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Study of the Transport Behavior of Multispherical Proppant in Intersecting Fracture Based on Discrete Element Method

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Energy Engineering 2025年第1期122卷 185-201页

作者： Chengyong Peng JianshuWu Mao Jiang Biao Yin Yishan Lou CNOOC research institute Company Limited Beijing100028China School of Petroleum Engineering Yangtze UniversityWuhan430100China Hubei Key Laboratory of oil and Gas drilling and Production Engineering(Yangtze University) Wuhan430100China

To analyze the differences in the transport and distribution of different types of proppants and to address issues such as the short effective support of proppant and poor placement in hydraulically intersecting fractures,this study considered the combined impact of geological-engineering factors on *** reservoir production parameters and the discrete elementmethod,multispherical proppants were ***,a 3D fracture model,based on the specified conditions of the L block,employed coupled(Computational Fluid Dynamics)CFD-DEM(Discrete ElementMethod)for joint simulations to quantitatively analyze the transport and placement patterns of multispherical proppants in intersecting *** indicate that turbulent kinetic energy is an intrinsic factor affecting proppant ***,the efficiency of placement and migration distance of low-sphericity quartz sand constructed by the DEM in the main fracture are significantly reduced compared to spherical ceramic proppants,with a 27.7%decrease in the volume fraction of the fracture surface,subsequently affecting the placement concentration and damaging fracture *** to small-angle fractures,controlling artificial and natural fractures to expand at angles of 45°to 60°increases the effective support length by approximately 20.6%.During hydraulic fracturing of gas wells,ensuring the fracture support area and post-closure conductivity can be achieved by controlling the sphericity of proppants and adjusting the perforation direction to control the direction of artificial fractures.

关键词： Hydraulic fracturing discrete element method proppant sphericity CFD-DEM

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A study of the mechanism of enhancing oil recovery using supercritical carbon dioxide microemulsions

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Petroleum Science 2013年第1期10卷 91-96页

作者： Dong Zhaoxia Li Yi Lin Meiqin Li Mingyuan Enhanced oil recovery research institute China University of Petroleum Beijing Key Laboratory for Greenhouse Gas Storage and Enhanced oil recovery Key Laboratory of Enhanced oil recovery CNPC

Supercritical carbon dioxide （scCO2） microemulsion was formed by supercritical CO2, H20, sodium bis（2-ethylhexyl） sulfosuccinate （AOT, surfactant） and C2HsOH （co-surfactant） under pressures higher than 8 MPa at 45 ℃. The fundamental characteristics of the scCO2 microemulsion and the minimum miscibility pressure （MMP） with Daqing oil were investigated with a high-pressure falling sphere viscometer, a high-pressure interfacial tension meter, a PVT cell and a slim tube test. The mechanism of the scCO2 microemulsion for enhancing oil recovery is discussed. The results showed that the viscosity and density of the scCO2 microemulsion were higher than those of the scCO2 fluid at the same pressure and temperature. The results of interfacial tension and slim tube tests indicated that the MMP of the scCO2 microemulsion and crude oil was lower than that of the scCO2 and crude oil at 45 ℃. It is the combined action of viscosity, density and MMP which made the oil recovery efficiency of the scCO2 microemulsion higher than that of the scCO2 fluid.

关键词： Supercritical carbon dioxide microemulsion MMP enhancing oil recovery

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Experimental study on asphaltene precipitation induced by CO_2 flooding

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Petroleum Science 2014年第1期11卷 174-180页

作者： DONG Zhao-xia WANG Jun LIU Gang LIN Mei-qin LI Ming-yuan Enhanced oil recovery research institute China University of Petroleum Beijing Key Laboratory for Greenhouse Gas Storage and Enhanced oil recovery Key Laboratory of Enhanced oil recovery CNPC

The effects of CO2 pressure,temperature and concentration on asphaltene precipitation induced by CO2 were studied using a high-pressure vessel,interfacial tensiometer,Fourier transform infrared （FTIR） and drill core displacement experimental *** results indicated that the content of asphaltene in crude oil decreased,and the interfacial tension between a model oil and distilled water increased,with an increase of CO2 pressure,decrease of temperature and increase of molar ratio of CO2 to crude oil when CO2 contacted crude oil in the high pressure *** content of asphaltene in sweepout oil and the permeability of test cores both also decreased with an increase of CO2 flooding *** main reason for changes in content of asphaltene in crude oil,in interfacial tension between model oil and distilled water and in the permeability of the test core is the precipitation of asphaltene which is an interfacially active substance in crude *** of asphaltene also blocks pores in the drill core which decreases the permeability.

