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01 February 2020, Volume 41 Issue 1 Previous Issue    Next Issue

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OIL AND GAS EXPLORATION

Style and Evolution of Thrust Decollement in Miquan Area in Piedmont of Bogda Mountain YANG Yulong 2020, 41 (1):  1-8.  doi: 10.7657/XJPG20200101 Abstract ( 358 )   HTML ( 23 )   PDF (8289KB) ( 134 )   Save To determine the structural style and stratum distribution in the Miquan area in the piedmont of Bogda Mountain, the paper establishes a typical thrust decollement style in the study area based on the study of the fault development characteristics and the controls of detachment layer on structure development. Restricted by the Upper Triassic mudstone and the detachment coal layer in the Lower Jurassic Badaowan formation, the basement fault which underwent a low-angle slip and thrust from south to north along the detachment layer at the early stage and a updip at the late stage incised into the strata and exposed on the surface, and displayed a unique deckchair-like shape. The secondary faults are of small scale, whose ends are located in the detachment layer. The piedmont of Bogda Mountain is divided into 3 large structural belts such as nappe belt (basement nappe), thrust belt and decollement belt. Miquan area located in the thrust belt can be divided into 4 structural steps laterally and 3 structural layers vertically. Each structural layer is an active-roof duplex and the development degrees of the secondary faults are different from each other. The establishement of the thrust decollement style has overturned the preliminary understanding about the structures. It is considered that the strata under the nappe still belong to the lower reservoir-forming combination where many favorable traps could be discovered. The understanding has great significance for petroleum exploration in the lower combination in the piedmont of the southern margin, Junggar basin. Figures and Tables | References | Related Articles | Metrics

Structural Characteristics and Evolution in the Southern Margin of Junggar Basin ZHU Ming, WANG Xin, XIAO Lixin 2020, 41 (1):  9-17.  doi: 10.7657/XJPG20200102 Abstract ( 641 )   HTML ( 19 )   PDF (13286KB) ( 346 )   Save The understanding of the complex structures in the southern margin of Junggar basin is very important to explore the oil traps in the middle-deep strata and discover large oil and gas fields. In this paper, the structural characteristics and evolution of the fold-thrust belt in the southern margin of Junggar basin are studied based on 2D structural sections, quantitative analysis of structural deformation, and the complex structural model and tectonic activity time and deformation mechanism are determined. The research results show that the southern margin of Junggar basin underwent two stages of deformation in the Late Jurassic and Miocene, respectively. Strike slip faults were developed in the Late Jurassic during which Gaoquan fault-uplift zone, Aika structural belt and Qigu-south Anjihai strike-slip fault formed, which were belong to Mesozoic strike-slip fault system in the periphery of Junggar basin. Thrust and fold belt were developed during Miocene. The Cenozoic anticline over-lapped on Gaoquan fault-uplift zone and Aika structural belt in the western section of the southern margin. The drilling of Well Gaotan-1 proves that the anticline structures overlying on the paleostructures are favorable targets for exploration. Three rows of thrust faults and imbricate structures are developed in the middle section of the southern margin, and the middle and lower parts of the structures are the main targets for petroleum exploration. The Cenozoic thrust-fold belt extends from south to north in the southern margin of Junggar basin. Qigu fault-fold zone in the piedmont and the deep folds in the basin formed in the early Miocene (23 Ma), the Huo-Ma-Tu thrust fault occurred at the end of Miocene(7 Ma), and Hutubi anticline and Kayindike anticline formed in Quaternery. Figures and Tables | References | Related Articles | Metrics

