优秀人才,凝聚形成了具有鲜明石油特色的精神品格,涌现出一大批践行教育家精神的模范教师。本组文章由我校5位优秀教师撰写,他们各自以在我校学习、教学、科研或管理的丰富经验和切身体会,阐述了对教育家精神的深刻理解和对践行教育家精神的深入思考,诠释了石油教育家精神的独特品质,希望以此引发我校教师对教育家精神特别是石油教育家精神的总结、传承与弘扬,激励广大教师尤其是青年教师以老一辈石油教育家和身边的模范教师为榜样,自觉践行教育家精神和石油教育家精神,努力成为躬耕讲台、铸魂育才的“大先生”,为实现人才强国、能源强国战略培养更多德才兼备的杰出人才。

关键词：教育家中国教育家精神石油高等教育能源报国

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渗吸置换提高原油采收率研究进展

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石油与天然气化工 2024年第3期53卷 64-72页

作者：王永红赵明伟耿捷晏翔刘长龙彭鑫蒙露明邹辰炜胡勇戴彩丽中国石油集团工程技术研究院有限公司中国石油大学(华东)石油工程学院中国石油乍得公司中海石油(中国)有限公司天津分公司中国石油化工股份有限公司石油勘探开发研究院

渗吸置换作用已逐渐成为非常规油藏和低渗、特低渗裂缝性油藏提高原油采收率的一种重要方式，大量裂缝的存在及细小孔隙发育为渗吸作用的发生创造了有利条件。首先，基于毛细管压力与重力对渗吸的贡献程度，对渗吸模式进行分类；而后，... 详细信息

渗吸置换作用已逐渐成为非常规油藏和低渗、特低渗裂缝性油藏提高原油采收率的一种重要方式，大量裂缝的存在及细小孔隙发育为渗吸作用的发生创造了有利条件。首先，基于毛细管压力与重力对渗吸的贡献程度，对渗吸模式进行分类；而后，主要聚焦于影响渗吸的各类因素，详细阐述如储层类型、孔渗物性、边界条件、流体(包括原油与渗吸液体)性质等因素对渗吸的影响规律及作用机制，总结了目前使用的研究渗吸的各种实验手段；最后，根据渗吸作用的研究进展，探讨在实验条件确定、黏土水化影响、界面张力优化和渗吸模式选择等方面所面临的问题，并对这些问题的研究前景进行展望。

关键词：渗吸提高采收率非常规油藏低渗特低渗裂缝

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Application of Polymers in Low Permeability Formations

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Journal of Materials Science and Chemical Engineering 2015年第5期3卷 37-45页

作者： Juan Zhao caili dai Guang Yang Jian Zhang Hui Yang Xinsheng Xue Xiaodong Kang Lixia Li State Key Laboratory of Offshore Oil Exploitation Beijing China CNOOC Research Institute Beijing China China University of Petroleum (East China) Qingdao China Key Laboratory of Colloid Interface and Chemical Thermodynamics Institute of Chemistry the Chinese Academy of Sciences Beijing China

For low-permeability sandstone reservoir with big channel, we researched the novel deep profile method alternative injection of anionic and cationic polymer. Evaluating various factors on adsorption capacity through lab test, the results show that with the increase of temperature, the adsorption capacity decreases and the cationic polymer is easier to be absorbed. With the increase of salinity, adsorption time or polymer concentration, the adsorption capacity increases. The adsorption equilibrium concentration of cationic polymer is 1500 mg/L;adsorption equilibrium time is 8 h. The adsorption equilibrium concentration of anionic polymer is 1000 mg/L;adsorption equilibrium time is 6 h. Physical simulation experiment shows that alternative injection of anionic and cationic polymer is better than injection of single polymer, and preferential injection of cationic polymer is better than preferential injection of anionic polymer. With the increase of injection rounds, sealing capacity gets better, but in view of cost, the rounds should not be more than 3. The profile control technique can obviously enhanced oil recovery, and water displacement recovery increases 41%. 2 wells were tested successfully in Henan Oilfield in June 2010. Approximate 154.47 tons of incremental oil was obtained with 2% water-cut decrease.

关键词： Anionic and Cationic Polymer Alternative Injection Sealing Capacity Water Displacement Recovery Increment

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Proppant transport law in multi-branched fractures induced by volume fracturing

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石油勘探与开发:英文版 2023年第4期50卷 955-970页

作者： GUO Tiankui LYU Mingkun CHEN Ming XU Yun WENG Dingwei QU Zhanqing dai caili HOU Jian LIU Xiaoqiang MOE Key Laboratory of Unconventional Oil&Gas Development China University of Petroleum(East China)Qingdao 266580China School of Petroleum Engineering China University of Petroleum(East China)Qingdao 266580China PetroChina Research Institute of Petroleum Exploration&Development Beijing 100083China School of Earth and Space Sciences Peking UniversityBeijing 100871China