关键词： CO2 flooding asphaltene precipitation oil-water interfacial tension core permeability

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Numerical investigation of proppant transportation characteristics in hydraulically fractured wedge fractures

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Petroleum 2024年第4期10卷 660-671页

作者： Xiaofeng Sun Jinxin Bao Zhipeng Li Jingyu Qu Key Laboratory of Enhanced oil and Gas recovery of Ministry of Education Northeast Petroleum University Sanya Offshore oil & Gas research institute Northeast Petroleum University China Petroleum Bohai drilling Engineering Co. Ltd.Fourth Drilling Engineering Branch

Hydraulic fracturing creates multiple induced fractures and micro-fractures, forming a complex fracture network in the reservoir. The study of the transport and distribution of the proppant within the fracture network is critical to the design and evaluation. However, existing simulation studies of proppant transport tend to be overly idealized and neglect the inhomogeneity of fracture widths that occur after fracturing. To address these issues, this study employs computational fluid dynamics(CFD) to study the transportation of fracturing fluid and proppant within a fracture network. The flow dynamics of solidliquid two-phase flow in fractures are simulated using the Euler-Euler multiphase flow model. Considering the actual variables in field construction and the inherent inhomogeneity in realistic fracture structures, a three-dimensional model was established to capture the gradual variation in fracture *** accuracy of this model was verified through a comparative analysis with physical experiments. On this basis, an investigation was conducted to explore the impact of particle size, particle density, particle volume concentration, and injection velocity on proppant transportation. The results demonstrate that,in contrast to conventional rectangular fractures, sandbanks formed from wedge fractures exhibit a lower height, which facilitates improved transportation into deeper fractures. Furthermore, particle concentration primarily influences distal fractures, with proppant particle size being second. The injection velocity has a significant impact on the height of the sandbank located in proximity to the fracture *** research findings provide a deeper understanding of the transport and distribution of proppants within wedge fractures, thereby establishing a theoretical basis for the analysis and engineering guidance in on-site hydraulic fracturing construction.

关键词： Proppant transport Wedge fracture Computational fluid dynamics (CFD) Particle-fluid flow Hydraulic fracturing

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Supplement and optimization of classical capillary number experimental curve for enhanced oil recovery by combination flooding

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Science China(Technological Sciences) 2014年第11期57卷 2190-2203页

作者： QI LianQing LIU ZongZhao YANG ChengZhi YIN YanJun HOU JiRui ZHANG Jian HUANG Bo SHI FengGang CNOOC EnerTech-drilling & Production Co. China United Coalbed Methane Corporation Ltd. CNPC research institute of Exploration and Development Enhanced oil recovery institute of China University of Petroleum CNOOC research institute

In the middle of the last century,American scientists put forward the concept of capillary number and obtained the relation curve between capillary number and residual oil through *** revealed that the corresponding residual oil saturation decreased with increasing of capillary number;after capillary number reached up to a limit,residual oil saturation would become stable and did not *** important achievements laid a theoretical base for enhanced oil recovery with chemical *** the basis of the theory,scholars developed chemical flooding numerical simulation software *** the numerical simulation study of combination flooding,the authors found that as the capillary number is higher than the limit capillary number,the changes of the residual oil saturation along with the capillary number differ from the classical capillary number *** displacement experiments prove that there are defects in classic capillary number experimental curve and it is necessary to mend and *** number‘calculation’curve is obtained with a method of numerical simulation calculation and a complete description of capillary number curve is provided;On this basis,combination flooding capillary number experimental curve QL is obtained through experiments,which is different from the classical capillary curve;and based on which,an expression of corresponding combination flooding relative permeability curve QL is given and the corresponding relative permeability parameters are determined with *** oil displacement experiment research recognizes the cause of the singular changes of the capillary number curve."Combination flooding capillary number experimental curve QL"and"combination flooding relative permeability curve QL"are written in combination flooding software IMCFS,providing an effective technical support for the application of combination flooding technical research.

