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Multi-Scale Pore System and Its Implication for Shale Oil Occurrence in Alkaline Lacustrine Mixed Sedimentary Shale Reservoirs:A Case Study from Fengcheng Formation,Mahu Sag,Junggar Basin 认领 引用
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作者 Yuanhao Zhang Zhenxue Jiang +9 位作者 Jiaqi Chang Zhiye Gao Liliang Huang Wenjun He Chengju Zhang Lei Chen Qingqing Fan Yunhao Han Bolin Zhang Chao Chen 《Journal of Earth Science》 SCIE CAS CSCD 2026年第1期180-198,共19页
The pore structure of shale oil reservoir significantly affects the occurrence and mobility of hydrocarbons.The potential of a new type of alkaline lake shale oil has been demonstrated,but there are few reports on the... The pore structure of shale oil reservoir significantly affects the occurrence and mobility of hydrocarbons.The potential of a new type of alkaline lake shale oil has been demonstrated,but there are few reports on the pore system of alkaline lake shale,which restricts the efficient exploration and development of shale oil.This study investigates the Fengcheng Formation shale in the Mahu sag of the Junggar Basin,employing methods such as low-temperature nitrogecn adsorption(LTNA),mercury intrusion capillary pressure(MICP),and nuclear magnetic resonance(NMR)to quantitatively characterize the multi-scale pore structure and fractal characteristics of shale,while evaluating the applicability of these methods.Based on a comprehensive analysis of material composition,different pore types,and fractal dimensions,the controlling factors for the development of different pore types and their seepage capacity are discussed.The results indicate that inorganic mineral pores are the main development in alkaline lake shale,with the pore morphology being characterized by slit-like and ink-bottle shapes.The multi-scale pore size distribution(PSD)shows that Ⅱ-micropores(10-100 nm)and mesopores(100–1000 nm)are the main contributors to the pore system.The development of Ⅱ-micropores is associated with feldspar and calcareous minerals,the development of Ⅰ-micropores(1000 nm)exhibit good flowability.The high content of siliceous minerals plays a positive role in the pore system of alkaline lake shale.The shale with higher fractal dimension Dmin exhibits greater adsorption capacity,which hinders the accumulation of free-state shale oil.Different types of pore space play different roles in the occurrence of shale oil,with free-state shale oil primarily occurring in micro-fractures and inorganic mineral pores,and the pore size is exceeding 10 nm. 展开更多
关键词 alkaline lake shale multi-scale pore system fractal dimension nuclear magnetic resonance shale oil occurrence
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Genesis of reservoir heterogeneity and its impacts on petroleum exploitation in beach-bar sandstone reservoirs:A case study from the Bohai Bay Basin,China 认领 引用 被引量：6
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作者 Xiaofei Shang Jiagen Hou Yue Dong 《Energy Geoscience》 2022年第1期35-48,共14页
Reservoir characteristics of beach-bar sandstone reservoirs in the 2nd member of the Shahejie Formation in Banqiao Sag are studied by means of well logging interpretation,thin section observation and physical property... Reservoir characteristics of beach-bar sandstone reservoirs in the 2nd member of the Shahejie Formation in Banqiao Sag are studied by means of well logging interpretation,thin section observation and physical property analysis.Further,the influence of deposition,diagenesis and internal architecture interface on reservoir quality are quantitatively analyzed.On this basis,the geneses of reservoir heterogeneity of beach-bar sandstone reservoirs are summarized.The following results are obtained.(1)Primary pores,secondary pores and micro-fractures are the main types of reservoir space in the study area,and the primary intergranular pore is the main pore type;the microscopic heterogeneity of reservoirs is strong,and the physical properties of beach-bar reservoirs in different regions vary widely.(2)Tectonicdeposition,diagenesis and reservoir internal architecture work in unison to cause the heterogeneity of beach-bar reservoir quality in the 2nd member of the Shahejie Formation in Banqiao Sag;the locations and scales of beach-bar sand bodies are obviously different in different fault blocks in the study area,determining the macroscopic distribution of beach-bar reservoirs;differential diagenesis intensifies the degree of reservoir heterogeneity;the fine-grained argillaceous deposits between different architecture units of beach-bar reservoirs are critical to the quality of reservoirs.(3)The differential distribution of beach-bar reservoir quality parameters in the study area affects the spatial heterogeneity of reservoirs,which not only controls the original oil/gas distribution,but also has a significant influence on the effect of waterflooding and leads to the local enrichment of remaining oil. 展开更多
关键词 Beach-bar deposits Reservoir characteristics Reservoir quality difference Internal architecture Oil/gas development
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Research on the influence of mineral heterogeneity under different CO2injection schemes in low permeability reservoirs 认领 引用 被引量：2
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作者 Taskyn Abitkazy Yingfu He +5 位作者 Fuli Chen Dawei Yuan Xinhao Li Ying Bai Beknur Omarbekov Akhan Sarbayev 《Natural Gas Industry B》 2024年第3期291-302,共12页
In the pursuit of sustainable oil and gas resource extraction,the innovative integration of carbon capture,utilization,and storage(CCUS)technology has emerged as the most promising approach.During the CCUS process,int... In the pursuit of sustainable oil and gas resource extraction,the innovative integration of carbon capture,utilization,and storage(CCUS)technology has emerged as the most promising approach.During the CCUS process,intricate physicochemical interactions between the injected CO2,facilitated through various injection strategies(Water Alternative Gas:WAG/Continue Gas Injection:CGI)and the formation fluids and heterogeneous mineral assemblages within the reservoir trigger alterations in mineral structures,consequently impacting permeability and recovery factors,constituting a pivotal aspect.Precisely delineating and quantifying these interactions is paramount for optimizing process design and evaluating reservoir dynamics in the successful implementation of CCUS operations.This study has carried out qualitative and quantitative characterization of mineral heterogeneity,different pore types,and mineral combination characteristics from a low-permeability sandstone reservoir.Additionally,the effect