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Prospect of Sinopec's Exploration for Natural Gas 认领 引用
1
作者 Long Shengxiang Zhu Hong Zhu Tong Chen Chunfang Xiao Kaihua 《China Oil & Gas》 CAS 2008年第3期22-27,共6页
Current state of Sinopec’s exploration for natural gasDistribution of exploration area and resource baseSinopec now owns the exploration right of 364 blocks, with the acreage about one million square kilometers. The ... Current state of Sinopec’s exploration for natural gasDistribution of exploration area and resource baseSinopec now owns the exploration right of 364 blocks, with the acreage about one million square kilometers. The company mainly carries out exploration for oil and 展开更多
关键词 中石化集团 天然气勘探 油气生产 石油炼制
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Sinopec's Non-fuel Profit Rises Significantly in First Half of 2016 认领 引用
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作者 Wei Haifeng 《China Oil & Gas》 CAS 2016年第3期38-40,共3页
China’s largest oil refiner China Petrochemical Corporation,also known as Sinopec Group,saw its non-fuel sales surge 43 percent in the first half of this year amid falling crude oil prices.The Beijing-based company’... China’s largest oil refiner China Petrochemical Corporation,also known as Sinopec Group,saw its non-fuel sales surge 43 percent in the first half of this year amid falling crude oil prices.The Beijing-based company’s non-fuel profits rose 42 percent from January to June,while sales of its retail oil products grew 3. 展开更多
关键词 Sinopec’s Non-fuel Profit Rises Significantly in First Half of 2016 than CNPC down more
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Optimizing the development plan for oil production and CO2 storage in target oil reservoir 认领 引用 被引量：1
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作者 Xiliang Liu Hao Chen +4 位作者 Yang Li Weiming Cheng Yangwen Zhu Hongbo Zeng Haiying Liao 《Energy Geoscience》 EI CAS CSCD 2025年第2期342-351,共10页
Carbon dioxide enhanced oil recovery(CO2-EOR)technology is used for oil production and CO2 storage in reservoirs.Methods are being constantly developed to optimize oil recovery and CO2 storage during the CO_(... Carbon dioxide enhanced oil recovery(CO2-EOR)technology is used for oil production and CO2 storage in reservoirs.Methods are being constantly developed to optimize oil recovery and CO2 storage during the CO2 displacement process,especially for low-permeability reservoirs under varying geological conditions.In this study,long-core experiments and trans-scale numerical simulations are employed to examine the characteristics of oil production and CO2 storage.Optimal production parameters for the target reservoir are also proposed.The results indicate that maintaining the pressure at 1.04 to 1.10 times the minimum miscible pressure(MMP)and increasing the injection rate can enhance oil production in the early stage of reservoir development.In contrast,reducing the injection rate at the later stages prevents CO2 channeling,thus improving oil recovery and CO2 storage efficiency.A solution-doubling factor is introduced to modify the calculation method for CO2 storage,increasing its accuracy to approximately 90%.Before CO2 breakthrough,prioritizing oil production is recommended to maximize the economic benefits of this process.In the middle stage of CO2 displacement,decreasing the injection rate optimizes the coordination between oil displacement and CO2 storage.Further,in the late stage,reduced pressure and injection rates are required as the focus shifts to CO2 storage. 展开更多
关键词 CO2displacement CO2storage Carbon dioxide enhanced oil recovery(CO2-EOR) Low-permeability oil reservoir Degree of miscibility
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Segmented evolution and exploration targets of the Cambrian platform margin in the Manxi area, Tarim Basin 认领 引用
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作者 Zongquan Hu Fan Feng +5 位作者 Chengming Fang Zicheng Cao Tieyi Wang Kangkang Guo Yang Li Shi Wang 《Energy Geoscience》 EI CAS CSCD 2025年第1期194-208,共15页
The Cambrian platform margin in the Tarim Basin boasts favorable source-reservoir-cap assemblages,making it a significant target for hydrocarbon exploration in ultra-to extra-deep facies-controlled for-mations.Of the ... The Cambrian platform margin in the Tarim Basin boasts favorable source-reservoir-cap assemblages,making it a significant target for hydrocarbon exploration in ultra-to extra-deep facies-controlled for-mations.Of the three major basins in western China,Tarim is the only basin with large-scale platform margin where no exploration breakthrough has been achieved yet.This study determines the vertical and lateral differential evolution of the platform margin(in the Manxi area hereafter referred to as the Cambrian Manxi platform margin)through fine-scale sequence stratigraphic division and a segmented analysis.The platform margin can be divided into the Yuqi,Tahe,Shunbei,and Gucheng segments,from north to south,based on the development of different ancient landforms and the evolutionary process of the platform.The Yuqi and Shunbei segments exhibit relatively low-elevation ancient landforms.Both segments were in a submarine buildup stage during the Early Cambrian,resulting in overall limited scales of their reservoirs.The Gucheng segment features the highest-elevation ancient landforms and accordingly limited accommodation spaces.As a result,the rapid lateral migration of high-energy facies zones leads to the development of large-scale reservoirs with only limited thicknesses.In contrast,the Tahe segment,exhibiting comparatively high-elevation ancient landforms,is identified as the most favorable segment for the formation of large-scale reservoirs.The cap rocks of the platform margin are dominated by back-reef dolomitic flats and tight carbonate rocks formed in transgressive periods.A comprehensive evaluation of source rocks,reservoirs,and cap rocks indicates that the Tahe segment boasts the optimal hydrocarbon accumulation conditions along the platform margin.In this segment,the Shayilike Formation transgressive deposits and the high-energy mound-shoal complexes along the platform margin of the Wusonggeer Formation constitute the optimal reservoir-cap rock assemblage,establishing this segment as the most promising target for hydrocarbon exploration in the platform margin. 展开更多
