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Main factors controlling unconventional gas enrichment and high production in the first member of Permian Maokou Formation,southeastern Sichuan Basin,SW China 认领 引用 被引量：2
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作者 HE Guisong SUN Bin +4 位作者 GAO Yuqiao ZHANG Peixian ZHANG Zhiping CAI Xiao XIA Wei 《Petroleum Exploration and Development》 SCIE 2025年第2期408-421,共14页
Based on the data of drilling,logging,experiment and gas testing in the Nanchuan area,southeastern Sichuan Basin,the hydrocarbon generation potential,gas genesis,occurrence state,migration,preservation conditions,pore... Based on the data of drilling,logging,experiment and gas testing in the Nanchuan area,southeastern Sichuan Basin,the hydrocarbon generation potential,gas genesis,occurrence state,migration,preservation conditions,pore and fracture features and accumulation evolution of the first member of Permian Maokou Formation(Mao 1 Member)are systematically studied,and the main controlling factors of unconventional gas enrichment and high production in marlstone assemblage of Mao 1 Member are discussed.(1)The enrichment and high yield of unconventional natural gas in the Mao 1 Member are controlled by three factors:carbon-rich fabric controlling hydrocarbon generation potential,good preservation controlling enrichment,and natural fracture controlling production.(2)The carbonate rocks of Mao 1 Member with carbon rich fabric have significant gas potential,exhibiting characteristics of self-generation and self-storage,which lays the material foundation for natural gas accumulation.(3)The occurrence state of natural gas is mainly free gas,which is prone to lateral migration,and good storage conditions are the key to natural gas enrichment.Positive structure is more conducive to natural gas accumulation,and a good compartment is created jointly by the self-sealing property of the Mao 1 Member and its top and bottom sealing property in monoclinal area,which is favorable for gas accumulation by retention.(4)Natural fractures are the main reservoir space and flow channel,and the more developed natural fractures are,the more conducive to the formation of high-quality porous-fractured reservoirs and the accumulation of natural gas,which is the core of controlling production.(5)The accumulation model of unconventional natural gas is proposed as“self-generation and self-storage,preservation controlling richness,and fractures controlling production”.(6)Identifying fracture development areas with good preservation conditions is the key to successful exploration,and implementing horizontal well staged acidizing and fracturing is an important means to increase production and efficiency.The study results are of referential significance for further understanding the natural gas enrichment in the Mao 1 Member and guiding the efficient exploration and development of new types of unconventional natural gas. 展开更多
关键词 Sichuan Basin Permian Maokou Formation unconventional natural gas main controlling factors of enrichment and high production accumulation model carbonate rock southeastern Sichuan Basin
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A comparative study of the main factors controlling geohazards induced by 10 strong earthquakes in Western China since the Wenchuan earthquake in 2008 认领 引用 被引量：6
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作者 Chao Peng Zhi-qiang Yin +2 位作者 Xu-jiao Zhang Hai Shao Ming-fei Pang 《China Geology》 CAS CSCD 2023年第1期70-84,共15页
Determining the main controlling factors of earthquake-triggered geohazards is a prerequisite for studying earthquake geohazards and post-disaster emergency response.By studying these factors,the geomorphic and geolog... Determining the main controlling factors of earthquake-triggered geohazards is a prerequisite for studying earthquake geohazards and post-disaster emergency response.By studying these factors,the geomorphic and geological factors controlling the nature,condition,and distribution of earthquake-induced geohazards can be analyzed.Such insights facilitate earthquake disaster prediction and emergency response planning.The authors combined field investigations and spatial data analysis to examine geohazards induced by seismic events,examining ten earthquakes including the Wenchuan,Yushu,Lushan events,to elucidate the main control factors of seismic geohazard.The authors observed that seismic geohazard occurrence is usually affected by many factors,among which active nature of the seismogenic fault,seismic peak ground acceleration(PGA),topographic slope and geomorphic height differences,and distance from the fault zone and river system are the most important.Compared with strike-slip earthquakes,thrust earthquakes induce more high-altitude and high-speed remote landslides,which can cause great harm.Slopes of 0°–40°are prone to secondary seismic geohazards,which are mainly concentrated 0–6 km from the river system.Secondary geohazards are not only related to seismogenic fault but also influenced by the associated faults in the earthquake area.The maximum seismic PGA and secondary seismic geohazard number are positively correlated,and the horizontal and vertical ground motions play leading and promoting roles in secondary geohazard formation,respectively.Through the research,the spatial distribution of seismic geohazards is predicted,providing a basis for the formulation of emergency response plans following disasters. 展开更多