on the physical properties of minerals from different development methods(WAG/CGI)was investigated using numerical simulation for CCUS applications.The results indicate that the saturated CO2fluid selectively dissolves the potassium feldspar(orthoclase)in intergranular pores,while the intergranular pores are filled with illite and secondary precipitated clay minerals.It initially dissolves the sensitive mineral(ankerite)in the intergranular pores.The decrease of ankerite and increase of illite result from the prolonged contact period between saturated CO2and minerals,which changes the mineral cementation to argillaceous type,thus affecting permeability in the context of CCUS.The spatial impact on reservoir physical properties depends on the spatial heterogeneity of the original sensitive minerals(ankerite,anorthite,illite,etc.)distributed in the study area.In the WAG scheme,the physicochemical interaction between saturated CO2and reservoir minerals is more intense than in the CGI scheme for CCUS operations,significantly impacting cumulative production. 展开更多
关键词 Low permeability reservoir Mineral heterogeneity CCUS Mineral dissolution Physical properties
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Occurrence of Global Natural Hydrogen and Profitable Preservation 认领 引用 被引量：3
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作者 Quanyou Liu Xiaoqi Wu +9 位作者 Xiaowei Huang Di Zhu Qingqiang Meng Dongya Zhu Huiyuan Xu Jiayi Liu Pengpeng Li Zheng Zhou Kaiqiang Zhang Zhijun Jin 《Journal of Earth Science》 SCIE CAS CSCD 2025年第4期1525-1554,共30页
Occurrence and abundance of molecular hydrogen in natural geologic reservoirs are enigmatic,due to its various sources,diverse migration pathways and complicated biological and chemical reactions.Natural gas samples c... Occurrence and abundance of molecular hydrogen in natural geologic reservoirs are enigmatic,due to its various sources,diverse migration pathways and complicated biological and chemical reactions.Natural gas samples containing hydrogen from producing wells in several sedimentary basins in China were collected in this study,and gas abundances and isotopic compositions of these gases were compared with those in global petroliferous basins and deep intrusive rocks.Several geochemical indicators were suggested for identifying sources,migration and accumulation mechanisms of hydrogen in the subsurface environment.Hydrogen contents in natural gas deposits have contributions from various sources with the following high-to-low order:microbial degradation>serpentinization>deep mantle volatile release>radiation-induced water decomposition>thermal cracking of organic matter.A hydrogen-rich reservoir in Kansas,USA,is specifically analyzed to determine its formation mechanism.This study suggests that future exploration of geological hydrogen resources may focus on the igneous rock bodies with overlying dense sedimentary rocks in the continental rift systems. 展开更多
关键词 “white”hydrogen hydrogen storage genetic identification enrichment and preservation geological distribution
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Pore formation and evolution mechanisms during hydrocarbon generation in organic-rich marl 认领 引用 被引量：3
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作者 Tong Wang Xiao-Feng Wang +6 位作者 Dong-Dong Zhang Qing-Tao Wang Hou-Yong Luo Jie Wang Zhong-Liang Ma Zhang-Xing Chen Wen-Hui Liu 《Petroleum Science》 SCIE EI CAS CSCD 2025年第2期557-573,共17页
Marine organic-rich marl is not only a high-quality hydrocarbon source of conventional oil and gas,but also a new type and field of unconventional oil and gas exploration.An understanding of its pore structure evoluti... Marine organic-rich marl is not only a high-quality hydrocarbon source of conventional oil and gas,but also a new type and field of unconventional oil and gas exploration.An understanding of its pore structure evolution characteristics during a hydrocarbon generation process is theoretically significant and has application prospects for the exploration and development of this special type of natural gas reservoirs.This study conducted thermal simulation of hydrocarbon generation under near-geological conditions during a whole process for cylinder samples of low mature marine organic-rich marl in the Middle Devonian of Luquan,Yunnan Province,China.During this process,hydrocarbon products at different evolution stages were quantified and corresponding geochemical properties were analyzed.Simultaneously,field emission scanning electron microscopy(FE-SEM)and low-pressure gas adsorption(CO2,N2)tests were applied to the corresponding cylinder residue samples to reveal the mechanisms of different types of pore formation and evolution,and clarify the dynamic evolution processes of their pore systems.The results show that with an increase in temperature and pressure,the total oil yield peaks at an equivalent vitrinite reflectance(VRo)of 1.03%and is at the maximum retention stage of liquid hydrocarbons,which are 367.51 mg/g TOC and 211.67 mg/g TOC,respectively.The hydrocarbon gas yield increases continuously with an increase in maturity.The high retained oil rate at the peak of oil generation provides an abundant material basis for gas formation at high maturity and over-maturity stage.The lower limit of VRofor organic matter(OM)pore mass development is about 1.6%,and bitumen pores,organic-clay complex pores together with intergranular pores,grain edge seams and dissolution pores constitute a complicated pore-seam-network system,which is the main reservoir space for unconventional carbonate gas.Pore formation and evolution are controlled synergistically by hydrocarbon generation,diagenesis and organic-inorganic interactions,and the pattern of pore structure evolution can be divided into four stages.A pore volume(PV)and a specific surface area(SSA)are at their highest values within the maturity range of 1.9%to 2.5%,which is conducive to exploring unconventional natural gas. 展开更多
关键词 Organic-rich marl Hydrocarbon generation-expulsion-retention process OM pores Pore evolution Organic-inorganic interactions
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Characteristics of Connected Pores and Evaluation of Shale Oil Mobility in the Qianjiang Formation,Qianjiang Sag,Jianghan Basin,China 认领 引用 被引量：2
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作者 Zhongliang Sun Zhiming Li +3 位作者 Chencheng He Feng Zhu Baojian Shen Longfei Lu 《Journal of Earth Science》 SCIE CAS CSCD 2025年第4期1591-1604,共14页