关键词 Tarim basin Cambrian Manxi platform margin Differential evolution Segmented characteristics
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Big data-driven analysis of shale gas enrichment patterns:A case study of the Wufeng–Longmaxi Formation in the Sichuan Basin and its periphery 认领 引用 被引量：1
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作者 Zongquan Hu Jin Meng +10 位作者 Wei Du Yitian Xiao Chuanxiang Sun Guanping Wang Baojian Shen Tianrui Ye Dongjun Feng Zengqin Liu Longfei Lu Ruyue Wang Qianru Wang 《Energy Geoscience》 EI CAS CSCD 2026年第1期166-178,共13页
The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation,found in sequence in the Sichuan Basin.This formation hosts rich shale gas reservoir... The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation,found in sequence in the Sichuan Basin.This formation hosts rich shale gas reservoirs,and its shale gas enrichment patterns are examined in this study using data from 1197 shale samples collected from 14 wells.Five basic and three key parameters,eight in all,are assessed for each sample.The five basic parameters include burial depth and the contents of four mineral types—quartz,clay,carbonate,and other minerals;the three key parameters,representing shale gas enrichment,are total organic carbon(TOC)content,porosity,and gas content.The SHapley Additive exPlanations(SHAP)analysis originated in game theory is used here in an interpretable machine learning framework,to address issues of heterogeneous data structure,noisy relationships,and multi-objective optimization.An evaluation of the ranking,contribution values,and conditions of changes for these parameters offers new quantitative insights into shale gas enrichment patterns.A quantitative analysis of the relationship between data-sets identifies the primary factors controlling TOC,porosity,and gas content of shale gas reservoirs.The results show that TOC and porosity jointly influence gas content;mineral content has a significant impact on both,TOC and porosity;and the burial depth governs porosity which,in turn,affects the conditions under which shale gas is preserved.Input parameter thresholds are also determined and provide a basis for the establishment of quantitative criteria to evaluate shale gas enrichment.The predictive accuracy of the model used in this study is significantly improved by the step-wise addition of two input parameters,namely TOC and porosity,separately and together.Thus,the game theory method in big data-driven analysis uses a combination of TOC and porosity to evaluate the gas content with encouraging results—suggesting that these are the key parameters that indicate source rock and reservoir properties. 展开更多
关键词 Big data-driven analysis Primary controlling factor Shale gas enrichment pattern Wufeng–Longmaxi Formation Sichuan basin
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Experimental techniques for qualitative and quantitative characterization of shale oil reservoir space,minerals,and fluids 认领 引用 被引量：1
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作者 Siyu Chen Zhenkai Huang +6 位作者 Guangyou Zhu Xi Li Zhiyong Chen Ruilin Wang Yue Huang Shengnan Liu Bijun Huang 《Energy Geoscience》 EI CAS CSCD 2026年第2期1-16,共16页
Characterizing shale oil reservoirs encompassing pore space,mineralogy,and fluids is fundamental to effective exploration and development.Recent advances in experimental techniques have significantly improved both the... Characterizing shale oil reservoirs encompassing pore space,mineralogy,and fluids is fundamental to effective exploration and development.Recent advances in experimental techniques have significantly improved both the qualitative and quantitative analysis of these components;however,a comprehensive systematic review is lacking.High-resolution imaging technologies,such as Scanning Electron Microscopy(SEM),Field Emission Scanning Electron Microscopy(FE-SEM),and Focused Ion Beam Scanning Electron Microscopy(FIB-SEM),enable detailed visualization of pore structures.Gas adsorption and high-pressure mercury intrusion methods provide accurate pore-scale quantification.Moreover,techniques like X-ray Diffraction(XRD),X-ray Fluorescence Spectroscopy(XRF),and Electron Probe Microanalysis(EPMA)allow precise mineral identification and compositional analysis.Confocal Scanning Laser Microscopy(CSLM),Raman Spectroscopy,Nuclear Magnetic Resonance(NMR),and Rock Pyrolysis provide insights into fluid occurrence and content within shale reservoirs.Based on a comprehensive review of existing research,this study identifies several key future directions:(1)addressing the challenges of nanopore observation in reservoir space characterization while minimizing the impact of sample preparation on pore structure;(2)improving the accuracy of quantitative mineral analysis and developing advanced new technologies for the precise measurement of complex mineral compositions;(3)enhancing the fluid quantitative evaluation of fluids by more effectively restoring subsurface geological conditions.This paper presents a current synthesis and forward-looking perspective on experimental techniques supporting shale oil exploration,aiming to guide future research and technological innovation in this field. 展开更多
关键词 Experimental technique Shale oil Reservoir space Mineral analysis Fluid characterization Qualitative and quantitative analysis
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Spatiotemporal distribution patterns and exploration implications of multi-type coal-measure gases in the Daniudi gas field,Ordos Basin,China 认领 引用