关键词 Wenchuan earthquake Geohazards Main control factors Comparative study Geological disater survey engineering Western China
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Differential Hydrocarbon Enrichment and its Main Controlling Factors in Depressions of the Bohai Bay Basin Differential Hydrocarbon Enrichment and its Main Controlling Factors in Depressions of the Bohai Bay Basin 认领 引用 被引量：17
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作者 JIANG Youlu LIU Hua +4 位作者 SONG Guoqi WANG Yongshi LIU Jingdong ZHAO Kai LYU Xueying 《Acta Geologica Sinica(English Edition)》 SCIE CAS CSCD 2017年第5期1855-1872,共18页
Significant differential hydrocarbon enrichment occurs in depressions in a petroliferous basin.There are multiple depressions in the Bohai Bay Basin, and each depression as a relatively independent unit of hydrocarbon... Significant differential hydrocarbon enrichment occurs in depressions in a petroliferous basin.There are multiple depressions in the Bohai Bay Basin, and each depression as a relatively independent unit of hydrocarbon generation, migration and accumulation, contains significantly different hydrocarbon generation conditions and enrichment degree. On the basis of previous documents and a large number of statistical data, this work comparatively analyzed the differential hydrocarbon enrichment and its major controlling factors in depressions of the Bohai Bay Basin. The results show that depressions in the Bohai Bay Basin have various hydrocarbon enrichment degrees, and can be categorized into four types, namely enormously oil-rich, oil-rich, oily and oil-poor depressions. In general, the enormously oil-rich and oil-rich depressions are distributed in the eastern part of the basin along the Tan-Lu and Lan-Liao faults, whereas depressions in the western part of the basin are poor in hydrocarbons. Moreover, the vertical distribution of hydrocarbons is also highly heterogeneous, with Pre-Paleogene strata rich in hydrocarbons in the northern and western depressions, Paleogene strata rich in hydrocarbons in the entire basin, and Neogene strata rich in hydrocarbons in the off-shore areas of the Bohai Bay Basin. From early depressions in onshore areas to the late depressions in offshore areas of the Bohai Bay Basin, the source rocks and source-reservoir-cap rock assemblages gradually become younger and shallower, and the hydrocarbon resource abundance gradually increases. Hydrocarbon supplying condition is the key factor constraining the hydrocarbon enrichment for different depressions,while the main source-reservoir-cap rock assemblage, sufficient hydrocarbons and the transportation capacity of faults control the vertical distribution of hydrocarbons. The main factors controlling hydrocarbon enrichment are different for different layers. The hydrocarbon supplying condition of source rocks is the key controlling factor, whereas the source-reservoir configuration, the main sourcereservoir-cap rock assemblages, and the fault transportation are the main factors of hydrocarbon enrichment in the Paleogene, Paleogene and Neogene, respectively. 展开更多
关键词 differential hydrocarbon enrichment hydrocarbon distribution hydrocarbon-rich depression fault transportation main controlling factors Bohai Bay Basin
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Analyses of the characteristics and main controlling factors of shale pores in the Niutitang Formation in the Guizhou region 认领 引用 被引量：3
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作者 Daquan Zhang Yi Chen +6 位作者 Shengyuan Ji Qingbo He Yisong Wang Ruiqin Lin Fulun Shi Xia Feng Wei Du 《Natural Gas Industry B》 2024年第4期394-404,共11页
The shale of the Lower Cambrian Niutitang Formation in the Guizhou region has undergone complex diagenesis and has developed different types of pore textures,which affect the occurrence status of shale.In the present ... The shale of the Lower Cambrian Niutitang Formation in the Guizhou region has undergone complex diagenesis and has developed different types of pore textures,which affect the occurrence status of shale.In the present study,we applied scanning electron microscopy(SEM)and an isotherm analysis of low-temperature nitrogen gas adsorption to shale core samples drawn from the Niutitang Formation in the Guizhou region to quantify the shale pore development characteristics.In addition,we conducted a shale geochemical analysis in light of the main controlling factors for pore development.The results indicate that the shale pores and fractures of the Niutitang Formation can be divided into three types:organic pores,inorganic pores,and micro fractures.The organic pores are mainly distributed in the organic matter between inorganic mineral particles,with small pore diameters,which are characterized by inkpot,elliptic,and beaded shapes.The inorganic pores are mainly composed of narrow slit intragranular pores and intergranular pores.The micro fractures develop parallel plates with four-side openings and splint plates.The pores of the shale are mainly mesopores(53%),followed by micropores and macropores,with pore diameter distributions ranging mainly from 1 to 50 nm.The specific surface area is mainly provided by nanoscale pores with average diameters of less than 4 nm.Therefore,the smaller pore makes a greater contribution to the specific surface area,while the specific surface area increases with an increase in the total pore volume.The study further indicates that