The connectivity of shale pores and the occurrence of movable oil in shales have long been the focus of research.In this study,samples from wells BX7 and BYY2 in the Eq3^4-10 cyclothem of Qianjiang Formation in the Qi... The connectivity of shale pores and the occurrence of movable oil in shales have long been the focus of research.In this study,samples from wells BX7 and BYY2 in the Eq3^4-10 cyclothem of Qianjiang Formation in the Qianjiang depression,were analyzed.A double mercury injection method was used to distinguish between invalid and effective connected pores.The pore characteristics for occurrence of retained hydrocarbons and movable shale oil were identified by comparing pore changes in low temperature nitrogen adsorption and high pressure mercury injection experiments before and after extraction and the change in the mercury injection amounts in the pores between two separate mercury injections.The results show that less than 50%of the total connected pores in the Eq34-10 cyclothem samples are effective.The development of effective connected pores affects the mobility of shale oil but varies with different lithofacies.The main factor limiting shale oil mobility in Well BX7 is the presence of pores with throat sizes less than 15 nm.In Well BYY2,residual mercury in injection testing of lamellar dolomitic mudstone facies was mainly concentrated in pores with throats of 10-200 nm,and in bulk argillaceous dolomite facies,it was mainly concentrated at 60-300 nm.The throats of hydrocarbon-retaining pores can be 5 nm or even smaller,but pores with movable shale oil in the well were found to have throat sizes greater than 40 nm.Excluding the influence of differences in wettability,the movability of shale oil is mainly affected by differences in lithofacies,the degree of pore deformation caused by diagenesis,the complexity of pore structures,and the connectivity of pore throats.Dissolution and reprecipitation of halite also inhibit the mobility of shale oil. 展开更多
关键词 Qianjiang depression double mercury injection effective connected pores retained hydrocarbons movable hydrocarbons hydrocarbons
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Sub-lacustrine debrite system:Facies architecture and sediment distribution pattern 认领 引用 被引量：1
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作者 Jian-Ping Liu Ben-Zhong Xian +13 位作者 Xian-Feng Tan Zhen Wang Jun-Hui Wang Long Luo Peng Chen Yan-Xin He Rong-Heng Tian Qian-Ran Wu Jia Wang Jin Li Long Chen Wen-Yi Peng Yi-Man Zhou Quan-Feng Jiang 《Petroleum Science》 SCIE EI CAS CSCD 2025年第1期110-129,共20页
The deep-water systems in different types of sedimentary basins exhibit significant variability.Current knowledge of deep-water deposition is mainly derived from deep-marine turbidite systems.However,the characteristi... The deep-water systems in different types of sedimentary basins exhibit significant variability.Current knowledge of deep-water deposition is mainly derived from deep-marine turbidite systems.However,the characteristics and differences of sub-lacustrine gravity flow deposition systems have been a research focus in the fields of sedimentology and petroleum geology.This study investigates the facies archi-tecture,depositional processes,and sediment distribution patterns of a sub-lacustrine debrite system in the Eocene Dongying Rift of the Bohai Bay Basin,China,through the analysis of integrated core data,3-D seismic data,and well-log data.Nine facies have been identified within the debrite system,representing various depositional processes such as sandy debris flow,muddy debris flow,turbidity currents,sandy slide,sandy slide/slump,and mud flow.Our research indicates that the sub-lacustrine system is primarily influenced by debris flow rather than turbidity currents,as supported by facies quantification,inter-pretation,and flow rheology analysis.Additionally,we have identified five basic facies building blocks in debrite systems,including slide masses,slump masses,debrite channels,debrite lobes,and turbidite sheets.We have also elucidated and proposed detailed sedimentary processes,flow transport,and transformation within the sub-lacustrine system through analysis of flow origins,facies sequences,and distribution characteristics.Our findings highlight the evolutionary progression from delta-front collapse to sandy slide/slump,sandy debris flow,and finally muddy debris flow.The efficient generation of turbidity currents from parental landslides on sand-prone slopes is deemed unlikely due to rift-basin morphology and transport distances.The formation of the five basic facies building blocks is closely linked to depositional processes and dominant flow types.Consequently,we present a deep-water depositional model for sub-lacustrine debrite systems,focusing on flow dynamics,sediment distribu-tion patterns,and basin morphology within deep lacustrine rifts.This model offers valuable insights into the variability of deep-water deposition in diverse basin settings and aids in predicting lithologic res-ervoirs during deep-water hydrocarbon exploration. 展开更多
关键词 Deep-water deposition Sediment gravity flow Debris flow Lacustrine basin Bohai Bay basin
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Mobility evaluation of continental shale oil of the Permian Fengcheng Formation in the Mahu Sag:Reservoirs characteristics,multiple influencing factors and conceptual models 认领 引用
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作者 Yuan-Hao Zhang Zhen-Xue Jiang +5 位作者 Jia-Qi Chang Zhi-Ye Gao Bo-Lin Zhang Zhi-Wei Wang Xiao-Xue Liu Li-Liang Huang 《Petroleum Science》 SCIE EI CAS CSCD 2025年第12期4910-4932,共23页
Mobility is a crucial metric for assessing sweet spots of continental shale oil.However,due to the complexity of shale oil reservoirs characteristics and the lack of systematic analyses of factors influencing mobility... Mobility is a crucial metric for assessing sweet spots of continental shale oil.However,due to the complexity of shale oil reservoirs characteristics and the lack of systematic analyses of factors influencing mobility,the difference in shale oil mobility under multiple lithofacies control remains unclear,causing significant challenges for mobility evaluation and sweet spot prediction.This study examines continental shales of the Fengcheng Formation in the Mahu Sag,employing scanning electron microscopy(SEM),nitrogen adsorption(NA),nuclear magnetic resonance(NMR),spontaneous imbibition(SI),and contact angle measurements(CAM)to investigate the pore structure,connectivity,and wettability properties of different lithofacies shale.Quantitative analyses of shale movable oil content and saturation were conducted using multistep temperature pyrolysis(MTP)and NMR centrifugation techniques.Furthermore,the influence of reservoir characteristics,geochemical characteristics,and lamination development on shale oil mobility were discussed.Results indicate that larger pore