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作者 Zhenrui Bai Fengcun Xing Zengqin Liu 《Energy Geoscience》 EI CAS CSCD 2025年第3期133-142,共10页
Coal-measure gas is a primary target with significant potential for the exploration of unconventional hydrocarbon resources.However,the spatiotemporal distribution and combination patterns of multi-type coal-measure g... Coal-measure gas is a primary target with significant potential for the exploration of unconventional hydrocarbon resources.However,the spatiotemporal distribution and combination patterns of multi-type coal-measure gases are yet to be clarified,directly impeding the sweet spot evaluation and exploration deployment of coal-measure gas.This study discussed the characteristics and distribution patterns of coal-measure gases in the Daniudi gas field in northeastern Ordos Basin,China,with abundant drilling data.The results indicate that the coal seams variably thin upward and are mainly seen in the first and second members of the Taiyuan Formation(also referred to as the Tai 1 and Tai 2 members,respectively)and the first member of the Shanxi Formation(Shan 1 Member).Nos.8,5 and 3 coal seams are laterally continuous,and significantly thicker in its southern part compared to the northern part.Moreover,carbonaceous mudstones and shales are better developed in the southern part,where limestones are only observed in the Tai 1 Member.Based on the main lithological types,we identified three lithologic roofs of coal seams,that is,limestone,mudstone,and sandstone,which determine the spatiotemporal distribution of coal-measure gases.Besides bauxite gas in the Benxi Formation,the coal-measure gases include tight-sand gas,coalbed methane(CBM),coal-measure shale gas,and tight-limestone gas,with CBM typically associated with coal-measure shale gas.The combinations of different types of coal-measure gas vary across different layers and regions.Tight-sand gas is well-developed in areas where tight sandstones are in contact with coal-measures.From the Taiyuan to the Shanxi formations,CBM gradually transitions into a combination of CBM and coal-measure shale gas,and coal-measure shale gas.Nos.8 and 5 coal seams in low-lying areas exhibit favorable gas-bearing properties due to their large thickness and favorable roof lithologies,serving as prospective play fairways.Mudstone and limestone roofs are more conducive to achieving good gas-bearing properties.The direct contact between sandstones and coal seams tends to result in the formation of tight-sand gas and a reduced gas content of CBM.While focusing on single types of gas reservoirs such as CBM and tight-sand gas,it is essential to consider the concurrent exploration of various coal-measure gas combinations to discover more additional gas resources and guide exploration deployment. 展开更多
关键词 Coal-measure gas Coal-measure shale gas Coalbed methane(CBM) Tight-sand gas Lithologic assemblage Distribution pattern of gas reservoirs
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Numerical Simulation on Depressurization-Driven Production of Class I Hydrate Deposits with Transition Layer and Perforation Modes Optimization 认领 引用
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作者 Yajie Bai Jian Hou Yongge Liu 《Energy Engineering》 EI 2025年第6期2503-2518,共16页
Natural gas hydrate widely exists in the South China Sea as clean energy.A three-phase transition layer widely exists in low permeability Class I hydrates in the Shenhu offshore area.Therefore,taking into account the ... Natural gas hydrate widely exists in the South China Sea as clean energy.A three-phase transition layer widely exists in low permeability Class I hydrates in the Shenhu offshore area.Therefore,taking into account the low-permeability characteristics with an average permeability of 5.5 mD and moderate heterogeneity,a 3-D geological model of heterogeneous Class I hydrate reservoirs with three-phase transition layers is established by Kriging interpolation and stochastic modeling method,and a numerical simulation model is used to describe the depressurization production performance of the reservoir.With the development of depressurization,a specific range of complete decomposition zones appear both in the hydrate and transition layers.The entire decomposition zone of the whole reservoir tends to outward and upward diffusion.There is apparent methane escape in the three-phase transition layer.Due to the improvement of local permeability caused by the phase transition of hydrate dissociation,some methane accumulation occurs at the bottom of the hydrate layer,forming a local methane enrichment zone.The methane migration trends in reservoirs are mainly characterized by movement toward production wells and hydrate layers under the influence of gravity.However,due to the permeability limitation of hydrate reservoirs,many fluids have not been effectively produced and remain in the reservoir.Therefore,to improve the effective pressure drop of the reservoir,the perforation method and pressure reduction method were optimized by analyzing the influencing factors based on the gas production rate.The comparative study demonstrates that perforating through the free gas layer combined with one-time depressurization can enhance the effective depressurization and improve production performance.The gas production rate from perforating through the free gas layer can be twice as high as that from perforating through the transition layer.This study can provide theoretical support for the utilization of marine energy. 展开更多
关键词 Class I hydrate transitional layers heterogeneity depressurization numerical simulation perforation mode
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Progress in research on the exploration and evaluation of deep geothermal resources in the Fujian-Guangdong-Hainan region,China 认领 引用 被引量：6
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作者 Herong Zheng Jun Luo 《Energy Geoscience》 EI 2024年第2期1-13,共13页
