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Time-dependent model for two-phase flow in ultra-high water-cut reservoirs: Time-varying permeability and relative permeability

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petroleum Science 2024年第4期21卷 2536-2553页

作者： Shao-Chun Wang Na Zhang Zhi-Hao Tang Xue-Fei Zou Qian Sun Wei Liu College of Energy Resources Chengdu University of Technology College of petroleum Engineering Shandong Institute of Petroleum and Chemical Technology

For the ultra-high water-cut reservoirs, after long-term water injection exploitation, the physical properties of the reservoir change and the heterogeneity of the reservoir becomes increasingly severe, which further aggravates the spatial difference of the flow field. In this study, the displacement experiments were employed to investigate the variations in core permeability, porosity, and relative permeability after a large amount of water injection. A relative permeability endpoint model was proposed by utilizing the alternating conditional expectation(ACE) transformation to describe the variation in relative permeability based on the experimental data. Based on the time dependent models for permeability and relative permeability, the traditional oil-water two-phase model was improved and discretized using the mimetic finite difference method(MFD). The two cases were launched to confirm the validation of the proposed model. The impact of time-varying physical features on reservoir production performance was studied in a real water flooding reservoir. The experimental results indicate that the overall relative permeability curve shifts to the right as water injection increases. This shift corresponds to a transition towards a more hydrophilic wettability and a decrease in residual oil saturation. The endpoint model demonstrates excellent accuracy and can be applied to time-varying simulations of reservoir physics. The impact of variations in permeability and relative permeability on the reservoir production performance yields two distinct outcomes. The time-varying permeability of the reservoir results in intensified water channeling and poor development effects. On the other hand, the time-varying relative permeability enhances the oil phase seepage capacity, facilitating oil displacement. The comprehensive time-varying behavior is the result of the combined influence of these two parameters, which closely resemble the actual conditions observed in oil field expl

关键词： Mimetic finite difference Water flooding reservoir Time-varying physical properties Numerical simulation

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Optimization of Gas-Flooding Fracturing Development in Ultra-Low Permeability Reservoirs

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Fluid Dynamics & Materials Processing 2024年第3期20卷 595-607页

作者： Lifeng Liu Menghe Shi Jianhui Wang Wendong Wang Yuliang Su Xinyu Zhuang Tight Oil Research institute PetroChina Research Institute of Petroleum Exploration&DevelopmentBeijing100083China Key Laboratory of Unconventional Oil&Gas Development China University of Petroleum(East China)Qingdao266580China Oil&Gas Technology Research institute Changqing Oilfield CompanyXi’an710018China

Ultra-low permeability reservoirs are characterized by small pore throats and poor physical properties, which areat the root of well-known problems related to injection and production. In this study, a gas injection floodingapproach is analyzed in the framework of numerical simulations. In particular, the sequence and timing of fracturechanneling and the related impact on production are considered for horizontal wells with different fracturemorphologies. Useful data and information are provided about the regulation of gas channeling and possible strategiesto delay gas channeling and optimize the gas injection volume and fracture parameters. It is shown that inorder to mitigate gas channeling and ensure high production, fracture length on the sides can be controlled andlonger fractures can be created in the middle by which full gas flooding is obtained at the fracture location in themiddle of the horizontal well. A Differential Evolution (DE) algorithm is provided by which the gas injectionvolume and the fracture parameters of gas injection flooding can be optimized. It is shown that an improvedoil recovery factor as high as 6% can be obtained.

关键词： Ultra-low permeability reservoir gas injection flooding component simulation fracture parameters intelligent optimization differential evolution

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Research on Quantitative Identification of Three-Dimensional Connectivity of Fractured-Vuggy Reservoirs

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Energy Engineering 2024年第5期121卷 1195-1207页

作者： Xingliang Deng Peng Cao Yintao Zhang Yuhui Zhou Xiao Luo Liang Wang exploration and Development Research institute PetroChina Tarim Oilfield CompanyKorla841000China PetroChina Hangzhou Research institute of Geology Hangzhou310023China School of petroleum Engineering Yangtze UniversityWuhan430100China

The fractured-vuggy carbonate oil resources in the western basin of China are extremely *** connectivity of carbonate reservoirs is complex,and there is still a lack of clear understanding of the development and topological structure of the pore space in fractured-vuggy ***,effective prediction of fractured-vuggy reservoirs is *** view of this,this work employs adaptive point cloud technology to reproduce the shape and capture the characteristics of a fractured-vuggy *** identify the complex connectivity among pores,fractures,and vugs,a simplified one-dimensional connectivity model is established by using the meshless connection element method(CEM).Considering that different types of connection units have different flow characteristics,a sequential coupling calculation method that can efficiently calculate reservoir pressure and saturation is *** automatic history matching,the dynamic production data is fitted in real-time,and the characteristic parameters of the connection unit are *** results show that the three-dimensional connectivity model of the fractured-vuggy reservoir built in this work is as close as 90%of the fine grid model,while the dynamic simulation efficiency is much higher with good accuracy.