diameter,higher imbibition slopes,and lower fractal dimensions of movable fluid pores(D2)correspond to higher movable oil saturation.Organic matter exerts a dual effect on shale movable oil content.When the TOC is below a threshold,the movable oil content gradually increases with TOC.Laminations exhibit favorable reservoir properties and light oil enrichment,enhancing shale oil mobility.Massive siltstone(MS)develops interconnected intergranular pores with the best pore structure and connectivity,the lowest D2 values,and the highest shale oil mobility.Laminated felsic shale(LFS)and laminated calcareous shale(LCS)exhibit moderate mobility,where the development of microfractures enhances fluid flow by connecting isolated pores into pore-fracture networks.In contrast,massive felsic shale(MFS)and bedded felsic shale(BFS)primarily develop intragranular dissolution pores with more complex structures and poorer connectivity,resulting in weaker mobility.A more accurate approach for assessing shale oil mobility has been presented,taking into account both total oil content and movable oil saturation.More importantly,this study establishes a comprehensive conceptual model illustrating the potential relationships among shale lithofacies,reservoir characteristics,and movable oil flow space in the study area.This research not only provides a systematic approach for assessing shale oil mobility but also deepens the understanding of flow mechanisms of continental shale oil,offering theoretical guidance for optimizing sweet spots in the Fengcheng Formation shale oil reservoirs of the Mahu Sag. 展开更多
关键词 Continental shale Lithofacies Shale oil mobility NMR-centrifugation Pore structure Fengcheng Formation
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A salt-induced viscosifying smart polymer for fracturing inter-salt shale oil reservoirs 认领 引用 被引量：11
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作者 Xian’e Li Hong-Yao Yin +3 位作者 Ru-Sheng Zhang Jia Cui Jun-Wen Wu Yu-Jun Feng 《Petroleum Science》 SCIE CAS CSCD 2019年第4期816-829,共14页
Inter-salt shale oil reservoirs located between two salt layers are always accompanied by high temperature and high salinity. However, the present commonly used water-soluble polymers in fracturing fluids su er from p... Inter-salt shale oil reservoirs located between two salt layers are always accompanied by high temperature and high salinity. However, the present commonly used water-soluble polymers in fracturing fluids su er from poor tolerance to high temperature and high salinity. Thermoviscosifying polymers(TVP) whose aqueous solution shows viscosity increase upon increasing temperature and salt concentration have received considerable attention recently, which is promising for utilization in fracturing fluids to overcome these problems. In this work, both the salt-induced viscosifying property and mechanism of a TVP solution were investigated and the performance of TVP used as fracturing fluid based on the conditions of the Jianghan inter-salt shale oil reservoir in China was evaluated. It is found that the salt-induced viscosifying property of the TVP solution decreases with temperature and shear rate, but increases with polymer concentration. The number of intermolecular hydrophobic domains increases with the salt concentration contributing to the strengthening of a 3D network structure, which results in an increase in viscosity. In addition, the TVP fracturing fluid formulated with saturated brine exhibits excellent temperature and shear resistance, sand-suspending performance, and gel-breaking performance. Its viscosity remains above50 m Pa s after being sheared for 1 h even at a high temperature of 140 °C and the sand-suspending stability can be maintained for more than 1 week at 100 °C. Furthermore, the fracturing fluid can be easily broken down within 12h using 0.2 wt%–0.3 wt% potassium persulfate without residue. 展开更多
关键词 Fracturing Salt-induced viscosifying Thermoviscosifying Smart polymer Rheological properties
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Controlling factors of remaining oil distribution after water flooding and enhanced oil recovery methods for fracturecavity carbonate reservoirs in Tahe Oilfield 认领 引用 被引量：5
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作者 ZHENG Songqing YANG Min +5 位作者 KANG Zhijiang LIU Zhongchun LONG Xibin LIU Kunyan LI Xiaobo ZHANG Shiliang 《Petroleum Exploration and Development》 SCIE 2019年第4期786-795,共10页
Based on comprehensive analysis of core, well logging, seismic and production data, the multi-scale reservoir space, reservoir types, spatial shape and distribution of fractures and caves, and the configuration relati... Based on comprehensive analysis of core, well logging, seismic and production data, the multi-scale reservoir space, reservoir types, spatial shape and distribution of fractures and caves, and the configuration relationship with production wells in fracture-cavity carbonate reservoirs were studied systematically, the influence of them on the distribution of residual oil was analyzed, and the main controlling factors mode of residual oil distribution after water flooding was established. Enhanced oil recovery methods were studied considering the development practice of Tahe oilfield. Research shows that the main controlling factors of residual oil distribution after water flooding in fracture-cavity carbonate reservoirs can be classified into four categories: local high point, insufficient well control, flow channel shielding and weak hydrodynamic. It is a systematic project to improve oil recovery in fracture-cavity carbonate reservoirs. In the stage of natural depletion, production should be well regulated to prevent bottom water channeling. In the early stage of waterflooding, injection-production relationship should be constructed according to reservoir type, connectivity and spatial location to enhance control and producing degree of waterflooding and minimize remaining oil. In the middle and late stage, according to the main controlling factors and distribution characteristics of remaining oil after water flooding, remaining oil should be tapped precisely by making use of gravity differentiation and capillary force imbibition, enhancing well control, disturbing the flow field and so on. Meanwhile, backup technologies of reservoir stimulation, new injection media, intelligent optimization etc. should be developed, smooth shift from water injection to gas injection should be ensured to maximize oil recovery. 展开更多
关键词 carbonate rock fracture-cavity reservoir multiple scale remaining oil distribution main controlling factor enhanced oil recovery