关键词： numerical simulation driving conditions interfacial tension capillary number combination flooding surfactant concentration wettability conversion

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Profile improvement during CO_2 flooding in ultra-low permeability reservoirs

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Petroleum Science 2014年第2期11卷 279-286页

作者： Zhao Fenglan Zhang Lei Hou Jirui Cao Shujun research institute of Enhanced oil recovery China University of Petroleum Key Laboratory of Enhanced oil recovery CNPC Key Laboratory of Petroleum Engineering Ministry of Education

Gas flooding such as CO2 flooding may be effectively applied to ultra-low permeability reservoirs, but gas channeling is inevitable due to low viscosity and high mobility of gas and formation heterogeneity. In order to mitigate or prevent gas channeling, ethylenediamine is chosen for permeability profile control. The reaction mechanism of ethylenediamine with CO2, injection performance, swept volume, and enhanced oil recovery were systematically evaluated. The reaction product of ethylenediamine and CO2 was a white solid or a light yellow viscous liquid, which would mitigate or prevent gas channeling. Also, ethylenediamine could be easily injected into ultra-low permeability cores at high temperature with protective ethanol slugs. The core was swept by injection of 0.3 PV ethylenediamine. oil displacement tests performed on heterogeneous models with closed fractures, oil recovery was significantly enhanced with injection of ethylenediamine. Experimental results showed that using ethylenediamine to plug high permeability layers would provide a new research idea for the gas injection in fractured, heterogeneous and ultra-low permeability reservoirs. This technology has the potential to be widely applied in oilfields.

关键词： Ethylenediamine organic amine profile improvement ultra-low permeability reservoirs,mitigation of gas channeling CO2 flooding

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Petroleum Characteristics and Controlling Factors in Lunnan Low Uplift,Tarim Basin

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Journal of Earth Science 2010年第2期21卷 236-246页

作者：王晓梅张水昌 State Key Laboratory of Enhanced oil recovery PetroChina research institute of Petroleum Exploration and Development

The Lunnan （轮南） low uplift is a complex basin that is situated in northwestern China. This area had undergone a range of tectonic events, and there are multi-production zones and reservoir types. Also, heavy oil, common black oil, volatilization oil, condensate oil and natural gas are approximately under the same stratum pressure grads and geothermal grads. The east Lunnan low uplift is mainly composed of condensate oil and natural gas, the middle part has many types of petroleum and the west part mostly has heavy oil. The petroleum geochemistry may be the principal reason for the great difference of the oil and gas characteristics. The heavy oil in the west part is established by the biodegradation and mixing effect. The mixing effect in the middle part produced the complex petroleum distribution, and the oil cracking effect and mixing effect, or air cutting effect in the east part is proof of the existence of the industrial condensate gas reservoir and waxy oil. Understanding of the complex petroleum reservoir can further supervise the development of petroleum exploration in the Lunnan low uplift.

关键词： Lunnan low uplift condensate oil natural gas heavy oil mixing effect biodegradation.

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Geological characteristics and accumulation mechanisms of the "continuous" tight gas reservoirs of the Xu2 Member in the middle-south transition region,Sichuan Basin,China

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Petroleum Science 2013年第2期10卷 171-182页

作者： Zou Caineng Gong Yanjie Tao Shizhen Liu Shaobo research institute of Petroleum Exploration & Development PetroChina State Key Laboratory of Enhanced oil recovery