关键词： Fractured-vuggy reservoir three-dimensional connectivity connection unit dynamic prediction automatic history matching

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Seismic identification and characterization of complex storage space oil and gas reservoirs

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Applied Geophysics 2024年第3期21卷 606-615,620页

作者： XiaoYu-Jiang Tao Song Li Deng-Gan Xiao Yue-Zhou Jing Liang Lele-Wei Ming Zhang Xiaofeng-Dai Research institute of petroleum exploration&Development Beijing100083China

To predict complex reservoir spaces(with developed caves,pores,and fractures),based on the results of full-azimuth depth migration processing,we adopted reverse weighted nonlinear inversion to improve the accuracy of porous reservoir *** imaging three-parameter wavelet transform technology was used to accurately predict small-scale cave *** joint inversion method of velocity and amplitude anisotropy was developed to improve the accuracy of small and medium-sized fracture *** results of multiscale fracture modeling and characterization,interwell connectivity analysis,and connection path prediction are consistent with the production ***,based on the above prediction findings,favorable reservoir development areas were *** above ideas and strategies have great application value for the efficient exploration and development of complex storage space reservoirs and the optimization of high-yield well locations.

关键词： complex storage space fracture prediction reservoir prediction cave prediction

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Micromechanism and mathematical model of stress sensitivity in tight reservoirs of binary granular medium

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petroleum Science 2024年第3期21卷 1780-1795页

作者： Jian-Bang Wu Sheng-Lai Yang Qiang Li Kun Yang Can Huang Dao-Ping Lv Wei Zhou State Key Laboratory of petroleum Resources and Engineering China University of Petroleum(Beijing)Beijing2249China Laboratoire de G eologie Ecole Normale Sup erieure/CNRS UMR8538PSL Research UniversityParis75005France Research institute of exploration and Development Xinjiang Oilfield CompanyKaramay834000XinjiangChina

Research on reservoir rock stress sensitivity has traditionally focused on unary granular structures,neglecting the binary nature of real reservoirs,especially tight *** the stresssensitive behavior and mathematical characterization of binary granular media remains a challenging *** this study,we conducted online-NMR experiments to investigate the permeability and porosity evolution as well as stress-sensitive control mechanisms in tight sandy conglomerate *** results revealed stress sensitivity coefficients between 0.042 and 0.098 and permeability damage rates ranging from 65.6%to 90.9%,with an average pore compression coefficient of 0.0168—0.0208 MPa ***-scale compression occurred in three stages:filling,compression,and compaction,with matrix pores playing a dominant role in pore *** stress sensitivity of binary granular media was found to be influenced by the support structure and particle *** stress sensitivity was associated with small fine particle size,high fines content,high uniformity coefficient of particle size,high plastic deformation,and low Young's ***-supported samples exhibited a high irreversible permeability damage rate(average=74.2%)and stress sensitivity coefficients(average=0.089),with pore spaces more *** contrast,grain-supported samples showed low stress sensitivity coefficients(average=0.021)at high stress *** on the experiments,we developed a mathematical model for stress sensitivity in binary granular media,considering binary granular properties and nested interactions using Hertz contact deformation and Poiseuille *** describing the change in activity content of fines under stress,we characterized the non-stationary state of compressive deformation in the binary granular structure and classified the reservoir into three *** model was applied for production prediction using actual data from the Mahu reservoir in China,showing that the e

关键词： Stress sensitivity Binary granular medium Tight reservoir Online-NMR Reservoir energy retention rate

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Catalytic Performance of Aquathermolysis and Viscosity Reduction of Heavy Oil over a WO_(3)/ZrO_(2) Solid Acid

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China petroleum Processing & Petrochemical Technology 2024年第3期26卷 82-92页

作者： Ning Haolong Wu Junwen Shen Zhibing Che Chang Tang Ruiyuan Liang Shengrong Zhang Juntao Jiang Haiyan Yuan Shibao State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development State Center For Research and Development of Oil Shale ExploitationPetroleum Exploration and Production Research InstituteSINOPECBeijing 100083China Xi’an Key Laboratory of Low-carbon Utilization for High-carbon Resources College of Chemistry and Chemical EngineeringXi’an Shiyou UniversityXi’anShaanxi 710065China College of petroleum Engineering Xi’an Shiyou UniversityXi’anShaanxi 710065China.