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Conglomerate Reservoir Pore Evolution Characteristics and Favorable Area Prediction: A Case Study of the Lower Triassic Baikouquan Formation in the Northwest Margin of the Junggar Basin, China 认领 引用 被引量：12
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作者 Meng Xiao Songtao Wu +1 位作者 Xuanjun Yuan Zongrui Xie 《Journal of Earth Science》 SCIE CAS CSCD 2021年第4期998-1010,共13页
This study examines the characteristics and pore evolution of the Baikouquan conglomerate reservoir in the Mahu sag of the Junggar Basin from original sedimentation and diagenesis.Analysis is based on core observation... This study examines the characteristics and pore evolution of the Baikouquan conglomerate reservoir in the Mahu sag of the Junggar Basin from original sedimentation and diagenesis.Analysis is based on core observation,thin section,X-ray diffraction,cathodoluminescence and image analysis,and combined with physical property and well log data.The results show that conglomerate reservoir in the Baikouquan Formation can be divided into three lithofacies types:TypeⅠis argillaceous filling conglomerate facies,in which cementation and dissolution are not developed,and the interstitial material is mainly argillaceous;TypeⅡis tuffaceous filling in fine conglomerate facies,in which volcanic rock debris,illite and dissolution are developed;TypeⅢis sandstone filling conglomerate facies,in which cementation and dissolution are developed.The reservoir undergoes complex diagenesis,and the diagenetic sequence is:compaction→early chlorite film→early calcite cementation→detritus,feldspar and tuffaceous dissolution→quartz secondary enlargement→late calcite cementation→oil invasion→forming illite.Quantitative study of pore evolution shows that dissolution and calcite cementation are relatively developed in lithofacies Type III,and that compaction has a great influence on lithofacies TypeⅠand II.According to comprehensive evaluation of lithofacies,diagenesis and pore structure characteristics,the reservoir space type is mainly the dissolution pore.It is mainly primarily mainly composed of lithofacies Type III,thickness of the gravel body is more than 25 m,porosity is generally more than 12%,which represents favorable conditions for the distribution of favorable reservoir. 展开更多
关键词 conglomerate reservoir lithofacies pore evolution favorable reservoir Junggar Basin
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Construction of carbonate reservoir knowledge base and its application in fracture-cavity reservoir geological modeling 认领 引用 被引量：5
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作者 HE Zhiliang SUN Jianfang +3 位作者 GUO Panhong WEI Hehua LYU Xinrui HAN Kelong 《Petroleum Exploration and Development》 2021年第4期824-834,共11页
To improve the efficiency and accuracy of carbonate reservoir research,a unified reservoir knowledge base linking geological knowledge management with reservoir research is proposed.The reservoir knowledge base serves... To improve the efficiency and accuracy of carbonate reservoir research,a unified reservoir knowledge base linking geological knowledge management with reservoir research is proposed.The reservoir knowledge base serves high-quality analysis,evaluation,description and geological modeling of reservoirs.The knowledge framework is divided into three categories:technical service standard,technical research method and professional knowledge and cases related to geological objects.In order to build a knowledge base,first of all,it is necessary to form a knowledge classification system and knowledge description standards;secondly,to sort out theoretical understandings and various technical methods for different geologic objects and work out a technical service standard package according to the technical standard;thirdly,to collect typical outcrop and reservoir cases,constantly expand the content of the knowledge base through systematic extraction,sorting and saving,and construct professional knowledge about geological objects.Through the use of encyclopedia based collaborative editing architecture,knowledge construction and sharing can be realized.Geological objects and related attribute parameters can be automatically extracted by using natural language processing(NLP)technology,and outcrop data can be collected by using modern fine measurement technology,to enhance the efficiency of knowledge acquisition,extraction and sorting.In this paper,the geological modeling of fracture-cavity reservoir in the Tarim Basin is taken as an example to illustrate the construction of knowledge base of carbonate reservoir and its application in geological modeling of fracture-cavity carbonate reservoir. 展开更多
关键词 knowledge management reservoir knowledge base fracture-cavity reservoir geological modeling carbonates paleo-underground river system Tahe oilfield Tarim Basin
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Granite thermal reservoirs in Lingshui area of Hainan Island and their significance to geothermal resources,China 认领 引用 被引量：4
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作者 Xiaorui Yun Ying Zhang +2 位作者 Dingyong Liang Yanming Qu Haifeng Chen 《Energy Geoscience》 EI 2023年第4期159-170,共12页
Hainan Island located at the southernmost tip of the continental crust of the South China Plate,has high terrestrial heat-flow values,widely-distributed hot springs,and rich geothermal resources.Intensified researches... Hainan Island located at the southernmost tip of the continental crust of the South China Plate,has high terrestrial heat-flow values,widely-distributed hot springs,and rich geothermal resources.Intensified researches on the origin and potentials of geothermal resources can promote Hainan Island's development into a clean energy island.To determine the geological conditions for the formation of geothermal resources in southern Hainan Island,we collected core samples of granites from the Baocheng batholith in southern Hainan Island and conducted systematic analysis in respect of petrology,geochronology,geochemistry,and petrophysical property.The results of this study are as follows.The Baocheng batholith in the southern Hainan Island has a crystallization age of 98.42±0.56 Ma,making it the product of magmatism in the early stage of the Late Cretaceous.It mainly consists of high-K calc-alkaline granites,which were intruded by intermediate-to-mafic veins.The Baocheng batholith has a high radioactive heat generation rate of 2.712-6.843μW/m3,with an average of 3.846μW/m3,a radioactive heat-flow value of 30.768 μW/m2and a heat-flow contribution rate of 38.95%-43.95%.As shown by the results of their thermophysical property analysis,the granites have high thermal conductivity and can serve as highquality geothermal reservoirs.In combination with previous geological and geophysical data,the geothermal model of the Lingshui area was established in this study.The deep structure indicates the presence of high-conductivity and low-resistivity layers in the basement of the Baocheng batholith.It can be inferred thereby that asthenospheric upwelling may occur and that there exist two magma vents at depth in the batholith.Therefore,magmatic heat at depth and granites with high radioactive heat generation rate serve as the main heat sources in the Lingshui area. 展开更多