Discovery of Ultra-Deep Rift Basin and Its Petroleum Exploration Significance in Sikeshu Sag, Junggar Basin LIANG Zeliang, PANG Zhichao, JI Dongsheng, FENG Xingqiang, WU Lin, SHI Hui 2020, 41 (1):  18-24.  doi: 10.7657/XJPG20200103 Abstract ( 422 )   HTML ( 11 )   PDF (19864KB) ( 256 )   Save A major breakthrough in petroleum exploration has been made in the Sikeshu sag of the southern margin of Junggar basin and the deep geological structures, basin framework and prototype basin in the sag have attracted much attention. Based on the latest 2D seismic data, this paper analyzes the seismic reflection and structural characteristics of the deep strata in the Sikeshu sag, determines the prototype basin and restores the tectonic evolution process of the Sikeshu sag. The study results show that the Carboniferous-Cenozoic strata are widely developed in the Sikeshu sag and their thickness centers are inherited. The Sikeshu sag has a fault depression-depression structure. Taking the bottom of the Jurassic as the boundary, the structure under the boundary is a fault depression characterized by thick volcanic-clastic deposits with noted boundary faults of the prototype basin, whereas the structure above the boundary is a depression filled with terrestrial debris deposits of Jurassic-Cretaceous, which is characterized by undeveloped faults, wide distribution range and thin sedimentary thickness. Combined with regional tectonic evolution and local geological structure, the evolution of the Sikeshu sag can be divided into two stages, namely rift and depression. The Sikeshu sag might have a relatively independent tectonic-sedimentary evolution during the rift stage, and was connected with Junggar basin during the depression stage. This paper believes that the syndepositional Gaoquan fault as one of the boundary faults of the rift basin, was an active normal fault and reversed to a thrust fault in the late stage. The Permian-Triassic shales and Jurassic coal seams controlled by the rift basin are the main source rocks of the ultra-deep strata in the Sikeshu sag and have great petroleum exploration potenital. Figures and Tables | References | Related Articles | Metrics

Genesis of Oil and Gas in Sikeshu Sag in the Southern Margin of Junggar Basin REN Jiangling, WANG Feiyu, ZHAO Zengyi, ZHANG Yunpei, MI Julei, LIU Cuimin 2020, 41 (1):  25-30.  doi: 10.7657/XJPG20200104 Abstract ( 340 )   HTML ( 17 )   PDF (761KB) ( 282 )   Save The oil found in the Sikeshu sag in the southern margin of Junggar basin is the light oil with associated wet gas, but the properties of the oil and gas in different regions are different and there are some disputes about the hydrocarbon sources. The samples of the Middle-Lower Jurassic and Middle-Upper Triassic source rocks obtained from the oucrops in the southern margin are selected. Based on the analysis of rock pyrolysis, choloroform asphalt A, gas chromatography and organic petrology and combined with geochemical analysis of the source rocks, the paper analyzes the geochemical properties of the source rocks of Triassic, Jurassic and Paleogene in the Sikeshu sag, determines the organic phases of the source rocks and discusses the genesis and origin of the oil and gas. The study results show that the light oil and gas in the Sikeshu sag mainly come from the source rocks of the Lower Jurassic Badaowan formation, probably from the Middle-Upper Triassic source rocks; the oil in Dushanzi oilfield and the Neogene Xihu anticline mainly comes from Jurassic or Triassic source rocks, partial oil from the source rocks of the Paleogene Anjihaihe formation. Figures and Tables | References | Related Articles | Metrics

Hydrocarbon Generation of Jurassic Source Rocks in the Southern Margin of Junggar Basin MA Wanyun, Dilidaer ROUZI, LI Ji, LIAO Jiande, WANG Haijing, HE Dan 2020, 41 (1):  31-37.  doi: 10.7657/XJPG20200105 Abstract ( 336 )   HTML ( 18 )   PDF (797KB) ( 453 )   Save The source rocks in the Lower and Middle Jurassic strata are generally considered as the major source rocks in the southern margin of Junggar basin. In order to deepen the understandings on the hydrocarbon generation features and distribution of the source rocks, the paper teases out the results of sedimentary and geochemical analysis on 9 outcrop sections and the data from 9 wells in the southern margin of Junggar basin, carries out thermal simulation experiments on hydrocarbon generation for mudstone, carbonaceous mudstone and coal, and studies the hydrocarbon generating evolutions of the 3 types of source rocks by combining with oil-source correlation. The study results show that in the southern margin of Junggar basin, medium-good source rocks are developed in the Lower Jurassic Badaowan formation, medium-quality source rocks are mainly distributed in the Middle Jurassic Xishanyao formation and the Lower Jurassic Sangonghe formation and coal acts as the important source rocks of gas. The oil mainly comes from the Jurassic dark mudstone and the mudstone in the Badaowan formation is the best source rock and widely distributed, which should be considered as the major hydrocarbon generation zone. The key gas generation and expulsion period of the Jurassic source rocks was the phase when the vitrinite reflectance reached 0.9%-1.8%, and the Huo-Ma-Tu anticline belt is located in the Jurassic hydrocarbon generating center in the southern margin of Junggar basin, where the vitrinite reflectance is generally higher than 2.0%. Therefore, the Huo-Ma-Tu-Hu anticline belt is the most favorable area for natural gas exploration. Figures and Tables | References | Related Articles | Metrics