organic carbon content is the most important internal factor for shale pore development,especially in terms of the control of volume and the specific surface area of micropores.Moreover,quartz content has a certain effect on shale pores;the pore volume and specific surface area increase with increasing quartz content,but the control effect is not obvious.The effect of clay minerals on shale pores is negligible.The type of organic matter is also an important factor in controlling the developmental difference of shale pores,and a high degree of thermal evolution is not conducive to organic pore development.It was therefore concluded that intergranular pores and microfractures,mainly mesopores,are the main reservoir space and migration channels of Niutitang shale in the study area.The organic carbon content,mineral components,organic matter type,and degree of thermal evolution jointly control the development of shale pores,among which the organic carbon content is the most important influencing factor. 展开更多
关键词 Guizhou region Niutitang formation Shale pore Development characteristics Main controlling factor
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Distribution rules,main controlling factors and exploration directions of giant gas fields in the Sichuan Basin 认领 引用 被引量：1
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作者 Wei Guoqi Yang Wei +6 位作者 Liu Mancang Xie Wuren Jin Hui Wu Saijun Su Nan Shen Juehong Hao Cuiguo 《Natural Gas Industry B》 2020年第1期1-12,共12页
Over the past decade,great progresses have been made in natural gas exploration in the Sichuan Basin,where several large gas fields(such as Anyue)have been discovered.With the increase of data and the deepening of exp... Over the past decade,great progresses have been made in natural gas exploration in the Sichuan Basin,where several large gas fields(such as Anyue)have been discovered.With the increase of data and the deepening of exploration,new knowledges have been gained in geological theory,thus it is necessary to further analyze the distribution characteristics and main controlling factors of large gas fields,thus to put forward new exploration directions for large gas fields.Therefore,based on the statistics on the geological parameters of 20 large gas fields discovered in this basin,the distribution rules,formation conditions and main controlling factors of large gas fields were analyzed,and the follow-up exploration directions were proposed.The following results were achieved.(1)Large gas fields are developed in different tectonic regions in the Sichuan Basin,mostly in the low and gentle tectonic belts in the central Sichuan Basin.Large gas fields are developed in seven series of strata in longitudinal stratigraphic sequences,which are dominated by the reef-shoal large gas fields formed in the Upper Permian ChangxingeLower Triassic Feixianguan Fms.(2)There are four sets of source rocks contributing to the formation of large gas fields,mostly from the assemblage of Xujiahe Fm source rocks.(3)Reservoirs in the large gas fields are dominated by porous carbonates and tight sandstones;large gas fields are mostly structuralelithological ones and normal pressure ones.(4)The development of marine large gas fields are mainly controlled by intracratonic rifts and paleo-uplifts.The controlling effect of intracratonic rifts is mainly from three aspects,namely the hydrocarbon generation center of source rocks,high-energy facies belts on the platform edges,and lateral sealing for hydrocarbon accumulation.The controlling effect of the paleo-uplifts mainly acts from another three aspects:intra-platform high-energy facies belts,karstic dolomite reservoirs and long-term hydrocarbon accumulation.The structures of foreland basins controlled the development of the continental large gas fields from four aspects:tectonic setting,source and reservoir assemblage,trap type and fracture distribution.In conclusion,a total of 5 domains with 14 favorable zones are the follow-up exploration directions of large gas fields in the Sichuan Basin. 展开更多
关键词 Sichuan Basin Large gas field Distribution rule Geological feature Main controlling factor Intracratonic rift Paleo-uplift Foreland basin structure Exploration direction
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Study onGeothermal Negative Anomaly andlts Main Controlling Factors in Sijiazhuang Minefield 认领 引用 被引量：1
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作者 YANG Changyong TIAN Qingling +3 位作者 HAO Chunsheng JI Changjiang YU Zhenfeng CHANG Huizhen 《山西焦煤科技》 CAS 2017年第8期8-16,共9页
The research on geotliermal fiel（i is one of the hot research content in the development of oil or gasand mining activities. Based on the stratum temperature measurement data of 332 borehole in Sijiazhuang coalfield,... The research on geotliermal fiel（i is one of the hot research content in the development of oil or gasand mining activities. Based on the stratum temperature measurement data of 332 borehole in Sijiazhuang coalfield,the formation litliology and composed characteristics ’ geological and hydrogeological conditions , we did a research onthe geotliermal negative anomaly and its main controlling factors. By the research, we come to a conclusion ： The mod-ern geothermal field of Sijiazhuang coalfield is mainly effected by 3 factors ： formation thermal conductivity , under -ground water and open structure. The high content of sandstone in coalfield layer causes strong thermal conductivity .fast heat conduction , difficulty in heat aggregation,which is themain controlling factors of lowvaluein geothermy of Sijiazhuang coalfield , the strong regional groundwater runoff state is the macro control factors of its lower in moderngeothermal field of this area. The mine groundwater flowstate play a “cooling” rool and the nel loss function to the surrounding rock temperature , which is an important control factor of geotliermal negative a-nomaly and geothermal field varies in thestudy area , theopen extensional fault and collapse colua good channel for geothermal loss,but also provide favorable conditions for from aquifer groundwater circulation and runoff,which is the key control factor to the geothermal field varies of this coal field. 展开更多