关键词 Hainan Island Geothermal energy Baocheng batholith Granite Radioactive heat flow Thermal conductivity
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Experimental analysis of matrix moveable oil saturation in tight sandstone reservoirs of the south Ordos Basin,China 认领 引用 被引量：3
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作者 Ting Xu Jun Pu +1 位作者 Xuejie Qin Yi Wei 《Energy Geoscience》 EI 2024年第1期184-195,共12页
Tight oil reservoirs in the south Ordos Basin are characterized by fractured,heterogeneous oil-bearing strata(an oil saturation of less than 55%on average),normal pressure(0.8±)and extra-low permeability(less tha... Tight oil reservoirs in the south Ordos Basin are characterized by fractured,heterogeneous oil-bearing strata(an oil saturation of less than 55%on average),normal pressure(0.8±)and extra-low permeability(less than 0.3 mD).In the Chang 8 tight sandstone reservoir in Honghe oilfield,micro-and nanopores,especially those with a pore-throat radius of less than 1 mm,account for more than 90%.Fluid flow in the matrix is non-linear and crude oil flow rates are very low under normal pressure gradients.An improved understanding of oil mobility in a tight matrix is key to further development of normalpressure tight-oil resources in the continental basin.In this study,constant-velocity and high-pressure mercury injection experiments were conducted using samples of typical tight sandstone cores obtained from the south of Ordos Basin.A new method for reconstructing the full-scale pore-throat distribution characteristics of tight sandstone reservoirs was established successfully,based on which multistage centrifugal tests,tests of low-pressure differential displacement of oil by water,and nuclear magnetic resonance tests were conducted in order to obtain the distribution characteristics of moveable fluid in different pores.The moveable oil saturation(MOS)and degree of oil recovery(i.e.ratio of accumulative oil production to producing geologic reserves)of the core samples under different differential pressures for displacement were determined.As for the tight oil reservoirs in the south Ordos Basin,the moveable fluids are mainly stored in sub-micron(0.10-0.5 mm)pores.For Type I reservoirs(k>0.1 mD),the volume percentage of moveable fluid in pores with a radius larger than 0.5 mm is relatively high(greater than 40%).The degree of oil recovery of water flooding serves as the basis for forecasting recoverable reserves for tight oil reservoirs.Recoverable reserves under water flooding,mainly occur in pores with a radius greater than 0.5 mm.The contribution of Type I reserves to oil production is observed to be greater than 60%,and the degree of oil recovery reaches up to 17.1%.These results help improve our understanding on the evaluation and classification of Chang 8 tight sandstone reservoirs in Honghe oilfield and serve as theoretical basis for pilot tests to explore effective injection media and development methods to improve the matrix-driven pressure differences and displacement efficiency for oil. 展开更多
关键词 Tight reservoir Pore-throat structure Moveable fluid volume Moveable oil saturation(MOS) Waterflooding oil recovery South Ordos basin
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Spatial configuration of sand and mud in the lacustrine nearshore sand bar deposits and its geological implications 认领 引用 被引量：2
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作者 SHANG Xiaofei DUAN Taizhong +1 位作者 HOU Jiagen LI Yan 《Petroleum Exploration and Development》 SCIE 2019年第5期954-968,共15页
Different configurational orders of sand bodies and interlayers in lacustrine nearshore sand bar reservoirs frequently interact,causing complicated genesis and distribution of argillaceous sediments,as well as other i... Different configurational orders of sand bodies and interlayers in lacustrine nearshore sand bar reservoirs frequently interact,causing complicated genesis and distribution of argillaceous sediments,as well as other issues.This paper investigates the spatial configuration of sand and mud in the sand bar reservoir,and analyzes its internal structure.Modern sand bar deposits in the Xiashan Lake,Shandong Province,China,were analyzed and compared with the sand bar reservoirs of the Member 2 of the Paleogene Shahejie Formation in the Banqiao Sag,China.The configurational mode of sand bar deposits was explored from the perspective of the spatial distribution and composition relationships between sand and mud.Based on the alternate deposition characteristics of sand and mud in the longitudinal direction,lacustrine nearshore sand bars can be divided into three sedimentary combination patterns:thin-sand and thin-mud interbed pattern,thick-mud thick-sand pattern,and thin-mud thick-sand pattern.Their mud components manifest as the deposition of fine-grained lithofacies of multiple genetic types.These include(semi-)deep lacustrine mud,sand and mud interbedded beach,argillaceous sediments in the water retention area behind the bar,and fall-silt seams that resulted from flood discharge.By summarizing the specific developmental locations and sequential relationships of each fine-grained argillaceous facies in modern sand bar deposits,a depositional process-based argillaceous sediment composition model is proposed.Based on this,this paper discusses the spatial configuration of sand bodies and argillaceous sediments in sand bar reservoirs,and introduces the typical stratigraphic structures of sand bars in two environments,i.e.,vertical superposition and lateral migration.In lacustrine nearshore sand bar reservoirs,the deposition and preservation degrees of mud mainly depend on three factors:accommodation space change,frequency of base-level cycles,and exposure-erosion time.These in turn influence the continuity and relative contents of sand and mud in reservoirs.The distribution of argillaceous sediments forms different orders of interlayers,which affects the heterogeneity and fluid percolation of sand bar reservoirs.Clarifying the space-matching relationship of sand and mud in sand bar deposits provides geological models and information parameters for the refined characterization and modeling of the internal configuration of sand bar reservoirs.Furthermore,this work offers guidance for the optimal adjustment of reservoir development strategies or the optimization of reservoir development plans. 展开更多
