IntroductionThe petroleum basin system in Northeast China is characterized by the Songliao Basin and its Mesozoic–Cenozoic peripheral small-to medium-sized basins. With escalating exploration challenges and operational costs in the mature Songliao Basin, strategic attention has shifted to evaluating hydrocarbon potential in these under-explored peripheral basins to address regional energy security and production sustainability.MethodsThis study investigates the eastern peripheral basins of Songliao, comprising 40 structurally segmented depressions where Lower Cretaceous strata serve as the principal hydrocarbon source interval. Despite their significance, systematic understanding of Cretaceous source rock distribution, geochemical heterogeneity, and hydrocarbon generation drivers in this region remains limited.ResultsThrough integrated geochemical profiling of Lower Cretaceous source rocks across representative basins (e.g., Sanjiang, Boli, Tonghua, and Liuhe), we present the first systematic characterization of spatial variations in source quality parameters, including lithology (e.g., brittle mineral assemblages), organic richness, thermal maturity, and kerogen type, and introduce “Moho depth” as a key controlling factor for explaining the north-south difference in organic matter maturity. The analysis further deciphers tectono-depositional controls on source rock development, particularly the coupling between rift architecture and lacustrine redox fluctuations.DiscussionThese insights advance regional petroleum system models and establish a predictive framework for hydrocarbon exploration targeting in Northeast China’s frontier basins.

This study is based on field observations and sample collections from the Panjinbulak, Qiongbulak, and Qunjisayi outcrops in the Yining Sag of the Ili Basin. Using organic geochemical analysis methods, the characteristics and hydrocarbon generation potential of the Permian Xiaoshansayi Formation (P2x) and Tamqisayi Formation (P2t) source rocks in the Yining Sag were compared and analyzed. The results indicate that the Permian source rocks in the Yining Sag of the Ili Basin exhibit high organic matter abundance and good types, among which the P2t source rocks are overall superior to the P2x. The P2t source rocks in the Panjinbulak outcrop section on the northern margin are dominated by Type II1-II2 kerogen, while those in the Qunjisayi and Qiongbulak outcrop sections on the southern margin show a transition to Type II2-III kerogen. The maturity of Permian source rocks presents a pattern of "higher in the south and lower in the north", and all have reached the hydrocarbon-generation threshold. The northern margin is in the oil window, mainly dominated by oil generation; the southeastern margin has higher maturity, mainly producing oil/condensate gas. The Permian source rocks were deposited in a saline-reducing environment, with mixed input of aquatic organisms and terrestrial plants. During the deposition of P2t source rocks in the northern margin, the water salinity was higher, and plankton such as cyanobacteria made prominent contributions. The P2t source rocks in the Panjinbulak outcrop section on the northern margin have relatively better organic matter abundance and type, making it the main hydrocarbon-generation-potential area. The source rocks in the Qunjisayi outcrop section on the southeastern margin are slightly poorer, but their maturity is higher, currently in the main oil window, representing a secondary hydrocarbon-generation-potential area.

The Hexi Corridor Basin Group, renowned for its Carboniferous source rocks, has emerged as a pivotal target for oil and gas exploration. This study integrates fieldwork, drilling, and geochemical data to analyze the Carboniferous lithofacies and paleogeography of the basin group, which is marked by extensive transgressive deposits. The Hexi Corridor experienced three key evolutionary phases during the Carboniferous. During the Early Carboniferous (deposition stage of the Qianheishan and Chouniugou Formations), crustal subsidence formed the Qilian epicontinental sea. Marine water intruded from the southeastern Qinling Mountains, and clastic sediments were supplied by the Alashan and Ordos oldlands to the north, developing lagoon-tidal flat facies interbedded with coal seams. As marine transgression expanded during the deposition of the Chouniugou Formation, the marine domain of the South Qilian area connected with the Beishan Trough, resulting in sedimentary differentiation between barrier-lagoon and open-coast deposits within this region. In the Late Carboniferous (deposition stage of the Jingyuan to Taiyuan Formations), transgression peaked; the marine area extended northward to Jiayuguan and eastward to connect with the North China Sea. Sediment thickness in the Helan Aulacogen changed sharply due to fault movement. This area was dominated by littoral-neritic tidal flat deposits with extensively developed coal seams, and detrital materials were still sourced from the Dunhuang–Alashan and Longxi oldlands. The entire evolutionary process was marked by tectonic control on basin development, multi-directional marine transgression, and persistent terrigenous sediment supply.