Deep geothermal resources in the Fujian-Guangdong-Hainan region,China,offer significant potential for sustainable energy.The diverse igneous rock formations along the southeast coast present intricate geological chall... Deep geothermal resources in the Fujian-Guangdong-Hainan region,China,offer significant potential for sustainable energy.The diverse igneous rock formations along the southeast coast present intricate geological challenges that impede exploration and evaluation efforts.In this study,we address critical concerns related to the Fujian-Guangdong-Hainan region's deep geothermal resources,encompassing heat source composition,formation conditions,strategic favorable areas,and exploration directions.Our methods involve the analysis of regional geothermal reservoirs and cap rocks.Major findings include:the primary heat sources in the Fujian-Guangdong-Hainan region consist of the radioactive heat generation from granites in the crust,heat conduction in the mantle,and,in specific areas like Yangjiang and Shantou,melts within the middle and lower crust;the deep,high-temperature geothermal resources in the region predominantly reside in basins'depressed areas.These areas are characterized by the confluence of triple heat sources:heat from the Earth's crust,mantle,and other supplementary sources;our analysis led to the identification of three strategic areas favorable for deep geothermal resources in the Fujian-Guangdong-Hainan region.These are the Beibu Gulf Basin's continental area,the Yuezhong Depression,and the Fuzhou-Zhangzhou area. 展开更多
关键词 Deep geothermal resources Geology of geothermal energy Strategic selection
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Analysis and Modelling of Salt-related Deformation in the Western Sichuan Foreland Basin,China 认领 引用
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作者 QIU Dengfeng HU Zongquan +2 位作者 John J.WALSH GUO Jinrui ZHANG Zhongming 《Acta Geologica Sinica(English Edition)》 SCIE CAS CSCD 2026年第1期265-285,共21页
The Western Sichuan Foreland Basin(WSFB)in South China,a prolific hydrocarbon province,exhibits complex structural deformation influenced by Triassic salt tectonics.This paper integrates seismic data and well data to ... The Western Sichuan Foreland Basin(WSFB)in South China,a prolific hydrocarbon province,exhibits complex structural deformation influenced by Triassic salt tectonics.This paper integrates seismic data and well data to elucidate the role of Middle-Lower Triassic evaporite layers in shaping basin structures,focusing on Xinchang Tectonic Zone(XTZ).Salt layers facilitated decoupled deformation between supra-and sub-salt sequences,forming salt pillows and fault-related folds.Three distinct structural trends were identified in XTZ.Key findings reveal that salt thickness variations correlate with deformation styles:thicker salt promoted detachment folding,while thinner salt led to hard-linked fault systems.Sub-salt E-NE trending reverse faults formed horsetail terminations associated with the Pengzhou faults(PzF),deviating from the primary Longmenshan thrust belt(LmsTB)orientation.Structural evolution occurred in three stages:(1)Indosinian salt deposition and foreland basin initiation;(2)Yanshanian eastward propagation of thrust systems with salt-driven detachment folding;(3)Himalayan reactivation overprinting earlier structures with sub-NS trending folds.This work establishes a direct link between salt layers and structural traps,demonstrating how salt acted as a critical detachment layer during multi-stage compression.Results provide insights into the gas exploration of the Late Triassic Xujiahe Formation,emphasizing the importance of salt-influenced deformation in foreland basin systems. 展开更多
关键词 salt structure fault horsetail terminations foreland basin western Sichuan
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Geochemical Characteristics and Origin of Natural Gas from the Ordovician Middle Gas-bearing Assemblage in the Ordos Basin:A Case Study of the Daniudi Gas Field 认领 引用
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作者 WU Xiaoqi WANG Ping +5 位作者 LIU Quanyou NI Chunhua ZHANG Yi ZHU Dongya JIA Huichong XIANG Liange 《Acta Geologica Sinica(English Edition)》 SCIE CAS CSCD 2026年第1期188-199,共12页
The Ordovician Majiagou Formation(O1m)in the Ordos Basin is a crucial exploration field for natural gas,and exploration of the Ordovician middle assemblage(O1m55-7)has recently yielded great breakthrough.The ... The Ordovician Majiagou Formation(O1m)in the Ordos Basin is a crucial exploration field for natural gas,and exploration of the Ordovician middle assemblage(O1m55-7)has recently yielded great breakthrough.The Daniudi gas field provides a good case study to determine the gas source for the strata.The O1m55-7gas displays C1/C1-5 ratios of 0.932-0.985 and CO2contents of 1.56%-11.75%,and the detectable H2S content ranges from 0.0002%to 1.8617%.Theδ13C1,δ13C2,δ13CCO2,andδD1values are−39.7‰to−35.6‰,−30.4‰to−23.7‰,−12.4‰to−4.6‰,and−204‰to−185‰,respectively.Identification of the gas origin and source indicates that the gaseous alkanes are commonly coal-derived gas.The gas was generated from the coal measures in the Taiyuan Formation(C3t)and subsequently migrated.A small amount of oil-associated gas,mainly from O1m carbonate source rocks,has been incorporated into the gas reservoir.The natural gas has experienced insignificant alteration by thermochemical sulfate reduction,and the relatively high levels of CO2are probably associated with corrosion alteration of carbonate reservoirs by injected fluid during acid fracturing. 展开更多
关键词 geochemical characteristics stable isotopic compositions genetic types thermochemical sulfate reduction gas-source correlation Ordovician Majiagou Formation Daniudi gas field
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Microfluidic technology in oil and gas reservoir development:Applications and challenges 认领 引用