关键词 lacustrine nearshore sand bar internal structure modern deposit space configuration Xiashan Lake Banqiao sag
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Roles of gypsum/salt-bearing sequence in hydrocarbon accumulation and storage 认领 引用 被引量：2
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作者 Wenhui Liu Yining Li +5 位作者 Quanyou Liu Xiaofeng Wang Qingqiang Meng Dianwei Zhang Longfei Lu Houyong Luo 《Energy Geoscience》 EI 2023年第1期93-102,共10页
Gypsum/salt beds are widely developed in petroliferous basins across the world.Most basins with gypsum/salt beds have been proven to host abundant hydrocarbon resources.Previous studies on the effects of gypsum/salt b... Gypsum/salt beds are widely developed in petroliferous basins across the world.Most basins with gypsum/salt beds have been proven to host abundant hydrocarbon resources.Previous studies on the effects of gypsum/salt beds on hydrocarbon reservoirs primarily focused on their excellent sealing property as cap rocks.However,an increasing number of exploration discoveries have shown that gypsum/salt beds have the potential to promote the formation of high-quality source rocks and hydrocarbon reservoirs.Gypsum/salt beds influence the generation,preservation and accumulation of hydrocarbons.Based on the systematic analysis of the generation of hydrocarbons in global gypsum/saltbearing sequences,the study discussed the control of gypsum/salt beds on play elements,and explore the relationship between the development of gypsum/salt beds and global large-and medium-scale hydrocarbon reservoirs.Furthermore,we analyzed the correlation between typical gypsum/saltbearing sequences and their hydrocarbon generation potentials in China.In-depth analysis shows three patterns in terms of the spatial superimposition of gypsum/salt beds and source rocks,that is,postsalt pattern,inter-salt pattern and pre-salt pattern.Among others,the source rocks of the inter-salt pattern are widely developed in salt basins and of great potential for hydrocarbon exploration. 展开更多
关键词 Gypsum/salt bed Hydrocarbon reservoir Source rock Play element
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Organic-Inorganic Interaction Recorded by Polycyclic Aromatic Steranes in Continental Epithermal Ore Deposits 认领 引用 被引量：1
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作者 XU Huiyuan LIU Quanyou +4 位作者 JIN Zhijun ZHU Dongya MENG Qingqiang LI Pengpeng ZHU Biqing 《Acta Geologica Sinica(English Edition)》 SCIE CAS CSCD 2023年第1期327-336,共10页
Continental epithermal ore deposits are commonly associated with sedimentary organic matter,oils or solid bitumen.These organics embedded in mineral deposits can convey valuable information of the ore genesis.However,... Continental epithermal ore deposits are commonly associated with sedimentary organic matter,oils or solid bitumen.These organics embedded in mineral deposits can convey valuable information of the ore genesis.However,the extent to which the formation of ore minerals was recorded by organic compounds remains largely unknown,as also is how metal-rich ores interfere with the molecular proxies in the temperature regime envisaged for hydrothermal activity.The molecular compositional changes of various polycyclic aromatic steranes and polycyclic aromatic hydrocarbons and compounds derived from the Jinding Pb/Zn deposit,SW China provide new data.Aliphatic regular steranes are present as traces.The transformation from polycyclic aromatic steranes to unsubstituted polycyclic aromatic hydrocarbons is observed to show an increased trend with increasing hydrothermal alteration levels;this is consistent with the transformation from unsubstituted polycyclic aromatic hydrocarbons to heterocyclic compounds.Dehydrocyclization(aromatization)of polycyclic biological compounds and hydrodecyclization(dearomatization)of polycyclic aromatic compounds are two important reaction pathways in hydrothermal systems with moderate temperature.This detailed investigation of organicinorganic interactions of two groups of polycyclic compounds with metal-rich ores provides insights into the questions on how and to what extent the formation of Pb/Zn deposits can be recorded by organics.This work will improve our understanding of carbon reduction,oxidation or condensation in the deep Earth and the carbon exchange between the Earth's crust and mantle,and may shed light on the processes for ultra-deep hydrocarbon exploration. 展开更多
关键词 petroleum resources organic-inorganic interaction biomarker polycyclic compounds hydrothermal environment
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Fast inversion of array laterolog measurements in an axisymmetric medium 认领 引用 被引量：1
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作者 Hu Song Chen Long Wang Jin 《Applied Geophysics》 SCIE CSCD 2019年第4期539-548,562,共10页
The array laterolog is an important tool for complex formation logging evaluation due to its high resolution and large detection depth.However,its logging responses are seriously affected by leakage events due to the ... The array laterolog is an important tool for complex formation logging evaluation due to its high resolution and large detection depth.However,its logging responses are seriously affected by leakage events due to the surrounding rock and by mud invasion.These factors must be considered when inverting array lateral logging data,so that the inversion results reflect the true formation conditions as much as possible.The difficulties encountered in the inversion of array lateral logging data are:too many inversion parameters cause the calculation of the Jacobian matrix to be difficult and the time required to select the initial inversion values due to the slow forward-modeling speed.In this paper,we develop a fast processing method for array laterolog data.First,it is important to clearly define the main controlling factors for the array laterolog response,such as thickness,the surrounding rock,and invasion.Second,based on a depth-window technique,processing the array laterolog data for the entire well is transformed into multiple 2 D inversions of the layers using a series of continuous depth windows.For each formation in a depth window,combined with the1 D equivalent fast-forward algorithm,rapid extraction of the radial resistivity profile of the formation is achieved.Finally,the 1 D inversion result is used as the initial state to further eliminate the influence of surrounding rocks and layer thicknesses on the apparent resistivity response.Numerical simulation results show that the factors affecting the response of the array laterolog are the invasion properties,the layer thicknesses,and the surrounding rocks;the windowing technique greatly reduces the number of inversion parameters needed and improves the inversion speed.A real application of the method shows that 2 D inversion can rapidly reconstruct the actual resistivity distribution and improve the accuracy of reservoir saturation calculations. 展开更多