关键词 Sijiazhuang Minefield Geothermal field Geothermal Negative anomaly Geothermal field dif feren-tiation Main control factors
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Fractal Characteristics and Main Controlling Factors of High-Quality Tight Sandstone Reservoirs in the Southeastern Ordos Basin 认领 引用 被引量：4
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作者 Ruilin Hao Wenhui Huang +1 位作者 Jiu Bo Li Yuan 《Journal of Earth Science》 SCIE CAS CSCD 2024年第2期631-641,共11页
Due to the complex conditions and strong heterogeneity of tight sandstone reservoirs,the reservoirs should be classified and the controlling factors of physical properties should be studied.Cast thin section observati... Due to the complex conditions and strong heterogeneity of tight sandstone reservoirs,the reservoirs should be classified and the controlling factors of physical properties should be studied.Cast thin section observations,cathodoluminescence,scanning electron microscopy(SEM),X-ray diffraction(XRD),and high-pressure mercury injection(HPMI)were used to classify and optimize the reservoir.The Brooks-Corey model and stepwise regression were used to study the fractal dimension and main controlling factors of the physical properties of the high-quality reservoir.The results show that the reservoirs in the study area can be divided into four types,and the high-quality reservoir has the best physical properties and pore-throat characteristics.In the high-quality reservoir,the homogeneity of transitional pores was the best,followed by that of micropores,and the worst was mesopores.The porosity was controlled by depth and kaolinite.The model with standardized coefficients is y=12.454−0.778×(Depth)+0.395×(Kaolinite).The permeability was controlled by depth,illite/montmorillonite,and siliceous cement,and the model with standardized coefficients is y=1.689−0.683×(Depth)−0.395×(Illite/Montmorillonite)−0.337×(Siliceous Cement).The pore-throat evolutionary model shows that the early-middle diagenetic period was when the reservoir physical properties were at their best,and the kaolinite intercrystalline pores and residual intergranular pores were the most important. 展开更多
关键词 fractal dimension main controlling factors stepwise regression high-quality tight sandstone reservoir Ordos Basin petroleum geolgoy
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Main Controlling Factors and Accumulation Model of Chang 9 Reservoir in Northwest Ordos Basin, China 认领 引用
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作者 Zhang Weigang Chen Gang 《China Oil & Gas》 CAS 2019年第6期39-44,共6页
In northwestern Ordos Basin, the Triassic reservoir Chang 9 has favorable reservoir forming conditions, extensive reservoir development, and huge potential for oil exploration and exploitation. Studying the main contr... In northwestern Ordos Basin, the Triassic reservoir Chang 9 has favorable reservoir forming conditions, extensive reservoir development, and huge potential for oil exploration and exploitation. Studying the main controlling factors and accumulation model of Chang 9 reservoir in this area can provide a basis for the production targets, and assist in formulating reasonable development technology policy. In this paper, to explore and summarize the hydrocarbon accumulation model, the Chang 9 reservoir were analyzed from the aspects of oil source, fracture, oil migration, structure, lithology and reservoir physical properties for the main controlling factors in this area. Organic geochemical and geological comprehensive analysis that the oil-source of the Chang 9 reservoir in the northwest of Ordos Basin is derived from Chang 7 hydrocarbon source rocks. The fractures provide a sound channel for the "vertical multi-point filling" of the oil source from Chang 7 to Chang 9. The crude oil migrates vertically from Chang 7 to Chang 9, then expands horizontally to form a reservoir. Structures play an important role in controlling the distribution of reservoirs, the control by sand in small layer and physical property is also obvious. This paper creatively establishes the reservoir accumulation model of Chang 9 in northwest of Ordos Basin, which is characterized by Vertical multi-point filling, horizontal expansion becomes oil pool. It reveals the genetic mechanism of the development of Chang 9 multi-reservoir in the study area, which provides guidance for exploration and evaluation deployment. 展开更多
关键词 Ordos Basin Chang 9 reservoir petroleum accumulation main control factors hydrocarbon pooling patterns
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Enrichment of tight oil and its controlling factors in central and western China 认领 引用 被引量：10