Reservoir Characteristics and Main Controlling Factors of Cretaceous Qingshuihe Formation in the Southern Margin of Junggar Basin SI Xueqiang, YUAN Bo, GUO Huajun, XU Yang, CHEN Nenggui, PENG Bo 2020, 41 (1):  38-45.  doi: 10.7657/XJPG20200106 Abstract ( 341 )   HTML ( 11 )   PDF (6429KB) ( 537 )   Save Profitable oil and gas flows of over 1,000 m 3/d have been obtained from the sandstone reservoir of the Cretaceous Qingshuihe formation in the Sikeshu sag of the southern margin, Junggar basin, which proves that the formation belongs to a set of high-quality reservoir. Based on the analysis of outcrop sections and drilling data and using polarizing microscope, pore and permeability analyzer and confocal laser scanning microscope, the paper analyzes the rock mineral, physical property and pore structure of the sandstone samples from the Qingshuihe formation and carries out researches on diagenetic evolution by combining with its burial history. The results show that the sandstone of Qingshuihe formation mainly containing feldspar lithic sandstone and lithic sandstone is characterized by a little matrix, medium content of cements and developed residual intergranular pores, which is at the Phase A of the middle diagenetic stage with the compaction dominated by pore reduction. The comprehensive analysis shows that the formation of the high-quality reservoir in Qingshuihe formation is controlled by 3 key factors such as early long-term shallow burial and late rapid deep burial, developed fractures and abnormal high formation pressure. The early long-term shallow burial and the late rapid deep burial are favorable for preservation of primary pores in the reservoir; both intragranular microfracture and bedding fracture are developed, which is helpful for the formation of efficient flowing paths in the sandstone reservoir; and the abnormal high formation pressure contributes to the preservation of intergranular pores and the opening of fractures. Figures and Tables | References | Related Articles | Metrics

Diagenetic Characteristics and Evaluation of Lower-Middle Jurassic Reservoirs in Qigu Fault-Fold Belt, Junggar Basin GUO Huajun, SI Xueqiang, TANG Xueying, XU Yang, PENG Bo 2020, 41 (1):  46-54.  doi: 10.7657/XJPG20200107 Abstract ( 331 )   HTML ( 13 )   PDF (19262KB) ( 115 )   Save Several sets of sandstone reservoirs from the Lower-Middle Jurassic strata are well developed in the Qigu fault-fold belt of the southern margin of Junggar basin. Based on the analysis of the outcrop section and drilling data and by using polarized microscope, porosity-permeability analyzer and SEM, the paper analyzes the rock and mineral characteristics, diagenesis, diagenetic facies and physical properties of the sandstone samples from the Lower-Middle Jurassic strata and performs reservoir classification and evaluation. The results show the sandstone from the Lower-Middle Jurassic strata in Qigu fault-fold belt is dominated by feldspathic litharenite and litharenite, which is characterized by medium textural maturity and low compositional maturity. The diagenetic process mainly includes compaction, cementation and dissolution. Different diagenetic facies directly affect the physical properties of the reservoir, which can be divided into low matrix content and weak cementation diagenetic facies, unstable mineral dissolution diagenetic facies, carbonate cementation diagenetic facies and matrix filling-compaction diagenetic facies. The Lower-Middle Jurassic reservoir can be classified into 6 types of 2 categories and some oil and gas reservoirs are tight sandstone reservoirs. Figures and Tables | References | Related Articles | Metrics