The exploration level of the Bogda Mountain front belt is relatively low, and the research on hydrocarbon accumulation is limited, resulting in unclear sources of discovered oil. To further investigate the geochemical characteristics and sources of crude oil in the Bogda Mountain front belt, this study conducted geochemical experimental analysis and oil–source correlations on crude oil and hydrocarbon source rock samples from the Permian Lucaogou Formation in the Yongfeng sub-sag and surrounding areas of the Bogda Mountain front belt. By using gas chromatography–mass spectrometry technology, the geochemical characteristics of saturated hydrocarbons and aromatic compounds were analyzed. Combined with stable carbon isotopes of saturated hydrocarbons and aromatic hydrocarbons, the organic matter source, maturity, and sedimentary environment were determined. The research results indicate that the crude oil from Well Xyd 1 exhibits mature characteristics, and the source material was deposited in a reducing to weakly oxidizing, weakly reducing environment. The source rocks of the Lucaogou Formation in Well Xyd 1 were formed in a reducing, semi-saline–saline sedimentary environment, while those from the Gjg and Dhs outcrops developed in a weakly oxidizing–weakly reducing, non-high-salinity, weakly stratified sedimentary environment. Carbon isotope, terpane, and isoalkane characteristics confirm a significant genetic relationship between the crude oil from Well Xyd 1 and the local Luzhaogou Formation source rocks. The source rocks of the Luzhaogou Formation in the Yongfeng sub-sag exhibit strong heterogeneity, with significant differences in sedimentary environments and parent materials in their spatial distribution. Maturity analysis indicates that the Luzhaogou Formation source rocks in Well Xyd 1 have reached a mature stage, whereas those from the Gjg and Dhs outcrops are at a relatively low maturity level.

The oil and gas exploration of the Middle and Lower Cambrian in the Tarim Basin reveals widely distributed source rocks with the Yuertusi Formation being recognized as high-quality source rocks that are distributed in a rather small range. The Xiaoerbulake Formation that is right under the Yuertusi Formation has also been eyed as potential high-quality source rocks and is studied through analyses focusing on the stratigraphic development, the abundance, type, and maturity of organic matter, and the paleoproductivity of a dark-colored algae dolomite within the formation. The results show that the dolomite is rich in organic matter of mainly types I and II kerogens. Although reached the high mature to over-mature stage, the dolomite was deposited in an anoxic sedimentary environment featuring a high paleoproductivity level and a high organic carbon burial efficiency, quite favorable for the development of high-quality source rocks. The study provides material evidence to the Middle-Lower Cambrian subsalt source rock-reservoir-caprock combination model for the Tarim Basin.

Introduction to Global Tectonic Systems, pp. 117-145 (2024) No AccessChapter 5: N-N-E-Trending Tectonic SystemsYuzhu Kang, Shuwen Xing, Zhihong Kang, Yue Zhao, Zhihu Ling, Zhijiang Kang, and Huijun LiYuzhu KangSinopec Petroleum Exploration and Production Research Institute, China Petrochemical Corporation, Beijing, China, Shuwen XingInstitute of Geomechanics, Chinese Academy of Geological Sciences, Beijing, China, Zhihong KangChina University of Geosciences (Beijing), Beijing, China, Yue ZhaoInstitute of Geomechanics, Chinese Academy of Geological Sciences, Beijing, China, Zhihu LingInstitute of Geomechanics, Chinese Academy of Geological Sciences, Beijing, China, Zhijiang KangSinopec Petroleum Exploration and Production Research Institute, Beijing, China, and Huijun LiInstitute of Geomechanics, Chinese Academy of Geological Sciences, Beijing, Chinahttps://doi.org/10.1142/9789811285561_0005Cited by:0 (Source: Crossref) PreviousNext AboutSectionsPDF/EPUB ToolsAdd to favoritesDownload CitationsTrack CitationsRecommend to Library ShareShare onFacebookTwitterLinked InRedditEmail Abstract: In this chapter, N-N-E-trending tectonic systems are introduced, including those in China, New Zealand–Tonga, the Eastern United States and the east coast of South America. Keywords: Tectonic systemN-N-E-trendingType FiguresReferencesRelatedDetails Recommended Introduction to Global Tectonic SystemsMetrics History KeywordsTectonic systemN-N-E-trendingTypePDF download