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作者 SONG Yan LUO Qun +2 位作者 JIANG Zhenxue YANG Wei LIU Dongdong 《Petroleum Exploration and Development》 2021年第2期492-506,共15页
Taking the tight oil of the Zhongnan sag in the Ordos Basin,Jimusar sag in the Junggar Basin and Qingxi sag in the Jiuquan Basin as study objects,based on field survey,dissection of tight oil reservoirs,sample test,mo... Taking the tight oil of the Zhongnan sag in the Ordos Basin,Jimusar sag in the Junggar Basin and Qingxi sag in the Jiuquan Basin as study objects,based on field survey,dissection of tight oil reservoirs,sample test,modeling experiment and comprehensive analysis,this study reveals that the tight oil accumulates at start-up pressure,advances under differential pressure,diffuses at alternating fast and low speeds,charges in stepped large area and migrates rapidly through fractures,and enriches in dominant fractures and pores.The root cause of ladder-like charge is the multiple scales of pores.The widespread source rock with high hydrocarbon generation intensity is the material basis for tight oil enrichment;the dominant source reservoir assemblage is the basic unit for tight oil enrichment;fractures and beddings are conducive to local rapid migration of tight oil;fractures and pores work together to control the enrichment of tight oil.Two typical accumulation models of tight oil are established,namely"source reservoir in coexistence,four optimal factors controlling enrichment around central area,and large-scale continuous distribution"for a large freshwater lake clastic rock basin and"source reservoir integration,four optimal factors controlling enrichment,central area distribution,small in size but high in enrichment degree"for a small saline lake diamictite depression. 展开更多
关键词 tight oil enrichment mechanism main control factor enrichment model central and western China
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Enrichment model and major controlling factors of below-source tight oil in Lower Cretaceous Fuyu reservoirs in northern Songliao Basin,NE China 认领 引用 被引量：4
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作者 WANG Xiaojun BAI Xuefeng +9 位作者 LI Junhui JIN Zhijun WANG Guiwen CHEN Fangju ZHENG Qiang HOU Yanping YANG Qingjie LI Jie LI Junwen CAI Yu 《Petroleum Exploration and Development》 SCIE 2024年第2期279-291,共13页
Based on the geochemical,seismic,logging and drilling data,the Fuyu reservoirs of the Lower Cretaceous Quantou Formation in northern Songliao Basin are systematically studied in terms of the geological characteristics... Based on the geochemical,seismic,logging and drilling data,the Fuyu reservoirs of the Lower Cretaceous Quantou Formation in northern Songliao Basin are systematically studied in terms of the geological characteristics,the tight oil enrichment model and its major controlling factors.First,the Quantou Formation is overlaid by high-quality source rocks of the Upper Cretaceous Qingshankou Formation,with the development of nose structure around sag and the broad and continuous distribution of sand bodies.The reservoirs are tight on the whole.Second,the configuration of multiple elements,such as high-quality source rocks,reservoir rocks,fault,overpressure and structure,controls the tight oil enrichment in the Fuyu reservoirs.The source-reservoir combination controls the tight oil distribution pattern.The pressure difference between source and reservoir drives the charging of tight oil.The fault-sandbody transport system determines the migration and accumulation of oil and gas.The positive structure is the favorable place for tight oil enrichment,and the fault-horst zone is the key part of syncline area for tight oil exploration.Third,based on the source-reservoir relationship,transport mode,accumulation dynamics and other elements,three tight oil enrichment models are recognized in the Fuyu reservoirs:(1)vertical or lateral migration of hydrocarbon from source rocks to adjacent reservoir rocks,that is,driven by overpressure,hydrocarbon generated is migrated vertically or laterally to and accumulates in the adjacent reservoir rocks;(2)transport of hydrocarbon through faults between separated source and reservoirs,that is,driven by overpressure,hydrocarbon migrates downward through faults to the sandbodies that are separated from the source rocks;and(3)migration of hydrocarbon through faults and sandbodies between separated source and reservoirs,that is,driven by overpressure,hydrocarbon migrates downwards through faults to the reservoir rocks that are separated from the source rocks,and then migrates laterally through sandbodies.Fourth,the differences in oil source conditions,charging drive,fault distribution,sandbody and reservoir physical properties cause the differential enrichment of tight oil in the Fuyu reservoirs.Comprehensive analysis suggests that the Fuyu reservoir in the Qijia-Gulong Sag has good conditions for tight oil enrichment and has been less explored,and it is an important new zone for tight oil exploration in the future. 展开更多
关键词 northern Songliao Basin Cretaceous Quantou Formation Qingshankou Formation upper generation and lower storage Fuyu reservoir tight oil main control factor enrichment model
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Controlling factors of marine shale gas differential enrichment in southern China 认领 引用 被引量：20
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作者 JIANG Zhenxue SONG Yan +8 位作者 TANG Xianglu LI Zhuo WANG Xingmeng WANG Guozhen XUE Zixin LI Xin ZHANG Kun CHANG Jiaqi QIU Hengyuan 《Petroleum Exploration and Development》 SCIE 2020年第3期661-673,共13页