＂Continuous＂ tight gas reservoirs are those reservoirs which develop in widespread tight sandstones with a continuous distribution of natural gas. In this paper, we summarize the geological features of the source rocks and ＂＇continuous＂ tight gas reservoirs in the Xujiahe Formation of the middle- south transition region, Sichuan Basin. The source rocks of the Xul Member and reservoir rocks of the Xu2 Member are thick （Xul Member： 40 m, Xu2 Member： 120 m） and are distributed continuously in this study area. The results of drilled wells show that the widespread sandstone reservoirs of the Xu2 Member are charged with natural gas. Therefore, the natural gas reservoirs of the Xu2 Member in the middle-south transition region are ＂continuous＂ tight gas reservoirs. The accumulation of ＂continuous＂ tight gas reservoirs is controlled by an adequate driving force of the pressure differences between source rocks and reservoirs, which is demonstrated by a ＂one-dimensional＂ physical simulation experiment. In this simulation, the natural gas of＂continuous＂ tight gas reservoirs moves tbrward with no preferential petroleum migration pathways （PPMP）, and the natural gas saturation of＂continuous＂ tight gas reservoirs is higher than that of conventional reservoirs.

关键词： Geological characteristics accumulation mechanism "continuous" tight gas reservoir Xu2Member middle-south transition region Sichuan Basin

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Experimental and numerical simulations of bottom hole temperature and pressure distributions of supercritical CO_2 jet for well-drilling

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Journal of Hydrodynamics 2014年第2期26卷 226-233页

作者：王瑞和霍洪俊黄志远宋慧芳倪红坚 School of Petroleum Engineering China University of Petroleum (East China) drilling Technology research institute Shengli Oil Field

The supercritical carbon dioxide （SC-CO2） drilling is a novel drilling technique developed in recent years. A detailed study of temperature and pressure distributions of the SC-CO2 jet on the bottom of a well is essensial to the SC-CO2 drilling. In this paper, the distributions of pressure and temperature on the bottom of the hole during the SC-CO2 jet drilling are simulated experimentally and numerically, and the impacts of the nozzle diameter, the jet length, and the inlet pressure of the SC-CO2 jet are analyzed. It is shown that, the bottom hole temperature and pressure increase with the increase of the nozzle diameter, and the bottom hole temperature reduces and the pressure increases first and then decreases with the increase of the jet length, indicating that the jet length has an optimum value. The increase of the inlet pressure can increase the temperature and pressure on the bottom, which has a positive effect on the drilling rate.

关键词： supercritical carbon dioxide CO2 jet numerical simulation SC-CO2 drilling

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Characteristics of Hydrocarbon Accumulation in the Paleozoic Donghetang Formation in the Southwestern Tahe Area

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Acta Geologica Sinica(English Edition) 2011年第4期85卷 899-910页

作者： ZHOU Wen ZHAO Guanjun LIU Fei YE Bin LI Xiuhua HUANG Tingting ZHOU Qiumei DONG Guoliang State Key Laboratory of Petroleum Reservoir Geology and Reservoir Engineering Chengdu University of TechnologyChengduSichuan 610059China drilling and oil recovery research institute Sichuan Petroleum Administrator BureauGuanghan Sichuan 618300China

The ancient structure characteristic,correlation of the oil and the hydrocarbon source rock characteristics,hydrocarbon migration trace,types and conditions of traps,migration passages and characteristic of hydrocarbon accumulation are researched in this *** is shown through the analysis that two main large tectonic activities after the Early Hercynian orogeny resulted in different tectonic patterns in the study *** main hydrocarbon infills occurred in the Donghetang Formation,the first occurred in the Early Hercynian resulting in the ancient hydrocarbon accumulation in the northern Tahe,the second infill was a large amount that occurred in places beneficial for hydrocarbon accumulation,such as structural traps and structural-stratigraphic traps formed in the Early Himalayan orogeny after migration along the faults through source rocks and other *** the earlier period of the Himalayan orogeny,the petroleum mainly migrated to the north,whereas petroleum migrated to the south and southeast because of the structural reverse in the Himalayan orogeny,so the middle and later period of the Himalayan orogeny is the key period for hydrocarbon *** model of＂oil generation formed early,hydrocarbon accumulation controlled by the faults through source rocks and structures formed late＂is *** is pointed out that the south of the research area is currently the beneficial district for hydrocarbon accumulation, which provides the basis for future petroleum exploration.

关键词： southwestern Tahe faults cutting through hydrocarbon source rock hydrocarbon igration trace model of hydrocarbon accumulation

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