关键词 array laterolog 2D inversion invasion profile windowing treatment 1D inversion
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Intelligent architecture modeling for multilevel fluvial reservoirs based on architecture interface and elements 认领 引用
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作者 Bo Niu Xiangyang Hu +4 位作者 Shuijian Wei Wenbo Zheng Jie Xu Bin Liu Zhidong Bao 《Energy Geoscience》 EI 2024年第1期293-310,共18页
At present,the architecture modeling method of fluvial reservoirs are still developing.Traditional methods usually use grids to characterize architecture interbeds within the reservoir.Due to the thin thickness of thi... At present,the architecture modeling method of fluvial reservoirs are still developing.Traditional methods usually use grids to characterize architecture interbeds within the reservoir.Due to the thin thickness of this type of the interlayers,the number of the model grids must be greatly expanded.The number of grids in the tens of millions often makes an expensive computation;however,upscaling the model will generate a misleading model.The above confusion is the major reason that restricts the largescale industrialization of fluvial reservoir architecture models in oilfield development and production.Therefore,this paper explores an intelligent architecture modeling method for multilevel fluvial reservoirs based on architecture interface and element.Based on the superpositional relationship of different architectural elements within the fluvial reservoir,this method uses a combination of multilevel interface constraints and non-uniform grid techniques to build a high-resolution 3D geological model for reservoir architecture.Through the grid upscaling technology of heterogeneous architecture elements,different upscaling densities are given to the lateral-accretion bedding and lateral-accretion bodies to simplify the model gridding.This new method greatly reduces the number of model grids while ensuring the accuracy of lateral-accretion bedding models,laying a foundation for large-scale numerical simulation of the subsequent industrialization of the architecture model.This method has been validated in A layer of X oilfield with meandering fluvial channel sands as reservoirs and B layer of Y oilfield with braided river sands as reservoirs.The simulation results show that it has a higher accuracy of production history matching and remaining oil distribution forecast of the targeted sand body.The numerical simulation results show that in the actual development process of oilfield,the injected water will not displace oil in a uniform diffusive manner as traditionally assumed,but in a more complex pattern with oil in upper part of sand body being left behind as residual oil due to the influences of different levels of architecture interfaces.This investigation is important to guiding reservoir evaluation,remaining oil analysis,profile control and potential tapping and well pattern adjustment. 展开更多
关键词 Architecture modeling Interface restriction Architectural element Fluvial deposits Mid-channel bar Point bar
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Distributions and accumulation mechanisms of helium in petroliferous basins 认领 引用 被引量：7
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作者 Pengpeng LI Quanyou LIU +6 位作者 Dongya ZHU Di ZHU Zheng ZHOU Xiaoqi WU Qingqiang MENG Jiahao LV Yu GAO 《Science China Earth Sciences》 SCIE EI CAS CSCD 2024年第10期3143-3168,共26页
Helium is an irreplaceable strategic mineral resource, and commercial helium-rich gas fields(He>0.1%) worldwide are typically discovered serendipitously during hydrocarbon exploration efforts. According to an analy... Helium is an irreplaceable strategic mineral resource, and commercial helium-rich gas fields(He>0.1%) worldwide are typically discovered serendipitously during hydrocarbon exploration efforts. According to an analysis of 75 helium-rich gas fields and 1048 natural gas samples worldwide, helium in natural gas generally exhibits “scarce”, “accompanying”, and“complex” properties, and helium-rich gas fields often occur at depths 1%). However, geological reserves in the former two types of gas fields are mainly in the range of 107–1011m3, whereas in the latter, they are only in the range of 105–107m3. There are nevertheless notable disparities in the genesis and migration patterns between helium and gaseous hydrocarbons. Helium necessitates carriers(such as formation water, hydrocarbon fluids, N2, mantle-derived fluids, etc.) during both accumulation and long-distance migration processes, where migration conduits are not confined to sedimentary strata, and may extend to the basin's basement, lower crust, and even lithospheric mantle. However, the accumulation conditions of both helium and gaseous hydrocarbons are generally considered equivalent. The presence of gaseous hydrocarbons facilitates both the rapid exsolution of helium within helium-containing fluids and subsequent efficient aggregation in gaseous hydrocarbons, while both reduce helium diffusion and diminish escape flux. In terms of caprock, gypsum, salt, and thick shale as sealing layers contribute to the long-term preservation of helium over geological timescales. Large helium-rich gas fields, predominantly crust-derived gas fields, are primarily concentrated in uplifted zones of ancient cratonic basins and their peripheries. Based on a diagram of the He concentration versus He/N2 ratio, crust-derived helium fields can be categorized as basement, combined basement-sedimentary rock, and sedimentary rock helium supply types. Comprehensively given China's helium grade, helium resource endowment,natural gas industrialization process, and current helium purification processes, the foremost deployment zones for the commercial production of helium should be the helium-rich gas fields located in the Ordos, Tarim, Sichuan, and Qaidam Basins in western and central China. In addition, certain(extra) large helium-containing gas fields serve as important replacement zones. 展开更多
关键词 Helium resource Geochemical characteristics Helium source rock Helium supply pattern Accumulation mechanism Determination of favorable zones
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