Coupling Relationship Between Densification Process and Hydrocarbon Charging Timing in Sandstone Reservoirs of Badaowan Formation in Qigu Fault-Fold Belt, Junggar Basin YANG Disheng, YAN Guihua, ZHOU Tianqi, LI Yan 2020, 41 (1):  55-66.  doi: 10.7657/XJPG20200108 Abstract ( 280 )   HTML ( 4 )   PDF (7731KB) ( 91 )   Save To reveal the relationship between densification process and hydrocarbon charging in the tight sandstone reservoir of the Lower Jurassic Badaowan formation in the Qigu fault-fold belt of the southern margin of Junggar basin, the diagenetic history of the sandstone reservoir in Badaowan formation is studied on the basis of casting thin section observation, X-ray diffraction, field emission-SEM and fluid inclusion analysis. The paper integrates the hydrocarbon generation and expulsion history of source rocks, stratigraphic burial history and thermal history simulation to restore the densification process and pore evolution history of the sandstone reservoir, and discusses the influences of the relationship between sandstone reservoir densification and hydrocarbon charging timing on reservoir type by combining with hydrocarbon charging history. The study results show that 4 diagenetic facies of the tight sandstone in Badaowan formation can be identified such as quartz secondary enlargement-dissolution, matrix-strong compaction, carbonate mineral cementation and authigenic clay mineral cementation, among which the porosity and permeability of quartz secondary enlargement-dissolution facies are relatively good. The desification of the reservoir is caused by high content of matrix, serious carbonate mineral cementation, limited dissolution and pore plugged by authigenic clay minerals. Moreover, the tight sandstone of Badaowan formation in Qigu fault-fold belt which belongs to the reservoir of “hydrocarbon accumulation after reservoir densification” experienced 3 periods of oil and gas charging—during the period Ⅰ, most sandstone reservoir had been densified before low maturity oil charging; during the period Ⅱ and Ⅲ, low maturity oil and high maturity oil migrated along the Qigu fault, charged and finally accumulated in the tight sandstone under overpressure. At the end of Neogene, the core of the Qigu anticline began to denudate, resulting in the significant reduction of residual pressure and the loss of hydrocarbon. After structural reformation the paleo-reservoirs became small-scaled tight reservoirs. The hydrocarbon accumulation process indicates that the traps located in the high positions of Qigu anticline and in the second row and third row of structural belts have great potential for oil and gas exploration. Figures and Tables | References | Related Articles | Metrics

Sedimentary Sequence and Depositional Environment Evolution of Upper Jurassic-Lower Cretaceous Strata in the Southern Margin of Junggar Basin GUAN Xutong, WU Chaodong, WU Jian, ZHOU Jiaquan, JIAO Yue, ZHOU Rong, YU Qingsen 2020, 41 (1):  67-79.  doi: 10.7657/XJPG20200109 Abstract ( 601 )   HTML ( 9 )   PDF (16674KB) ( 314 )   Save The sedimentary facies of the Upper Jurassic-Lower Cretaceous strata in the southern margin of Junggar basin can be divided into meandering river, alluvial fan, alluvial fan transformed by lake and shallow lake facies. According to the architecture element analysis, 10 main lithofacies is classified, among which polymictic Gm1 supported by matrix is massive maroon conglomerate with fine-coarse grain size, poor sorting and roundness; polymictic Gm2 supported by grain is massive brown conglomerate with fine-medium grain size, moderate-poor sorting and roundness; Gm3 supported by grain is massive greyish green or orange fine conglomerate with good sorting and roundness. Some seismite structures were developed during the depositional periods of Gm1 and Gm2. During the Middle to Late Jurassic, the climate was arid, structural activities were active in the northern Tianshan, the basin was filled rapidly and the accommodation space reduced and meandering river deposits were developed in the Upper Jurassic Qigu formation. Under the influence of the rapid closure of the Mongol-Okhotsk Ocean, the extensional tectonic setting evolved to a local compressive setting, structural activities in the northern Tianshan continued, the basin contracted, the accomodation space reduced, and the boundary of the basin withdrew from the central Tianshan to northern Tianshan. During the deposition period of the Upper Jurassic Kalazha formation, brownish red fluvial fan sediments were widely developed in the southern margin of Junggar basin and the filling of the Jurassic basin ended. During the deposition period of the Lower Cretaceous Qingshuihe formation, the Mongolia-Okhotsk Ocean closed, the tectonic setting became stable, the basin expanded and the accommodation space increased, large-scale rapid lake transgression occured, the climate became humid, then fluvial fan deposits were developed in the southern margin, followed by shallow lake deposits, greyish green or orange lacustrine conglomerate and fine deposits, indicating the beginning of the filling of a Cretaceous basin. Figures and Tables | References | Related Articles | Metrics