Based on the exploration and development practice of marine shale gas in Fuling, Weiyuan, Changning, Luzhou and Southeast Chongqing in southern China, combined with experiments and analysis, six factors controlling di... Based on the exploration and development practice of marine shale gas in Fuling, Weiyuan, Changning, Luzhou and Southeast Chongqing in southern China, combined with experiments and analysis, six factors controlling differential enrichment of marine shale gas are summarized as follows:(1) The more appropriate thermal evolution and the higher the abundance of organic matter, the higher the adsorption and total gas content of shale will be.(2) Kerogen pyrolysis and liquid hydrocarbon cracking provide most of the marine shale gas.(3) The specific surface area and pore volume of organic matter rich shale increased first and then decreased with the increase of thermal evolution degree of organic shale. At Ro between 2.23% and 3.33%, the shale reservoirs are mainly oil-wet, which is conducive to the enrichment of shale gas.(4) The thicker the roof and floor, the higher the shale gas content. The longer the last tectonic uplift time and the greater the uplift amplitude, the greater the loss of shale gas will be.(5) The buried depth and dip angle of the stratum have different controlling and coupling effects on shale gas in different tectonic positions, resulting in two differential enrichment models of shale gas.(6) The effective and comprehensive matching of source, reservoir and preservation conditions determines the quality of shale gas accumulation. Good match of effective gas generating amount and time, moderate pore evolution and good preservation conditions in space and time is essential for the enrichment of shale gas. 展开更多
关键词 southern China shale gas differential enrichment main controlling factors factors matching accumulation effect
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Differences and controlling factors of composite hydrocarbon accumulations in the Tazhong uplift, Tarim Basin, NW China 认领 引用 被引量：11
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作者 JIANG Tongwen HAN Jianfa +5 位作者 WU Guanghui YU Hongfeng SU Zhou XIONG Chang CHEN Jun ZHANG Huifang 《Petroleum Exploration and Development》 SCIE 2020年第2期229-241,共13页
Based on three-dimensional seismic interpretation, structural and sedimentary feature analysis, and examination of fluid properties and production dynamics, the regularity and main controlling factors of hydrocarbon a... Based on three-dimensional seismic interpretation, structural and sedimentary feature analysis, and examination of fluid properties and production dynamics, the regularity and main controlling factors of hydrocarbon accumulation in the Tazhong uplift, Tarim Basin are investigated. The results show that the oil and gas in the Tazhong uplift has the characteristics of complex accumulation mainly controlled by faults, and more than 80% of the oil and gas reserves are enriched along fault zones. There are large thrust and strike-slip faults in the Tazhong uplift, and the coupling relationship between the formation and evolution of the faults and accumulation determine the difference in complex oil and gas accumulations. The active scale and stage of faults determine the fullness of the traps and the balance of the phase, that is, the blocking of the transport system, the insufficient filling of oil and gas, and the unsteady state of fluid accumulation are dependent on the faults. The multi-period tectonic sedimentary evolution controls the differences of trap conditions in the fault zones, and the multi-phase hydrocarbon migration and accumulation causes the differences of fluid distribution in the fault zones. The theory of differential oil and gas accumulation controlled by fault is the key to the overall evaluation, three-dimensional development and discovery of new reserves in the Tazhong uplift. 展开更多
关键词 Tarim Basin Tazhong uplift fault zone complex oil and gas accumulation oil and gas distribution difference main controlling factor
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Major controlling factors and hydrocarbon accumulation models of large-scale lithologic reservoirs in shallow strata around the Bozhong sag,Bohai Bay Basin,China 认领 引用 被引量：5
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作者 ZHOU Xinhuai WANG Deying +2 位作者 YU Haibo YANG Haifeng LI Long 《Petroleum Exploration and Development》 SCIE 2022年第4期758-769,共12页
Based on the practice of oil and gas exploration and the analysis of shallow lithologic reservoirs,combined with the allocation relationship and enrichment law of oil and gas accumulation factors,main controlling fact... Based on the practice of oil and gas exploration and the analysis of shallow lithologic reservoirs,combined with the allocation relationship and enrichment law of oil and gas accumulation factors,main controlling factors and models of hydrocarbon accumulation of large lithologic reservoirs in shallow strata around the Bozhong sag are summarized,and favorable exploration areas are proposed.The coupling of the four factors of“ridge-fault-sand-zone”is crucial for the hydrocarbon enrichment in the shallow lithologic reservoirs.The convergence intensity of deep convergence ridges is the basis for shallow oil and gas enrichment,the activity intensity of large fault cutting ridges and the thickness of cap rocks control the vertical migration ability of oil and gas,the coupling degree of large sand bodies and fault cutting ridges control large-scale oil and gas filling,the fault sealing ability of structural stress concentration zones affects the enrichment degree of lithologic oil and gas reservoirs.Three enrichment models including uplift convergence type,steep slope sand convergence type and depression uplift convergence type are established through the case study of lithologic reservoirs in shallow strata around the Bozhong sag. 展开更多