Tungstated zirconia(WO_(3)/ZrO_(2))solid acid catalysts with different WO_(3) contents were prepared by a hydrothermal method and then used in the catalytic aquathermolysis of heavy oil from *** WO_(3)/ZrO_(2) solid acid catalyst was characterized by a range of characterization methods,including X-ray diffraction,NH3-temperature programmed desorption,and pyridine infrared *** WO_(3) content of the WO_(3)/ZrO_(2) catalysts had an important impact on the structure and property of the *** the WO_(3) mass fraction was 20%,it facilitated the formation of tetragonal zirconia,thereby enhancing the creation of robust acidic *** is considered to have a strong impact on the catalytic performance of the aquathermolysis of heavy *** the catalyst containing 20%WO_(3) was used to catalyze the aquathermolysis of heavy oil under conditions of 14.5 MPa,340℃,and 24 h,the viscosity of heavy oil decreased from 47266 to 5398 mPa·s and the viscosity reduction rate reached 88.6%.The physicochemical properties of heavy oil before and after the aquathermolysis were analyzed using a saturates,aromatics,resins,and asphaltenes analysis,gas chromatography,elemental analysis,densimeter *** the aquathermolysis,the saturate and aromatic contents significantly increased from 43.3%to 48.35%and 19.47%to 21.88%,respectively,with large reductions in the content of resin and asphaltene from 28.22%to 25.06%and 5.36%to 2.03%,*** sulfur and nitrogen contents,and the density of the oil were significantly *** factors were likely the main reasons for promoting the viscosity reduction of heavy oil during the aquathermolysis over the WO_(3)/ZrO_(2) solid acid catalysts.

关键词： heavy oil aquathermolysis viscosity reduction WO_(3)/ZrO_(2)solid acid catalyst

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Hydrocarbon gas huff-n-puff optimization of multiple horizontal wells with complex fracture networks in the M unconventional reservoir

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petroleum Science 2024年第2期21卷 1018-1031页

作者： Hao-Chuan Zhang Yong Tang You-Wei He Yong Qin Jian-Hong Luo Yu Sun Ning Wang De-Qiang Wang State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation Southwest Petroleum UniversityChengdu610500SichuanChina CNPC Research institute of petroleum exploration&Development Beijing100083China Southwest Oil&Gas Field Company PetroChinaChengdu610051SichuanChina State Key Laboratory of Offshore Oil Exploitation CNOOC Research Institute Co.LtdBeijing100027China

The oil production of the multi-fractured horizontal wells(MFHWs) declines quickly in unconventional oil reservoirs due to the fast depletion of natural energy. Gas injection has been acknowledged as an effective method to improve oil recovery factor from unconventional oil reservoirs. Hydrocarbon gas huff-n-puff becomes preferable when the CO_(2) source is limited. However, the impact of complex fracture networks and well interference on the EOR performance of multiple MFHWs is still unclear. The optimal gas huff-n-puff parameters are significant for enhancing oil recovery. This work aims to optimize the hydrocarbon gas injection and production parameters for multiple MFHWs with complex fracture networks in unconventional oil reservoirs. Firstly, the numerical model based on unstructured grids is developed to characterize the complex fracture networks and capture the dynamic fracture ***, the PVT phase behavior simulation was carried out to provide the fluid model for numerical simulation. Thirdly, the optimal parameters for hydrocarbon gas huff-n-puff were obtained. Finally, the dominant factors of hydrocarbon gas huff-n-puff under complex fracture networks are obtained by fuzzy mathematical method. Results reveal that the current pressure of hydrocarbon gas injection can achieve miscible displacement. The optimal injection and production parameters are obtained by single-factor analysis to analyze the effect of individual parameter. Gas injection time is the dominant factor of hydrocarbon gas huff-n-puff in unconventional oil reservoirs with complex fracture networks. This work can offer engineers guidance for hydrocarbon gas huff-n-puff of multiple MFHWs considering the complex fracture networks.

关键词： Unconventional oil reservoir Complex fracture network Hydrocarbon gas huff-n-puff Parameter optimization Numerical simulation

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Sand control mechanism of radial well filled with phase change material in hydrate reservoir

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petroleum Science 2024年第4期21卷 2571-2582页

作者： Xiao-Qiang Liu Zhong-Xi Han Zhi-Lin Luo Hai-Long Lu Ying Sun Qing You Tian-Kui Guo Zhan-Qing Qu School of Energy Resources China University of Geosciences (Beijing) Beijing Key Laboratory of Unconventional Natural Gas Geological Evaluation and Development Engineering China University of Geosciences (Beijing) China Research institute of petroleum exploration and Development Engineering Technology Research institute of Southwest Oil & Gas Field Company PetroChina Beijing International Center for Gas Hydrate School of Earth and Space Sciences Peking University School of Advanced Material Peking University Shenzhen Graduate School School of petroleum Engineering China University of Petroleum (East China)