By systematically analyzing the natural gas composition, carbon isotopes, and source rock characteristics in the Yongfeng sub-sag of the Bogda Mountain front belt, natural gas characteristics were determined, and the genetic types and sources of natural gas were investigated. The research results indicate that methane is the main component of natural gas in the Yongfeng sub-sag, with low levels of heavy hydrocarbons and a high drying coefficient. These characteristics make it dry gas, which refers to natural gas with a methane content of over 95%. The ethane carbon isotope δ13C2 of natural gas is −28.5‰ and belongs to oil type gas. The methane carbon isotope δ13C1 of natural gas is −58.6‰~−59.4‰, has a relatively depleted methane carbon isotope value, shows significant differences from the surrounding natural gas methane carbon isotope, and belongs to the category of biogenic gas. The Permian Lucaogou Formation is the main source rock in the study area, with good organic matter abundance. The microscopic components of kerogen are mainly composed of sapropelic formations and the organic matter type is I–II1. The source rock has a high maturity and has reached the mature stage, mainly consisting of oil and wet gas. The ethane carbon isotope of natural gas in the Yongfeng sub-sag shows as oil type gas, which is consistent with the kerogen type of the Lucaogou Formation source rocks, indicating that the natural gas mainly comes from the Lucaogou Formation source rocks. Based on comprehensive data and information on natural gas composition, carbon isotopes, and burial history of the source rocks, it is believed that some of the crude oil generated from the Lucaogou Formation in the early stage underwent biodegradation due to tectonic uplift, resulting in biogenic methane and the formation of crude oil biodegraded gas.

The Nadanhada terrane is considered to accrete to the eastern end of the Jiamusi Block during the Pacific Plate subduction. Constraints on the deep structure of the Nadanhada terrane and Jiamusi Block are essential to study the evolution, transformation and current activity of the eastern Asian continental margin. To reconstruct the accretion processes, two magnetotelluric sounding sections and a seismic reflection section were conducted in the eastern part of Jiamusi Block, the middle, and the southern end of the Nadanhada terrane respectively. Geophysical data revealed resistant stable structures and west-dipping discontinuous reflections with a thickness of around 15 km in the upper crust of Jiamusi Block. In contrast, the lower crust of the Jiamusi block exhibited high conductivity and short sub-horizontal reflections that suggest upwelling of mantle material under Pacific Plate subduction. Moreover, the low resistivity zone observed connecting the shallow crust with the upper mantle in the Tongjiang-Yuejinshan fault was interpreted as the boundary line between the Jiamusi block and Nadanhada terrane. The Nadanhada terrane can be subdivided into the Yuejinshan and Raohe complexes based on their distinct geophysical features. The Yuejinshan Complex is characterized by irregular bodies with high resistivity and short arc reflections with a thickness of about 10 km. In contrast, the Raohe Complex displays high-resistivity blocks and west-dipping thrust nappe strong reflections with a thickness of about 5 km. Additionally, the high-conductivity layer located between the Raohe Complex and the underlying basement is believed to be the detachment zone. Since the Cretaceous, the continuous subduction of the Pacific Plate has caused magmatism that has led to the high conductivity crust. The observation of low-resistivity channels and arcuate reflections within the crust supports the notion of upwelling of mantle-derived materials brought about by the subduction of the Pacific Plate in the Cenozoic era.

松辽盆地常规油气勘探开发已进入中后期,后续接替资源不足,油气勘查亟需向外围新区、新层系、新类型拓展.通过实施三维高精度重磁电勘探、油气参数井钻探工程,结合高精度锆石206Pb/238U测年、有机地球化学测试、XRD矿物组分测定、核磁物性分析等手段,对松辽盆地外围东部双阳盆地非常规油气地质条件进行了综合调查研究.结果表明:双阳盆地发育石炭二叠系—白垩系完整的地层层序,共划分9套物性组合,存在2套具有低密度、低电阻率和低磁化的碎屑岩沉积地层,经钻探验证,在松辽盆地外围双阳盆地发现2套暗色页岩层系,根据地层综合地比和锆石年龄测定,2套页岩地层时代分别为下白垩系长安组和三叠系大酱缸组.其中,长安组页岩有机质丰度高,TOC含量平均1.63％,热解参数计算生烃潜力S1+S2平均值为1.21 mg/g,有机质以Ⅱ1,Ⅱ2型干酪根为主,热演化程度Ro处于0.55％～0.95％,中-低热演化程度,核磁有效孔隙度平均值为4.5％,脆性矿物石英+长石+碳酸盐矿物的含量均值为59％,具有较好的储集性和可压性,是有利的致密油、页岩油富集层系;大酱缸组页岩有机质丰度中等,TOC含量平均1.52％,生烃潜力S1+S2平均值为0.35 mg/g,有机质以Ⅱ2,Ⅲ型干酪根为主,Ro处于1.59％～2.64％,高成熟-过成熟演化阶段,核磁有效孔隙度平均值为3.3％,脆性矿物含量均值为56％,是有利的煤层气、页岩气富集层系.根据岩性组合及油气富集基本特征初步分析,上述2套有利页岩层系的形成,与火山活动有着密切的关系,松辽外围东部发育的39个沉积盆地同样具有火山活动期断陷湖盆沉积特征,推测具备非常规油气形成富集的物质基础和地质条件,指示松辽外围东部盆地群具有非常规油气勘查远景.