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作者 Jianchao Cai Jin Yang +1 位作者 Lin Meng Lufeng Zhang 《International Journal of Coal Science & Technology》 SCIE EI CAS CSCD 2026年第1期387-392,共6页
Microfluidic technology,as an advanced experimental technique at the microscale,demonstrates significant potential for application in oil and gas reservoir development.By constructing microscopic models with varying p... Microfluidic technology,as an advanced experimental technique at the microscale,demonstrates significant potential for application in oil and gas reservoir development.By constructing microscopic models with varying pore structures and surface chemical properties,this technology can simulate fluid displacement behaviors in different types of reservoirs.Through the modification of fluid properties and displacement conditions in experiments,it allows for the quantitative analysis of fluid distribution characteristics during displacement processes.This provides valuable technical tools for studying the microscopic mechanisms of CO2 flooding,chemical flooding,and other enhanced oil/gas recovery techniques.This paper reviews the unique advantages of microfluidic technology in revealing pore-scale transport behaviors and optimizing development strategies,while also analyzing the current challenges associated with its application.With advancements in materials science and manufacturing technologies,microfluidic technology is expected to play an increasingly prominent role in reservoir development,offering new technical support for the efficient development of oil and gas reservoirs. 展开更多
关键词 Microfluidic technology Reservoir development Fluid distribution Pore-scale transport
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Mechanisms and Controlling Factors of Displacement-Front Evolution during Chemical Flooding in HighWater-Cut Reservoirs 认领 引用
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作者 Dejun Wu Chunlei Yu +3 位作者 Xuan Lu Deshuo Tao Xiaoning Li Hao Song 《Fluid Dynamics & Materials Processing》 EI 2026年第6期265-284,共20页
To address the short peak-production period and limited incremental recovery commonly encountered during chemical flooding of high water-cut reservoirs,this study investigates the dynamic evolution of displacement fro... To address the short peak-production period and limited incremental recovery commonly encountered during chemical flooding of high water-cut reservoirs,this study investigates the dynamic evolution of displacement fronts and their controlling factors through laboratory experiments and numerical simulation.Two-dimensional plate flooding experiments were first conducted to characterize the evolution of the oil bank in homogeneous and heterogeneous reservoirs,revealing a four-stage process of formation,enrichment,mobilization,and residual depletion.Based on water-cut behavior,the flooding process was further classified into early-response,peak-response,and late-response stages.A three-dimensional heterogeneous reservoir model was subsequently developed to quantify the spatiotemporal evolution of the pressure,oil-bank,and chemical-agent fronts.The results show a clear displacementfront sequence,with the pressure front leading,the oil bank occupying the intermediate zone,and the chemical-agent front trailing behind.Sensitivity analyses demonstrate that the flooding system,chemical concentration,and slug size significantly influence oil-bank development.Compared with polymer flooding and polymer-surfactant flooding,the heterogeneous flooding system increases the maximum oil-bank magnitude by 72% and 43%,respectively.Higher chemical concentrations promote oil-bank enrichment,although the incremental benefit gradually diminishes.In addition,a critical slug size of approximately 0.4 PV is identified,beyond which further increases yield limited improvement. 展开更多
关键词 Chemical flooding front characterization oil bank migration evolution patterns physical simulation numerical simulation influencing factors
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Multi-source and multi-attribute collaborative fracture network modeling of a sandstone reservoir in Ordos Basin 认领 引用
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作者 Yinbang Zhou 《Energy Geoscience》 EI CAS CSCD 2026年第1期214-223,共10页
The effective channeling of fluid flow by fractures is a liability for enhanced oil recovery(EOR)methods like CO2 flooding or CO2 storage.Developing a distributed fracture model to understand the heterogeneity o... The effective channeling of fluid flow by fractures is a liability for enhanced oil recovery(EOR)methods like CO2 flooding or CO2 storage.Developing a distributed fracture model to understand the heterogeneity of the fracture network is essential in characterizing tight and low-permeability reservoirs.In the Ordos Basin,the Chang 8-1-2 layer of the Yanchang Formation is a typical tight and low permeability reservoir in the JH17 wellblock.The strong heterogeneity of distributed fractures,differing fracture scales and fracture types make it difficult to effectively characterize the fracture distribution within the Chang 8-1-2 layer.In this paper,multi-source and multi-attribute methods are used to integrate data into a neural network at different scales,and fuzzy logic control is used to judge the correlation of various attributes.The results suggest that attribute correlation between coherence and fracture indication is the best,followed by correlations with fault distance,north–south slope,and north–south curvature.Advantageous attributes from the target area are used to train the neural network,and the fracture density model and discrete fracture network(DFN)model are built at different scales.This method can be used to effectively predict the distribution characteristics of fractures in the study area.And any learning done by the neural network from this case study can be applied to fracture network modeling for reservoirs of the same type. 展开更多