Comparative Analysis on Sedimentary and Reservoir Characteristics of Jurassic to Cretaceous Between Foreland Basins in Southern and Northern Tianshan Mountains GAO Zhiyong, FENG Jiarui, CUI Jinggang, ZHOU Chuanmin, SHI Yuxin 2020, 41 (1):  80-92.  doi: 10.7657/XJPG20200110 Abstract ( 386 )   HTML ( 6 )   PDF (5024KB) ( 391 )   Save Based on the comparative analysis of the Jurassic and Cretaceous strata in Kuqa depression and the southern margin of Junggar basin, it is considered that the paleotopography in the southern Tianshan was higher than that in the northern Tianshan before the Early Cretaceous, which is the main reason causing the significant differences in the thickness, lithologic association and sedimentary facies in the 2 areas. Furthermore, it is identified that each Jurassic formation in Kuqa depression is thinner than that in the southern margin of Junggar basin and the genetic mechanism of different sedimentary environments in the Early Jurassic is determined. From the Late Jurassic to Early Cretaceous, the differences in ancient climate, tectono-paleogeography and topography, and the structural uplifting and denudation at the end of Late Cretaceous resulted in the differences in sedimentary environment and thickness, clastic component, burial mode and fracture development degree in the 2 areas. On the basis of further determination of the lithofacies palaeogeography characteristics and favorable sandbody distribution in the deep strata of the southern margin, the paper analyzes the differences in reservoir and its controlling factors between the foreland basins in the southern and northern Tianshan Mountains, concludes that the deep reservoirs in the southern margin with relatively low exploration degree are controlled by sedimentary facies, geothermal gradient, burial mode, abnormal high pressure, secondary dissolution and tectonic fracture, and points out the favorable areas for reservoir distribution in the deep strata of the southern margin of Junggar basin. Figures and Tables | References | Related Articles | Metrics

Genesis and Distribution of Shallow Conglomerates in the Southern Margin of Junggar Basin DENG Yong, CHEN Peng, ZHANG Xin, ZHOU Zhisong, TIAN Chenxi, LIU Yahui, ZENG Xiaolan 2020, 41 (1):  93-99.  doi: 10.7657/XJPG20200111 Abstract ( 454 )   HTML ( 9 )   PDF (18205KB) ( 142 )   Save The hugely thick conglomerates are widely developed in the shallow layers of the southern margin of Junggar basin, which leads to the poor seismic imaging quality of the shallow layers and the difficulties in accurate determination of the structural high and configuration of the underlying target zone. Based on the analysis of the structure, sedimentary evoluation and ancient landform in the southern margin of Junggar basin since Neogene, the paper identifies the geological framework, establishes the genetic model and determines the distribution of the conglomerate layer. The study shows that the conglomerate in the southern margin of Junggar basin can be divided into low-speed conglomerate and high-speed conglomerate vertically. A geological genetic model of “segmented by the ancient swell horizontally, multistage fan overlapping and progradation in the early period and rapid accumulation in the late period vertically” is established, which was controlled by multistage tectonic movements, paleostructure and sediment supply during the Himalayan period. The conglomerate layer is segmented by the ancient Chepaizi swell, where 2 alluvial fan groups are developed in the east and west, respectively and can be further divided into 5 alluvial fans. The conglomerate layer is thick in the south and thin in the north, among which the high-speed conglomerate is relatively thick and low-speed conglomerate is relatively thin. The eastern alluvial fan group is controlled by 3 rows of positive tectonics and 3 N-S trending conglomerate belts are developed in the eastern fan group. Figures and Tables | References | Related Articles | Metrics

Mudstone Caprock Sealing Capacity of the Lower Reservoir-Forming Combination in the Foreland Thrust Belt of the Southern Margin, Junggar Basin ZHUO Qingong, LEI Yongliang, BIAN Yongguo, CHEN Zhuxin, HU Hanwen 2020, 41 (1):  100-107.  doi: 10.7657/XJPG20200112 Abstract ( 297 )   HTML ( 8 )   PDF (941KB) ( 288 )   Save Cretaceous and Jurassic mudstone caprocks of the lower reservoir-forming combination are widely distributed in the foreland thrust belt of the southern margin of Junggar basin, which are featured with high displacement pressure and very strong sealing capacity. However, the destruction of the strong tectonic compression to caprock sealing capacity at the late stage can not be ignored. The results of physical simulation and numerical simulation of triaxial compression of the mudstone show that the thick and homogeneous mudstone in the deep strata has high compressive strength and strong sealing capacity. Under the compression, the mudstone layers with different dip angles have three deformation modes such as plasticity, brittleness and periodic brittleness-plasticity alternation. According to the actual geological conditions and case analysis of the mudstone in the lower reservoir-forming combination, the mudstone caprock in the foreland thrust belt of the southern margin of Junggar basin is divided into four districts, and the dynamic evolution of the sealing capacity of the mudstone caprocks in different districts controls the hydrocarbon accumulation and distribution in the foreland thrust belt. Figures and Tables | References | Related Articles | Metrics