"十三五"期间,公益性油气调查立足支撑国家能源安全保障工作定位,针对新区、新层系、新类型、新领域开展基础地质调查和战略选区评价,相继在长江经济带页岩气、松辽盆地陆相页岩油气、北方新区新层系油气,以及煤层气等非常规油气地质调查领域取得了突破性成果,解决了一批油气基础地质问题和工程技术难题.初步构建起长江经济带页岩气勘探开发新格局,有力推动了松辽盆地陆相页岩油气勘探开发进程.优选的勘查区块有效支撑国家油气勘查开采体制改革,助推形成了多处油气页岩气资源基地."十四五"时期,油气地质调查需要依靠科技创新和信息化两大引擎,突出大型盆地整体结构调查和综合评价,聚焦非常规、深层油气,优选优质勘查区块,着力支撑油气勘查开采体制改革与矿产资源管理改革,推动构建公益性与商业性油气勘探有效衔接新机制,服务油气资源产业高质量发展.

松辽外围东部盆地群位于中国东北地区的东部,研究区内共有39个中小规模沉积盆地,总面积约52×104 km2.在总结东部盆地群烃源岩沉积特征的基础上,通过对三江、勃利、通化及红庙子等盆地下白垩统烃源岩有机地球化学综合分析,查明了研究区下白垩统主力烃源岩有机质丰度、有机质成熟度以及有机质类型等指标特征、分布规律,并分析了影响这些指标在区域上规律变化的地质因素,以提升研究区的油气基础地质认识,为东北地区油气资源调查与勘探部署提供科学依据.

东北亚陆缘增生造山过程深受古太平洋板块的俯冲作用影响,饶河杂岩作为古太平洋板块俯冲中央造山带东端的直接证据,分析研究其构造特征对于研究东北亚地区的构造演化具有重要意义.地球物理探测是研究地下岩性变化和深部结构的重要方法,本文布设了一条大地电磁剖面和同测线的人工反射地震,大地电磁测深方法采集点距500 m,频率范围为320 Hz～1000 s,对时间序列数据进行时频转换,预处理后进行二维非线性共轭梯度反演,得到最终的电性模型.人工地震采用爆破震源,满覆盖180次,记录6 s,采用CGG等软件对地震数据进行处理,叠加偏移后获得最终的地震剖面.电性模型显示饶河杂岩体具有不连续高阻体的特征,且西部的高阻体以西倾为主,中东部高阻体呈块状,东部的高阻体不规则,高阻体下存在低阻带,深部有高导体存在.在地震剖面上,饶河杂岩可以分为五个区域,其中西部为西倾的反射体,中部为斜交短反射体,东部上部为强弱不均的短反射体,东部下部为弱反射体,深部为长短不一的杂乱反射体.通过本次的地球物理观测和处理工作,饶河杂岩体可分为两部,浅部具有高阻体、西倾反射体的特征,深部为高导体、杂乱不均一反射体.上下层之间存在分界面,具有低阻带、较为连续的强反射轴的特征.

1 研究目的(Objective) 从1995年塔中11井取得工业油流后,历经数年勘探,塔里木盆地志留系大致呈"东部产气、中部产油、西部未突破"的整体面貌.研究区位于塔里木盆地西北部柯坪断隆东段沙井子构造带,属矿权空白和油气勘查新区,地震、地质和钻井等资料较少,勘探程度较低.新苏地1井钻探和地层测试的主要目的是评价落实该区石油地质条件、力争获得油气突破.相关研究对于探索塔西北志留系含油气性、评价资源潜力和填补油气勘探空白意义重大.