关键词 Tight oil reservoir CO2flooding CO2storage Reservoir fracture Fracture network modeling Fracture density
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Reinterpretation of volcanic and hydrothermal influence on organic matter accumulation and paleo-depositional environment in a lacustrine shale system:Insight from interpretable machine learning model 认领 引用
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作者 Enze Wang Xiaoxiao Ma +7 位作者 Maowen Li Yingxiao Fu Menhui Qian Tingting Cao Zhiming Li Yue Feng Zhijun Jin Tong Li 《Petroleum Science》 SCIE EI CAS CSCD 2026年第6期3037-3058,共22页
The significant resource potential of lacustrine shale oil has spurred interest in understanding organic matter enrichment mechanisms.However,conventional analytical methods are often constrained by multicollinearity ... The significant resource potential of lacustrine shale oil has spurred interest in understanding organic matter enrichment mechanisms.However,conventional analytical methods are often constrained by multicollinearity and statistical limitations,hindering accurate identification of enrichment mechanisms under complex depositional conditions.Interpretable machine learning models present a viable alternative to address this issue.The 7th member of the Yanchang Formation(T3y7)is one of the key targets for lacustrine shale oil exploration and development in China.Nevertheless,the role of volcanic activity in organic matter accumulation within this unit remains controversial,hindering a comprehensive understanding of organic enrichment mechanisms in lacustrine systems.To address this challenge,this study integrates geochemical data from YYa borehole in the southern Ordos Basin and previously published datasets to reconstruct the paleoenvironmental settings of various lithofacies assemblages in the T3y7 shale.By leveraging published literature and new experimental data,this study develops an interpretable machine learning model based on random forest(RF),extreme gradient boosting(XGBoost),and support vector machine(SVM)to quantitatively determine the dominant controls on organic matter accumulation.Using the T3y7 shale as a case study,the influence mechanisms of both volcanic and hydrothermal activities on organic enrichment in lacustrine shale systems are further explored.Two distinct lithofacies assemblages were identified in the T3y7 shale:laminated black shale and massive dark-gray mudstone.These assemblages are characterized by significant differences in paleoclimate,salinity,redox conditions,primary productivity,terrigenous influx,and the intensity of volcanic and hydrothermal activities.Results from the interpretable machine learning model indicate that organic matter enrichment in the T3y7 shale is primarily governed by the coupling of high primary productivity and favorable preservation conditions,and decoupling of volcanic and hydrothermal activities was a significant factor in the development of different lithofacies in the T3y7.Importantly,the influence of volcanic activity on organic matter enrichment in lacustrine systems is nonlinear:while moderate volcanic activity promotes organic accumulation,intense volcanic activity tends to exert a detrimental effect.In contrast,hydrothermal activity appears to play a more consistently positive role in the formation of organic-rich shale in the T3y7.These findings highlight the need to distinguish between volcanic and hydrothermal processes in future studies in order to more obje ctive ly evaluate their respective impacts on organic-rich shale development in lacustrine settings.This study provide s a robust frame work for understanding the mechanisms of organic matter enrichment in shale deposited under complex geological conditions,and deepens our insight into the formation of organic-rich shale in lacustrine sedimentary systems influenced by volcanic and hydrothermal activity. 展开更多
关键词 Lacustrine shale Paleoenvironment reconstruction Interpretable machine leaning Volcanic and hydrothermal activity Organic matter enrichment mechanisms Ordos Basin
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Petrographic,Mineralogical and Geochemical Constraints on the Origin of Regional-Scale Dolomitization:A Case Study of the Cambrian–Lower Ordovician Dolomites in the Bachu Area,Central Tarim Basin,China 认领 引用
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作者 Miao Li Yushuang Zhou +3 位作者 Yongqiang Zhao Juan Xu Fei Wu Feng Geng 《Journal of Earth Science》 SCIE CAS CSCD 2026年第1期23-35,共13页
The Cambrian and Lower Ordovician strata of the Bachu area in central Tarim Basin are characterized by extensively dolomitized,which have significant potential for favourable hydrocarbon reservoirs.The study herein co... The Cambrian and Lower Ordovician strata of the Bachu area in central Tarim Basin are characterized by extensively dolomitized,which have significant potential for favourable hydrocarbon reservoirs.The study herein combined petrographic,mineralogical and geochemical analyses to investigate the formation environments of these dolomite units and utilized Mg isotopic profiles to constrain the changes in the fluid flow trajectory.Positive excursions of δ18O and upwardincreasing δ26Mg profiles were observed in samples of the Wusonger formation(Є1w),which may result from evaporation.Moreover,based on high 87Sr/86Sr ratios,high total REE concentrations and the occurrence of specific minerals,including quartz,barite,gypsum and pyrite,we interpret an evaporitic near-surface origin for the Є1w dolomites.Samples of the Xiaoerblak Formation(Є1x)are the product of seepage-reflux dolomitization,suggested by upward-decreasing δ26Mg profiles and relatively lower 87Sr/86Sr ratios than the Є1w samples.The overlapping isotope(δ18O,δ13C and 87Sr/86Sr)values between samples of the Shayilik(Є2s)and Awatagh(Є2a)Formation,in addition to the petrography evidence and Mg isotope variations,suggest that the formation of these dolomites were due to the shallow-burial dolomitization.The occurrence of the Xiaqiulitagh(Є3ql)and Penglaiba(O1p)dolomites along stylolites,together with their large crystals with opaque cores and clear rims and vertically constant δ26Mg profiles,indicate that their formation may be related to pressure dissolution by mechanical compaction during deep-burial dolomitization.Therefore,the assembling of multiple petrographic,mineralogical and geochemical methods can shed light on the complicated generation processes of regional-scale dolomite within Tarim Basin or elsewhere. 展开更多