关键词 shallow lithologic reservoir main controlling factors convergence ridge accumulation model Bozhong sag Bohai Bay Basin
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Elemental characteristics of lacustrine oil shale and its controlling factors of palaeo-sedimentary environment on oil yield: a case from Chang 7 oil layer of Triassic Yanchang Formation in southern Ordos Basin 认领 引用 被引量：4
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作者 Delu Li Rongxi Li +1 位作者 Zengwu Zhu Feng Xu 《Acta Geochimica》 EI CAS CSCD 2018年第2期228-243,共16页
As an important unconventional resource, oil shale has received widespread attention. The oil shale of the Chang 7 oil layer from Triassic Yanchang Formation in Ordos Basin represents the typical lacustrine oil shale ... As an important unconventional resource, oil shale has received widespread attention. The oil shale of the Chang 7 oil layer from Triassic Yanchang Formation in Ordos Basin represents the typical lacustrine oil shale in China. Based on analyzing trace elements and oil yield from boreholes samples, characteristics and paleo-sedi- mentary environments of oil shale and relationship between paleo-sedimentary environment and oil yield were studied. With favorable quality, oil yield of oil shale varies from 1.4% to 9.1%. Geochemical data indicate that the paleo-redox condition of oil shale＇s reducing condition from analyses of V/Cr, V/（V ＋ Ni）, U/Th, δU, and authi genic uranium. Equivalent Boron, Sp, and Sr/Ba illustrate that paleosalinity of oil shale is dominated by fresh water. The paleoclimate of oil shale is warm and humid by calculating the chemical index of alteration and Sr/Cu. Fe/Ti and （Fe ＋ Mn）/Ti all explain that there were hot water activities during the sedimentary period of oil shale. In terms of Zr/Rb, paleohydrodynamics of oil shale is weak. By means of Co abundance and U/Th, paleo-water-depth of oil shale is from 17.30 to 157.26 m, reflecting sedimentary environment which is mainly in semi deep-deep lake facies. Correlation analyses between oil yield and six paleoenvironmental factors show that the oil yield of oil shale is mainly controlled by paleo-redox conditions, paleoclimate, hot water activities, and depth of water.Paleosalinity and paleohydrodynamics have an inconspicuous influence on oil yield. 展开更多
关键词 Elemental geochemistry Palaeosedimentary Main controlling factors Lacustrine oil shale Triassic Ordos Basin
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Natural Gas Types,Distribution Controlling Factors,and Future Exploration in the Western Qaidam Basin 认领 引用 被引量：5
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作者 GUO Zeqing SUN Ping +5 位作者 LI Jian ZHANG Lin LIU Weihong TIAN Jixian ZHANG Shaosheng ZENG Xu 《Acta Geologica Sinica(English Edition)》 SCIE CAS CSCD 2014年第4期1214-1226,共13页
The Paleogene and Neogene oil and gas in the western Qaidam basin have a regular distribution in three concentric zones from the edge to the center of the basin. Natural gas mainly occurs in the inner zone, and the ga... The Paleogene and Neogene oil and gas in the western Qaidam basin have a regular distribution in three concentric zones from the edge to the center of the basin. Natural gas mainly occurs in the inner zone, and the gas-oil ratio of the northern area of the basin is significantly higher than that of the southern area. Large amounts of carbon isotope data of natural gas, plotted in X- shaped and comprehensive identification diagrams for the southern area and northern area, respectively, were used to identify the types of natural gas. The large-scale distribution of natural gas is highly consistent with the Ro values of major source rocks, but is poorly correlated with the type of organic matter. This indicates that the main controlling factor of natural gas distribution is organic matter maturity, and the kerogen types act as the basis for the formation of different types of natural gas. Paleouplifts and squeezed anticlines near hydrocarbon generation depression centers, which are major natural gas-rich regions, control the migration directions of natural gas, while hydrocarbon migration pathways and fault systems connecting gas sources are the most important factors for natural gas reservoir formation in the inner basin. Therefore, favorable zones for natural gas distribution can be predicted on the basis of the distribution of thermal evolution and the gas generation intensity of major source rocks as well as the structural map. The Shizigou-Youshashan- Yingdong-Dawusi, Youquanzi -Kaitemilike - Youdunzi, and Xiaoliangshan - Nanyishan - Dafengshan structural belts are favorable zones for natural gas accumulation. This study has important theoretical and practical significance for future natural gas exploration. 展开更多
关键词 western Qaidam basin natural gas types distributional characteristics main controlling factors maturity favorable zones