在我国油气资源对外依存度不断攀升,能源安全形势日益严峻的背景下,油气调查评价和勘探开发仍是能源工作的重中之重.近年来,公益性油气调查工作聚焦自身优势,积极服务于国家能源安全,支撑油气资源管理与矿权体制改革成效显著,在油气勘探的新区、新层、新类型方面不断取得突破性成果.公益性油气调查在新疆塔里木盆地西北部温宿凸起新近系、沙井子构造带志留系,准噶尔盆地南缘的二叠系和三叠系均获得了工业油(气)流;在南方鄂西宜昌、黔北武陵山等复杂构造区的页岩气、松辽盆地的页岩油、四川盆地南部煤层气等资源的勘探均取得了重大突破,这些成果有力带动了能源企业的积极投入与勘探,有效彰显了公益性油气地质调查的引领和示范作用.深层油气资源的安全勘探、油气矿权空白区的基础地质调查及非常规油气的调查与勘探将是我国未来油气勘探重要的接替领域.公益性油气调查将以油气基础地质问题为抓手,积极探索油气勘探接替领域,为油气资源规划和管理做好支撑,力争为国家能源安全保障与重大发展战略做出更大的贡献.

东北地区是中国重要的石油天然气生产基地,多年来一直是国内主力油气供应区,但随着松辽盆地油气勘探难度逐渐增大,勘探与开发成本增高,目前亟需新的油气接替区为油气上产和可持续发展提供接替领域和资源保障.松辽盆地外围东部发育39个沉积盆地,规模大小不一,油气勘探潜力较大,已成为东北地区油气勘探的重要领域之一.笔者对松辽外围东部地区的石油地质概况和油气勘探现状进行了分析总结,结合近年来油气基础地质调查工作的进展,提出了东北东部地区油气调查新方向,包括吉林东部地区白垩系页岩油气勘探、三江盆地浅层中新生界生物气勘探、三江地区早中生界海相硅质岩勘探、三江地区上古生界油气勘探,为未来东北东部地区油气资源调查与勘探的部署提供了科学依据.

近年来,中国老油田开发逐渐进入中后期,油气对外依存度也持续增高,亟需寻找新的油气区接替.三江盆地位于中国东北黑龙江省东部,是松辽盆地外围东部面积最大的盆地,迄今暂未取得油气勘探突破.笔者通过对三江盆地开展野外地质调查和钻井勘探,分析总结了该区早中生代沉积的大架山组含硅质岩层系的岩性与分布特征,认为这套早中生代硅质岩与暗色泥岩地层在盆地东部广泛发育并且厚度较大,并且相关测试结果表明其中的暗色泥岩有机质丰度可达0.95％,有机质类型以Ⅱ1型为主,处于高成熟阶段,具有良好的生烃潜力,有望成为三江盆地油气勘探新层系,值得进一步开展油气勘探工作.

1. Objectives The research and prospecting degree of these Mesozoic residual faulted basins located in Tonghua and its peripheral areas, such as Tonghua basin, Liuhe basin and Hongmiaozi basin is low. And these basins are considered to be unified sedimentary basins during the Mesozoic（Fig. 1）.

On the basis of reprocessing 34 new two-dimensional spliced long sections (20,191 km) in the Tarim Basin, the deep structure features of the Tarim Basin were analyzed through interpreting 30,451 km of two-dimensional seismic data and compiling basic maps. Seismic interpretation and geological analysis conclude that the Nanhua-Sinian strata are a set of rift-depression depositional systems according to their tectonic and depositional features. The rift valley formed in the Nanhua Period, and the transformation became weaker during the late Sinian Period, which eventually turned into depression. From bottom to top, the deposited strata include mafic igneous, tillite, mudstone, and dolomite. Three major depocenters developed inside this basin during the rift stage and are distributed in the eastern Tarim Basin, the Awati area, and the southwestern Tarim Basin. Among them, the rift in the eastern Tarim Basin strikes in the near east-west direction on the plane and coincides with the aeromagnetic anomaly belt. This represents a strong magnetic zone formed by upwelling basic volcanic rock along high, steep normal faults of the Nanhua Period. Controlled by the tectonic background, two types of sedimentary systems were developed in the rift stage and depression stage, showing two types of sequence features in the Sinian depositional stage. The Nanhua System appears as a wedge-shaped formation, with its bottom in unconformable contact with the base. The rifting event has a strong influence on the current tectonic units in the Tarim Basin, and affects the distribution of source rock in the Yuertus Formation and reservoir beds in the Xiaoerbulake Formation in Lower Cambrian, as well as the gypseous cap rock in Middle Cambrian. The distribution features of the rifts have important and realistic significance for determining the direction of oil and gas exploration in the deep strata of the Tarim Basin. Comprehensive analysis suggests that the Tazhong region is the most favorable zone, and the Kalpin-Bachu region is the optimal potential zone for exploring sub-salt oil and gas in deep Cambrian strata.