关键词 genesis of dolomites isotopes magnesium isotope Tarim Basin Cambrian–Lower Ordovician
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Practice and theoretical and technical progress in exploration and development of Shunbei ultra-deep carbonate oil and gas field,Tarim Basin,NW China 认领 引用 被引量：42
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作者 MA Yongsheng CAI Xunyu +4 位作者 YUN Lu LI Zongjie LI Huili DENG Shang ZHAO Peirong 《Petroleum Exploration and Development》 SCIE 2022年第1期1-20,共20页
In this review on the exploration and development process of the Shunbei ultra-deep carbonate oil and gas field in the Tarim Basin, the progress of exploration and development technologies during the National 13th Fiv... In this review on the exploration and development process of the Shunbei ultra-deep carbonate oil and gas field in the Tarim Basin, the progress of exploration and development technologies during the National 13th Five-Year Plan of China has been summarized systematically, giving important guidance for the exploration and development of ultra-deep marine carbonate reservoirs in China and abroad. Through analyzing the primary geological factors of “hydrocarbon generation-reservoir formation-hydrocarbon accumulation” of ancient and superposed basin comprehensively and dynamically, we point out that because the Lower Cambrian Yuertusi Formation high-quality source rocks have been located in a low-temperature environment for a long time, they were capable of generating hydrocarbon continuously in late stage, providing ideal geological conditions for massive liquid hydrocarbon accumulation in ultra-deep layers. In addition, strike-slip faults developed in tectonically stable areas have strong control on reservoir formation and hydrocarbon accumulation in this region. With these understandings, the exploration focus shifted from the two paleo-uplifts located in the north and the south to the Shuntuoguole lower uplift located in between and achieved major hydrocarbon discoveries. Through continuing improvement of seismic exploration technologies for ultra-deep carbonates in desert, integrated technologies including seismic acquisition in ultra-deep carbonates,seismic imaging of strike-slip faults and the associated cavity-fracture systems, detailed structural interpretation of strike-slip faults, characterization and quantitative description of fault-controlled cavities and fractures, description of fault-controlled traps and target optimization have been established. Geology-engineering integration including well trajectory optimization,high efficiency drilling, completion and reservoir reformation technologies has provided important support for exploration and development of the Shunbei oil and gas field. 展开更多
关键词 ultra-deep carbonates fault-controlled fracture-vug reservoir strike-slip fault Shunbei oil and gas field Ordovician Tarim Basin
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Several issues worthy of attention in current lacustrine shale oil exploration and development 认领 引用 被引量：68
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作者 JIN Zhijun ZHU Rukai +1 位作者 LIANG Xinping SHEN Yunqi 《Petroleum Exploration and Development》 2021年第6期1471-1484,共14页
Based on the current research status of shale oil exploration and development at home and abroad,through field observations,dissection of typical shale oil regions,analysis and testing of organic-rich shale samples,et... Based on the current research status of shale oil exploration and development at home and abroad,through field observations,dissection of typical shale oil regions,analysis and testing of organic-rich shale samples,etc.,we compare the differences in geological and engineering characteristics of shale oil reservoirs in marine and continental basins in China and the United States,put forward several issues worthy of attention in the exploration and development of lacustrine shale oil in typical basins of China,including the concept of tight oil and shale oil,vertical permeability and horizontal permeability,differences between continental and marine shale oil reservoirs,medium-low maturity and medium-high maturity,source-reservoir and source-caprock,geology and engineering,selection criteria of favorable areas and“sweet spots”,basic scientific research and application research.By comparing and analyzing organic-rich shales in the Triassic Yanchang Formation of the Ordos Basin,the Permian Lucaogou Formation in the Jimsar Sag of the Junggar Basin,the Permian Fengcheng Formation in the Mahu Sag,the Cretaceous Qingshankou&Nenjiang Formation in the Songliao Basin and the Paleogene Kongdian&Shahejie Formation in the Bohai Bay Basin,we believe that three key scientific issues must be studied in-depth from shale oil exploration to development in the future:(1)the physical,chemical and biological processes during the deposition of terrestrial fine-grained sediments and the formation mechanism of terrestrial organic-rich shale;(2)the dynamic evolution of diagenesis-hydrocarbon generation-reservoir formation,and the mechanisms of hydrocarbon formation and accumulation;(3)the fracturing mechanisms of terrestrial shale layers in different diagenetic stages and the multi-phase and multi-scale flow mechanism of shale oil in shale layers of different maturities.In addition,we should clarify the main controlling factors of shale oil reservoir characterization,oil-bearing properties,compressibility and fluidity of shale oil with different maturities,establish a lacustrine shale oil enrichment model and the evaluation methodology,to provide effective development methods,and ultimately to establish theoretical foundation and technical support for the large scale economical exploration and development of lacustrine shale oil resources in China. 展开更多