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海拉尔盆地贝尔凹陷南屯组二段油气成藏主控因素及有利成藏区预测 认领 引用 被引量：2
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作者 王滨涛 赵小青 +2 位作者 董磊 贾善坡 王宏强 《大庆石油地质与开发》 CAS 北大核心 2026年第2期35-42,共8页
目前对海拉尔盆地贝尔凹陷南屯组二段油气成藏主控因素的研究大多集中在定性分析上,缺乏对有利成藏区带的精准定量预测,制约了其增储上产进程。基于油气藏分布临界条件分析,采用成藏主控因素耦合定量评价方法,对贝尔凹陷南屯组二段油气... 目前对海拉尔盆地贝尔凹陷南屯组二段油气成藏主控因素的研究大多集中在定性分析上,缺乏对有利成藏区带的精准定量预测,制约了其增储上产进程。基于油气藏分布临界条件分析,采用成藏主控因素耦合定量评价方法,对贝尔凹陷南屯组二段油气藏开展了油气分布规律研究。结果表明:贝尔凹陷南屯组二段控制油气成藏主控因素为烃源岩、盖层、孔隙度、砂岩厚度、断裂,其中南屯组二段排烃中心贝尔凹陷3 km范围内分布了89.6%以上的油气藏;南屯组二段储层孔隙度、砂岩厚度具有规律性展布特征,均呈现南部发育较好、东部发育较差的特点;油气盖层厚度410~460 m条件下聚集了大量油藏,随着盖层厚度增大,油藏个数先增大后减小,断裂密度较大区域成藏概率相对较高;将主控要素进行耦合,预测出南屯组二段发育2个最有利成藏区带,1个有利成藏区带,1个较有利成藏区带,1个成藏区带。实例验证表明,有利成藏区预测结果可靠,研究成果可为贝尔凹陷南二段油气藏勘探提供指导。 展开更多
关键词 有利区预测 主控因素 成藏概率 临界条件 南屯组二段 贝尔凹陷 海拉尔盆地
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中国页岩气典型区块开发规律与分析 认领 引用 被引量：1
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作者 王纪伟 康玉柱 +3 位作者 魏海鹏 李东晖 宋丽阳 高安荣 《断块油气田》 CAS CSCD 北大核心 2026年第2期177-183,共7页
页岩气作为清洁能源,已成为全球“双碳”目标下最现实的过渡资源,但中国针对页岩气的勘探开发工作尚处于早期,储量动用规律、开发生产规律、产能主控因素等不明确。文中以中国石化6个已开发区块为例,基于各区块实际开发过程中取得的地... 页岩气作为清洁能源,已成为全球“双碳”目标下最现实的过渡资源,但中国针对页岩气的勘探开发工作尚处于早期,储量动用规律、开发生产规律、产能主控因素等不明确。文中以中国石化6个已开发区块为例,基于各区块实际开发过程中取得的地质、工程、采气等资料,系统对比分析其储量动用模式、区块开发模式及开发指标等。研究结果表明:1)页岩气储量动用模式可分为快速高效动用、边评价边动用2类模式;气井初期递减快、后期低产递减趋缓,总体符合双曲+指数递减模型;2)6个典型区块开发模式可以分为快速建产、稳步建产2种模式,稳产期探明储量采气速度分别为1.50%,0.65%;3)明确了气藏储层压力、试气段长度、液量是影响页岩气井产能的主控因素,并基于13项指标建立了页岩气井产能预测模型,预测结果与实测无阻流量平均符合率为75.8%。该文成果可有效指导中国页岩气高效开发,且具有重要理论意义。 展开更多
关键词 页岩气 储量动用 产能 生产规律 主控因素 预测模型
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辽河盆地清水洼陷及周边深层碎屑岩储层特征及成因 认领 引用 被引量：1
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作者 唐洁云 傅巍 +4 位作者 张向宇 张宏 张树田 蒋美忠 徐振旺 《非常规油气》 2026年第1期8-17,共10页
辽河坳陷深层砂岩勘探获得重大突破,清东地区4口百吨井,进一步展示了深层勘探的巨大潜力,但不同层段和不同沉积环境储层发育特征及含油气性差异较大,深层碎屑岩优质储层控制因素并不十分清楚。为了探明深层砂岩储层成因及受控因素,针对... 辽河坳陷深层砂岩勘探获得重大突破,清东地区4口百吨井,进一步展示了深层勘探的巨大潜力,但不同层段和不同沉积环境储层发育特征及含油气性差异较大,深层碎屑岩优质储层控制因素并不十分清楚。为了探明深层砂岩储层成因及受控因素,针对孔隙成因和储层主控因素不清晰等问题,开展了CT扫描、扫描电镜和X射线衍射(XRD)等检测研究。结果表明:(1)研究区深层砂岩发育原生孔隙带,普遍孔隙度大于10%,渗透率大于9.87×10-3μm2,具有孔大、吼道粗和渗透性相对高的特点;(2)沉积地质背景和水流条件差异,形成差异性成岩演化,导致了储层物性的巨大差异,属于优质储层发育的主控因素;(3)研究区沙二段和沙四段牵引流沉积原生孔隙发育带是最优质储层。 展开更多
关键词 深层碎屑岩 储层特征 主控因素 孔隙 清水洼陷 辽河盆地
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Differential enrichment mechanisms of organic matter in middle-upper Triassic lacustrine mudstone,north Kuqa depression(Tarim Basin,China):An integrated approach utilizing inorganic and organic geochemical evidence 认领 引用
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作者 Dejiang Li Qun Zhao +6 位作者 Lingyu Zhao Yanpeng Chen Ze Deng Xiangchun Chang Bingbing Shi Runye Han Shangbin Wang 《Acta Geochimica》 EI CAS CSCD 2026年第2期422-438,共17页
The Kuqa Depression,recognized as one of the best hydrocarbon-enriched depressions within the Tarim Basin,has long been debated regarding its principal source intervals,which has restricted petroleum exploration and d... The Kuqa Depression,recognized as one of the best hydrocarbon-enriched depressions within the Tarim Basin,has long been debated regarding its principal source intervals,which has restricted petroleum exploration and development in this area.This study focuses on the hydrocarbon source rocks of the Middle-Upper Triassic Karamayi Formation and Upper Triassic Huangshanjie Formation in the northern part of the Kuqa Depression through a comprehensive organic and elemental investigation.The examinations indicate that the source rocks of the Karamayi Formation-Huangshanjie Formation are dark mudstones developed in a lacustrine setting.The organic matter abundance generally ranges from fair to good.The organic matter type is mainly TypeⅡ,with a portion being TypeⅢ,and the source rocks have reached a mature stage.During the depositional period of the source rocks in the Karamayi Formation,variations in paleoproductivity,characteristics of ancient water bodies and intensity of hydrothermal activity together influenced the organic matter enrichment model of the Misbrac section,which is controlled by preservation conditions and paleoproductivity.In contrast,the Heiyingshan and Kuqa River sections exhibit paleoproductivity-dominated enrichment mechanisms.During the depositional period of the Huangshanjie Formation,the organic matter enrichment model in the study area is controlled by both the preservation conditions and paleoproductivity. 展开更多
关键词 Organic matter enrichment Lacustrine source rocks Main controlling factors Tarim Basin
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塔西南地区油气成藏主控因素与重点突破方向 认领 引用
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作者 耿锋 曹自成 +4 位作者 沙旭光 陈文凯 魏华动 杨素举 张云峰 《石油实验地质》 CAS CSCD 北大核心 2026年第3期529-541,共13页
塔里木盆地塔西南地区下寒武统玉尔吐斯组、石炭系卡拉沙依组烃源岩品质佳,古构造格局及断裂活动演化与油气充注关键期适配,储盖配置关系优越;近期多口井获得工业油气流,呈现多层系、多类型立体勘探的局面,但不同层位成藏控制因素及勘... 塔里木盆地塔西南地区下寒武统玉尔吐斯组、石炭系卡拉沙依组烃源岩品质佳,古构造格局及断裂活动演化与油气充注关键期适配,储盖配置关系优越;近期多口井获得工业油气流,呈现多层系、多类型立体勘探的局面,但不同层位成藏控制因素及勘探方向具有明显差异性。以逼近寒武系有效烃源岩发育区、聚焦麦盖提斜坡及和田与麦西两大古隆起、主攻三大领域为目标,对塔西南关键层位成藏主控因素及重点突破方向进行了系统研究。麦盖提斜坡寒武系主要目标区包括西段肖尔布拉克组缓坡背景下的颗粒滩(有利面积超过100 km2)、中段玉中地区东段上寒武统阿瓦塔格组前积体、东段玉东—玉中构造带盐下构造—岩性圈闭等。和田古隆起及周缘构造带奥陶系碳酸盐岩领域主要面向生烃坳陷的持续构造运动稳定区、继承性活动断裂带等晚期油气充注的有利目标区;规模储层形成和保存是关键,玉东断褶区6条后展式逆冲推覆构造带及岩溶叠合区、玉中低凸起3条走滑断裂+串珠状强反射的缝洞体叠合区为重点区带,地震上进行了多次波发育情况下小尺度缝洞体成像攻关。麦西古隆起巴什托地区上古生界在海西期之后长期位于构造高部位,寒武系、石炭系双源供烃,油气成藏有利,上倾方向以巴楚组生屑灰岩段高能滩相及东河塘组岩性—构造圈闭为目标,岳普湖区块以小海子组高能滩相有利圈闭为目标,采用保幅保真提高地震分辨率采集处理解释技术系列实现了针对薄层、致密砂岩储层的精准预测。 展开更多
关键词 圈闭 成藏主控因素 寒武系 奥陶系 上古生界 塔西南地区
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