To further clarify the proppant transport and placement law in multi-branched fractures induced by volume fracturing, proppant transport simulation experiments were performed with different fracture shapes, sand ratios, branched fracture opening time and injection sequence of proppants in varied particle sizes. The results show that the settled proppant height increases and the placement length decreases in main fractures as the fracturing fluid diverts gradually to the branched fractures at different positions. The flow rate in branched fractures is the main factor affecting their filling. The diverion to branched fractures leads to low flow rate and poor filling of far-wellbore branched fractures. The inclined fracture wall exerts a frictional force on the proppant to slow its settlement, thus enhancing the vertical proppant distribution in the fracture. The increase of sand ratio can improve the filling of near-wellbore main fracture and far-wellbore branched fracture and also increase the settled proppant height in main fracture. Due to the limitation of fracture height, when the sand ratio increases to a certain level, the increment of fracture filling decreases. When branched fracture is always open(or extends continuously), the supporting effect on the branched fractures is the best, but the proppant placement length within the main fractures is shorter. The fractures support effect is better when it is first closed and then opened(or extends in late stage) than when it is first opened and then closed(or extends in early stage). Injecting proppants with different particle sizes in a specific sequence can improve the placement lengths of main fracture and branched fracture. Injection of proppants in an ascending order of particle size improves the near-wellbore fracture filling, to a better extent than that in a descending order of particle size.

关键词： volume fracturing proppant transport complex fracture support multi-branched fracture fracture inclination opening time of branched fracture

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Characteristics and displacement mechanisms of the dispersed particle gel soft heterogeneous compound flooding system

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Petroleum Exploration and Development 2018年第3期45卷 481-490页

作者： ZHAO Guang dai caili YOU Qing Petroleum Engineering School of China University of Petroleum Qingdao 266580 China Energy School of China University of Geosciences Beijing 100083 China

Considering high temperature and high salinity in the reservoirs, a dispersed particle gel soft heterogeneous compound(SHC) flooding system was prepared to improve the micro-profile control and displacement efficiency. The characteristics and displacement mechanisms of the system were investigated via core flow tests and visual simulation experiments. The SHC flooding system composed of DPG particles and surfactants was suitable for the reservoirs with the temperature of 80-110 °C and the salinity of 1×10~4-10×10~4 mg/L. The system presented good characteristics: low viscosity, weak negatively charged, temperature and salinity resistance, particles aggregation capacity, wettability alteration on oil wet surface, wettability weaken on water wet surface, and interfacial tension(IFT) still less than 1×10^(-1) mN/m after aging at high temperature. The SHC flooding system achieved the micro-profile control by entering formations deeply and the better performance was found in the formation with the higher permeability difference existing between the layers, which suggested that the flooding system was superior to the surfactants, DPG particles, and polymer/surfactant compound flooding systems. The system could effectively enhance the micro-profile control in porous media through four behaviors, including direct plugging, bridging, adsorption, and retention. Moreover, the surfactant in the system magnified the deep migration capability and oil displacement capacity of the SHC flooding system, and the impact was strengthened through the mechanisms of improved displacement capacity, synergistic emulsification, enhanced wettability alteration ability and coalescence of oil belts. The synergistic effect of the two components of SHC flooding system improved oil displacement efficiency and subsequently enhanced oil recovery.

关键词： soft heterogeneous compound flooding dispersed particle gel surfactant synergistic effect displacement mechanism high temperature and high salinity reservoirs

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基于强化界面润湿调控的多羟基苯磺酸盐驱油剂的合成与性能评价

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化学学报 2022年第1期80卷 63-68页

作者：李琳王子昭刘佳伟陈佳金晓戴彩丽中国石油大学(华东)石油工程学院青岛266580 中国石油大学(华东)非常规油气开发教育部重点实验室青岛266580

通过调控原油-岩石界面润湿性进而提高采收率是油田高效开发的重要思路.现有阴离子表面活性剂改变岩石表面润湿性能力有限,研发强化界面润湿调控性能的新型驱油剂具有重要应用意义.本工作合成了一种新型表面活性剂二羟甲基十二烷基苯磺... 详细信息

通过调控原油-岩石界面润湿性进而提高采收率是油田高效开发的重要思路.现有阴离子表面活性剂改变岩石表面润湿性能力有限,研发强化界面润湿调控性能的新型驱油剂具有重要应用意义.本工作合成了一种新型表面活性剂二羟甲基十二烷基苯磺酸钠(SDDBS),通过红外和核磁进行结构表征.探究了SDDBS在亲油岩石表面的吸附行为、降低油水界面张力能力、对岩石表面润湿性调控能力、油膜剥离能力以及驱油性能.实验结果表明SDDBS可在亲油岩石表面均匀吸附,临界胶束浓度下可将油水界面张力降至2.54 mN/m,亲油玻璃片经0.02%(w) SDDBS溶液处理48 h后,其空气中水滴接触角由100.2°降低至24.5°,水下油滴接触角由19.2°增加至153.9°,证明SDDBS可将亲油/疏水的岩石表面调控为强亲水/水下强疏油状态.采用0.02%(w) SDDBS溶液在60℃下处理原油老化的玻璃片, 24 h内油膜剥离面积高达89%,在地层水条件下油膜剥离面积仍可达81%.室内模拟岩心驱油实验结果显示采收率提高10.53%.本工作通过一步法合成一种新型多羟基苯磺酸盐驱油剂,通过引入氢键强化其界面润湿调控能力用于油膜高效剥离,具有较强实际应用潜力.

关键词：表面活性剂驱油剂界面润湿性油膜剥离

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