Radial well filled with phase change material has been proposed as a novel sand control method for hydrate exploitation. In order to reveal the sand control mechanism, CFD-DEM coupling method is applied to simulate the migration, settlement, and blockage processes of sand particles in the radial *** obtained results indicate that three scenarios have been recognized for sand particles passing through sand control medium, based on the diameter ratio of sand control medium to sand particle（Dd）:fully passing（Dd= 8.75-22.5）, partially passing and partially blocked（Dd= 3.18-5.63）, and completely blocked（Dd= 2.18-3.21）. After being captured by the sand control medium, sand particles can block pores, which increases fluid flow resistance and causes a certain pressure difference in the radial *** pressure in the radial well should be lower than the hydrate phase equilibrium pressure during sand control design, for the purpose of promoting hydrate decomposition, and sand capture. The length of the radial well should be optimized based on the reservoir pore pressure, production pressure difference,bottom hole pressure, and the pressure gradient in the radial well. It should be noticed that the sand control medium leads to a decrease in permeability after sand particles captured. Even the permeability is reduced to several hundred millidarcy, it is still sufficient to ensure the effective flow of gas and water after hydrate decomposition. Increasing fluid velocity reduces the blocking capacity of the sand control medium, mainly because of deterioration in bridging between sand particles.

关键词： Hydrate reservoir Sand control Radial well CFD-DEM

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Study on the Impact of Massive Refracturing on the Fracture Network in Tight Oil Reservoir Horizontal Wells

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Fluid Dynamics & Materials Processing 2024年第5期20卷 1147-1163页

作者： Jianchao Shi Yanan Zhang Wantao Liu Yuliang Su Jian Shi exploration and Development Research institute Changqing Oilfield CompanyXi’an710018China National Engineering Laboratory for exploration and Development of Low Permeability Oil and Gas Fields Xi’an710018China Key Laboratory of Unconventional Oil and Gas Development(China University of petroleum(East China)) Ministry of EducationQingdao266580China

Class III tight oil reservoirs have low porosity and permeability,which are often responsible for low production rates and limited *** repeated fracturing is a well-known technique to fix some of these *** such methods,existing fractures are refractured,and/or new fractures are created to facilitate communication with natural *** study explored how different refracturing methods affect horizontal well fracture networks,with a special focus on morphology and related fluid flow *** particular,the study relied on the unconventional fracture model(UFM).The evolution of fracture morphology and flow field after the initial fracturing were analyzed *** simulation results indicated that increased formation energy and reduced reservoir stress differences can promote fracture *** was shown that the length of the fracture network,the width of the fracture network,and the complexity of the fracture can be improved,the oil drainage area can be increased,the distance of oil and gas seepage can be reduced,and the production of a single well can be significantly increased.

关键词： Type III tight oil reservoirs refracturing methods horizontal wells fracture network study fracture network evolution

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A typical Riedel Shear Pattern of active faults in the Laolongwan Basin， Northeastern Tibetan Plateau

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Journal of Earth Science 2024年

作者： Kai-Xun WANG Xiao-Gang LI Wei SHI Xiang-You FENG Qian YANG Jie LI Zheng-Jian XU Zhou-Jun PENG Shao-Hua XU Yi-Xue XIONG Mao LIN School of petroleum Engineering， Chongqing University of Science and Technology Chongqing Key Laboratory of Complex Oil and Gas Field exploration and Development， Chongqing University of Science and Technology Geophysics Research institute of Jiangsu Oilfield Company，sinopec SinoProbe Laboratory， Chinese Academy of Geological Sciences Academy of Dazu Rock Carvings

Riedel shear system， consists of some different oriented faults and derivative structures， is an important pattern of tectonic activity and stress regulation， which has been widely applied to the interpretation of intracontinental deformation. The Laolongwan Basin， located in the western Haiyuan fault zone at the northeastern Tibetan Plateau， is a key area to study the Cenozoic intracontinental deformation in the northeastern plateau， which formed a complex active fault system during the Cenozoic. However， the activity of these faults and their kinematic mechanism remain unclear. In this contribution， based on detailed structural interpretation of remote sensing image， field observations and OSL dating analysis， we propose a Riedel Shear model of active fault system in the Laolongwan basin. Our observations show that this active fault system is consist of four major faults， including the left strike-slip Hasi Shan Fault and Zihong Shan Fault with thrusting characteristics， the Southern Zihong Shan thrust fault and the Mijia Shan normal fault. The fault offset and OSL dating analyses suggest that the left-lateral slip rate of the Hasi Shan Fault is ～ 2.60-3.01 mm/a since ca. 15 ka， whereas the Zihong Shan Fault is ～ 1.10-1.13 mm/a since ca. 14 ka. Fault-slip vectors analyses indicate that the active fault system related to the Riedel Shear in the Laolongwan Basin was controlled by the regional ENE-WSW compressive stress. This compression also caused the significant left-lateral strike-slip movement along the Haiyuan Fault zone at the same time， which might result from the northeastward continuous expanding of the Tibetan Plateau during the late Cenozoic.

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