关键词 lacustrine shale oil medium-low maturity medium-high maturity vertical permeability horizontal permeability source-reservoir source-caprock geology and engineering
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Construction and application of an ontology-based domain-specific knowledge graph for petroleum exploration and development 认领 引用 被引量：17
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作者 Xianming Tang Zhiqiang Feng +6 位作者 Yitian Xiao Ming Wang Tianrui Ye Yujie Zhou Jin Meng Baosen Zhang Dongwei Zhang 《Geoscience Frontiers》 SCIE CAS CSCD 2023年第5期373-383,共11页
The massive amount and multi-sourced,multi-structured data in the upstream petroleum industry impose great challenge on data integration and smart application.Knowledge graph,as an emerging technology,can potentially ... The massive amount and multi-sourced,multi-structured data in the upstream petroleum industry impose great challenge on data integration and smart application.Knowledge graph,as an emerging technology,can potentially provide a way to tackle the challenges associated with oil and gas big data.This paper proposes an engineering-based method that can improve upon traditional natural language processing to construct the domain knowledge graph based on a petroleum exploration and development ontology.The exploration and development knowledge graph is constructed by assembling Sinopec’s multi-sourced heterogeneous database,and millions of nodes.The two applications based on the constructed knowledge graph are developed and validated for effectiveness and advantages in providing better knowledge services for the oil and gas industry. 展开更多
关键词 Knowledge Graph Petroleum exploration and development Natural language processing Ontology
Research advances on the mechanisms of reservoir formation and hydrocarbon accumulation and the oil and gas development methods of deep and ultra-deep marine carbonates 认领 引用 被引量：15
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作者 MA Yongsheng CAI Xunyu +9 位作者 LI Maowen LI Huili ZHU Dongya QIU Nansheng PANG Xiongqi ZENG Daqian KANG Zhijiang MA Anlai SHI Kaibo ZHANG Juntao 《Petroleum Exploration and Development》 SCIE 2024年第4期795-812,共18页
Based on the new data of drilling, seismic, logging, test and experiments, the key scientific problems in reservoir formation, hydrocarbon accumulation and efficient oil and gas development methods of deep and ultra-d... Based on the new data of drilling, seismic, logging, test and experiments, the key scientific problems in reservoir formation, hydrocarbon accumulation and efficient oil and gas development methods of deep and ultra-deep marine carbonate strata in the central and western superimposed basin in China have been continuously studied.(1) The fault-controlled carbonate reservoir and the ancient dolomite reservoir are two important types of reservoirs in the deep and ultra-deep marine carbonates. According to the formation origin, the large-scale fault-controlled reservoir can be further divided into three types:fracture-cavity reservoir formed by tectonic rupture, fault and fluid-controlled reservoir, and shoal and mound reservoir modified by fault and fluid. The Sinian microbial dolomites are developed in the aragonite-dolomite sea. The predominant mound-shoal facies, early dolomitization and dissolution, acidic fluid environment, anhydrite capping and overpressure are the key factors for the formation and preservation of high-quality dolomite reservoirs.(2) The organic-rich shale of the marine carbonate strata in the superimposed basins of central and western China are mainly developed in the sedimentary environments of deep-water shelf of passive continental margin and carbonate ramp. The tectonic-thermal system is the important factor controlling the hydrocarbon phase in deep and ultra-deep reservoirs, and the reformed dynamic field controls oil and gas accumulation and distribution in deep and ultra-deep marine carbonates.(3) During the development of high-sulfur gas fields such as Puguang, sulfur precipitation blocks the wellbore. The application of sulfur solvent combined with coiled tubing has a significant effect on removing sulfur blockage. The integrated technology of dual-medium modeling and numerical simulation based on sedimentary simulation can accurately characterize the spatial distribution and changes of the water invasion front.Afterward, water control strategies for the entire life cycle of gas wells are proposed, including flow rate management, water drainage and plugging.(4) In the development of ultra-deep fault-controlled fractured-cavity reservoirs, well production declines rapidly due to the permeability reduction, which is a consequence of reservoir stress-sensitivity. The rapid phase change in condensate gas reservoir and pressure decline significantly affect the recovery of condensate oil. Innovative development methods such as gravity drive through water and natural gas injection, and natural gas drive through top injection and bottom production for ultra-deep fault-controlled condensate gas reservoirs are proposed. By adopting the hierarchical geological modeling and the fluid-solid-thermal coupled numerical simulation, the accuracy of producing performance prediction in oil and gas reservoirs has been effectively improved. 展开更多
关键词 deep and ultra-deep marine carbonate mechanisms of hydrocarbon accumulation reef-beach facies high-sulfur sour gas reservoirs ultra-deep fault-controlled fractured-cavity reservoir wellbore sulfur deposition fluid-solid-thermal numerical simulation
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