Pore-cave systems formed by karstification in the eogenetic stage of carbonate rocks provide abundant potential reservoir space for hydrocarbons. However, whether these dissolution pore-caves can become effective reservoir spaces during the later burial period, serving as the key to the success of hydrocarbon exploration. Therefore, it is important to explore the fluid activities and their alteration effects on eogenetic karst reservoirs during the later burial. Focusing on the Cambrian Longwangmiao Formation in the northwestern Sichuan Basin, this study systematically analyzed the formation of reservoir space in the eogenetic stage and the reworking of the system by fluids in the later stages, based on petrology, geochemistry, burial history, and tectonic evolution data. Results showed that many millimeters to several centimeters scale of pores and caves in the Longwangmiao Formation were produced by eogenetic karstification. These pore-caves underwent by two episodes of dolomite infilling in the shallow burial stage (D1) and in the Caledonian–Hercynian period (D2). Geochemical parameters indicate that D1 and D2 were both affected by meteoric water. In the early shallow burial stage, the dolomitic fluid was enriched in a relatively closed, reducing environment, whereas in the later stage, the fluid was affected by a relatively open oxidizing environment due to Caledonian–Hercynian fractures. Both D1 and D2 took place before the massive hydrocarbon migration from the Cambrian source rocks in the Middle Permian to those of the Middle Triassic. After the formation of the dissolution pore-caves, the precipitation from two episodes of dolomitic fluids led to the degradation of the Longwangmiao Formation carbonate reservoir space in the northwestern Sichuan Basin. In the southern part of the Shatan section-Well MS1, closed to the paleo-uplift of the central Sichuan Basin, where eogenetic karstification was superimposed by Caledonian–Hercynian supergene karstification, may be form effective reservoir and is a significant prospect for exploration.

The Sichuan Basin is one of the vital basins in China, boasting abundant hydrocarbon reservoirs. To clarify the intensity of the tectonic stress field of different tectonic episodes since the Mesozoic and to identify the regional dynamic background of different tectonic movements in the Sichuan Basin and its adjacent areas, the characteristics of the acoustic emission in rocks in different strata of these areas were researched in this paper. Meanwhile, the tectonic stress magnitude in these areas since the Mesozoic was restored. The laws state that the tectonic stress varied with depth was revealed, followed by the discussion of the influence of structural stress intensity on structural patterns in different tectonic episodes. These were conducted based on the paleostress measurement by acoustic emission method and the inversion principle of the stress fields in ancient periods and the present, as well as previous research achievements. The results of this paper demonstrate that the third episode of Yanshanian Movement (Yanshanian III) had the maximum activity intensity and tremendously influenced the structural pattern in the study area. The maximum horizontal principal stress of Yanshanian III varied with depth as follows: 0.0168 x + 37.001 (MPa), R2 = 0.8891. The regional structural fractures were mainly formed in Yanshanian III in Xujiahe Formation, west Sichuan Basin, of which the maximum paleoprincipal stress ranging from 85.1 MPa to 120.1 MPa. In addition, the law stating the present maximum horizontal principal stress varies with depth was determined to be 0.0159 x+10.221 (MPa), R2=0.7868 in Wuling Mountain area. Meanwhile, it was determined to be 0.0221 x+9.4733 (MPa), R2=0.9121 in the western part of Xuefeng Mountain area and 0.0174 x+10.247 (MPa), R2=0.8064 in the whole study area. These research results will not only provide data for the simulation of stress field, the evaluation of deformation degree, and the prediction of structural fractures, but also offer absolute geological scientific bases for the elevation of favorable shale gas preservation.