APPLICATION OF TECHNOLOGY

Identification and Characterization of Middle-Shallow Conglomerates of Sikeshu Area in the Southern Margin of Junggar Basin FAN Xu, LIU Yiwen, ZHENG Hongming, MA Junyan, YIN Lili 2020, 41 (1):  108-113.  doi: 10.7657/XJPG20200113 Abstract ( 317 )   HTML ( 6 )   PDF (9332KB) ( 107 )   Save The middle-lower assemblage structure in the southern margin of Junggar basin is generally located below the middle-shallow gravel belt, and the conglomerates are characterized by wide and irregular lateral distribution and large variations of vertical velocity, which seriously restrict the fine identification of the targets in the middle-lower assemblage. Therefore, it is very important to figure out the structure and distribution of the gravel belt for accurately identifying the configuration and high point position of the underlying structure. Combining micro-logging and drilling data with seismic sections, the paper analyzes the structural characteristics of middlle-shallow conglomerates, describes the top and bottom interfaces of low-speed and high-speed conglomerate intervals of the Sikeshu area in the southern margin of Junggar basin, and establishes time-depth curves by districts and sections, which can be used to guide the accurate depth-domain mapping of composite structures and the velocity model building of the middle and shallow layers for prestack depth migration. The application result shows that the identification and characterization of the middle-shallow conglomerate of the Sikeshu area in the southern margin of Junggar basin is of great help for the accurate determination of the structural objectives and the imaging quality improvement of the seismic sections, which can also be applied in other similar areas in the southern margin of Junggar basin. Figures and Tables | References | Related Articles | Metrics

Progress and Application of Imaging Technology for Complex Structures in the Southern and Northern Tianshan Mountains HUANG Lijuan, LUO Wenshan, FANG Yong, DONG Yuwen, WU Xinxing, LI Guangpeng 2020, 41 (1):  114-119.  doi: 10.7657/XJPG20200114 Abstract ( 338 )   HTML ( 8 )   PDF (18070KB) ( 115 )   Save It is very difficult to obtain the accurate images of the underground complex structures in the foreland thrust belts of the northern and southern Tianshan Mountains because the structures are very complicated both at the surface and underground, and the velocity modeling of TTI prestack depth migration and imaging technology can be used to solve the problem. At present, the velocity modeling of TTI prestack depth migration and imaging technology mainly include the static correction technology matched with prestack depth migration, prestack denoising technology and TTI anisotropic velocity modeling and depth migration technology, which can integrate static correction, denoising and velocity modeling technologies and provide an accurate velocity model for prestack depth migration. Finally, the imaging quality and precision of the complex structures are improved and the drilling consistency rises year by year, which proves that the technology can provide support to well allocation and petroleum exploration in the foreland thrust belts of the northern and southern Tianshan Mountains. Figures and Tables | References | Related Articles | Metrics

Deformation Mechanism of Hutubi Anticline in the Southern Margin of Junggar Basin: Insights From Physical Simulation Experiment ZHANG Xichen, MA Delong, WEI Lingyun, WANG Hongbin, WANG Yanjun, LIU Wenqiang, YANG Xiulei 2020, 41 (1):  120-126.  doi: 10.7657/XJPG20200115 Abstract ( 377 )   HTML ( 7 )   PDF (4125KB) ( 356 )   Save The fold-thrust belts in the southern margin of Junggar basin are characterized by multi-stage superimposition and deformation. The Hutubi anticline located in the front of the thrust is far away from the Tianshan Mountains and shows a double-layer structure, among which the deep layer is a Permian fault-depression-paleohigh and the shallow layer is a fault anticline of Jurassic with its overlying strata. To investigate the main controls on the shallow anticline formation and the vertical deformation mechanism of the Hutubi anticline, 5 groups of models are designed to perform physical simulation study by using control variable and comparative analysis methods on the basis of the identification of structural style and deformation laws. The study results show that the experimental result of the fault-depression-paleohigh model is similar to the seismic interpretation result. As the main controlling factor, the paleohigh in the fault-depression margin induced the overlying strata to deform into anticlines, which can prove the time-space coupling relations between the deep layer and shallow layer in the Hutubi anticline. The shape of the shallow anticline is also controlled by the combination of the scale of the underlying fault-depression, the thickness of the overlying strata and the syntectonic sedimentation. It is a scientific and effective method to reveal the correlation and deformation mechanism of vertical superimposed structures by using physical simulation experiments, which could provide more basis for petroleum exploration and production in the foreland area of the southern margin of Junggar basin. Figures and Tables | References | Related Articles | Metrics