莺-琼盆地海相烃源岩特征及高温高压环境有机质热演化

莺歌海盆地与琼东南盆地存在渐新统海岸平原-半封闭浅海相和中新统浅海相两套海相烃源岩。其中,渐新统烃源岩发育于琼东南盆地早第三纪半地堑,存在海岸平原和半封闭浅海两类烃源岩组合。海岸平原含煤烃源岩有机质丰度高,富含陆源有机质,具有很好的生气潜力;半封闭浅海相烃源岩TOC含量总体低于1.0%,但其规模大且存在TOC1.5%的较高丰度段,故亦具有较大的生气能力。中新统海相烃源岩主要分布于莺歌海盆地裂后热沉降形成的中央坳陷,其有机质丰度横向变化比较大,位于中央坳陷带的烃源岩有机质丰度较高,TOC大多在0.40%～2.97%之间,有机质以气型干酪根为主。盆地的高地温为有机质向天然气转化提供了有利的条件,尤其是热流体活动使浅层有机质超前熟化,但地层超压对有机质热演化也有一定的抑制作用。盆地模拟结果显示,莺-琼盆地主要凹陷烃源岩大量生气时间较晚,与圈闭形成期的时空配置好,有利于成藏。     

Microfacies and depositional environment of Late Cretaceous to Early Paleocene oil shales from Jordan

The purpose of this study is to better understand the depositional setting of Late Cretaceous to Early Paleocene oil shales from southeast and central-east Jordan. One core from both the Jafr and the Azraq-Hamza Basins was logged, and their lithology, texture, and ichnofabrics were recorded. A total of 79 thin sections were analyzed petrographically, and eight microfacies types recognized. Both cores show lithologic and petrographic similarities. The oil shales are Maastrichtian to Danian in age and can be described as organic matter and calcite-rich mudrocks. The most abundant granular components are foraminifera and various types of phosphatic bio- and lithoclasts. Macrofossils (bivalves, ostracods, echinoderms) were recorded in some intervals. The current results were compared with data from a previous publication on Maastrichtian oil shales from the Jafr Basin. A new model explaining the deposition of the oil shales of the Jafr and Azraq-Hamza Basins is proposed. The onset of the Maastrichtian oil shale deposition in both basins coincides with the early Maastrichtian transgression in this region. The organic matter-rich sediments were deposited in a mid to outer ramp setting below the storm wave base. Younger oil shales of Late Maastrichtian to Danian age were deposited in a shallower environment, below the fair weather wave base. The Cretaceous/Paleogene boundary is marked by a hiatus in both cores. The Danian oil shales show relatively lower “total organic carbon” content than the Maastrichtian ones. The former are believed to have been deposited in more oxygenated bottom waters of a mid-ramp zone.     

陕北油页岩地质特征、成矿规律及开发条件

陕北油页岩主要分布于鄂尔多斯盆地的三叠系延长组和侏罗系安定组、延安组地层中,其中三叠系延长组的长7、长9、长1是油页岩发育的主要层段。地层总体为一产状平缓的向北西西微倾的单斜构造,地表绝大部分被第四系现代风积沙覆盖。油页岩矿石多呈灰黑色片状,主要成分为硬质粘土类矿物,含少量石英、长石细屑及沥青质点。油页岩分布受基底差异运动形成的构造坳陷盆地控制。成矿受岩相古地理环境控制,深湖一半深湖相沉积环境形成的油页岩分布广泛,品质好,浅湖和三角洲相沉积环境形成的油页岩分布范围小、厚度小、含油率低。鄂尔多斯盆地不仅油页岩资源丰富,而且开发条件优越,具有广阔的开发利用前景,对解决我国油气等常规能源供需矛盾突出的问题非常有利。     

New palaeontological investigations in the Jurassic of western Thailand

The paleontological investigations of the Jurassic of Western Thailand, districts of Mae Sot (Tak–Mae Sot highway, Padaeng Tak and Ban Mae Kut Luang Zinc mines) and Umphang (Klo Tho), provide age constraints for the Late Indosinian orogeny, the Paleotethys closure and the timing of the marine Jurassic inundation of Sundaland. The basal conglomerate of the Jurassic is derived from the pelagic Triassic Mae Sariang substratum. Stratigraphy, microfacies and paleontology of the Jurassic marine strata focus especially on ammonites, bivalves, large benthic foraminifera and algae. Among ammonites, the Tethyan Catulloceras perisphinctoides Gemmellaro marks the Upper Toarcian (Aalensis Zone) along the Tak–Mae Sot highway and Riccardiceras longalvum (Vacek), Malladaites pertinax (Vacek), Abbasites sp. and Vacekia sp. indicate Middle Aalenian to lowermost Bajocian in the Padaeng Mine (SE of Mae Sot) and Klo–Tho (Umphang). Vacekia sp., Spinammatoceras schindewolfi Linares and Sandoval and Malladaites vaceki Linares and Sandoval indicate Middle Aalenian to lowermost Upper Aalenian at Ban Mae Kut Luang (NE of Mae Sot). Among foraminifers, the large benthic foraminifer Timidonella sarda Bassoullet, Chabrier and Fourcade in the Western Tethys is indicative for Aalenian–Bajocian times, as characterized in the section at the Tak–Padaeng Zinc mine and the Klo–Tho Formation near Umphang. The endemic foraminifer Gutnicella kaempferi characterizes the Pu Khloe Khi Formation near Umphang. Among bivalves, shallow marine, dominantly endemic fauna includes Parvamussium donaiense (Mansuy) and Bositra ornate (Quenstedt), from the Toarcian to the Early Bajocian. A consideration of the faunal affinity shows that the fauna is partly endemic with Northern Tethyan (Eurasian) affinity.     

Petroleum Geological Conditions in Qiangtang Basin

PETROLEUM GEOLOGICAL CONDITIONS IN QIANGTANG BASIN     

吉林东部中、新生代盆地非常规油气资源及潜力分析

通过对吉林东部中、新生代区域构造、盆地地质、沉积背景的综合研究,详细阐述了吉林东部中、新生代盆地非常规油气的类型、分布及其地质特征,认为研究区非常规油气的主要类型为油页岩和煤层气,具有一定的页岩气资源潜力。油页岩主要分布在辉桦盆地、罗子沟盆地、松江盆地、延吉盆地和敦化盆地等盆地中,主要层位为下白垩统大拉子组和古近系桦甸组,主要沉积环境为半深湖-- 深湖环境。煤层气的分布范围较广,主要层位为早、中侏罗世地层和古近纪梅河组、珲春组,集中在珲春盆地、敦化盆地、双阳盆地等煤层较厚、埋藏较浅的盆地中。伊通盆地具有页岩气潜力。     

典型盆地煤与油页岩共生成矿物质及古气候分析

选取煤与油页岩共生典型盆地山东黄县盆地、辽宁抚顺盆地、黑龙江依兰盆地和内蒙古金宝屯盆地,综合分析了其成矿物质特点,认为共生背景下煤岩中的低等动植物和油页岩中的高等植物均比单一矿种下含量高。这一规律可用于勘探、开发煤或油页岩单一矿种时预测其共生矿种存在的可能性。对古气候的分析表明,气候变换在一定程度上制约着煤与油页岩的共生模式,这种共生模式可为古气候研究提供一定依据,反之,通过古气候的变迁也可帮助勘探、开发共生背景下的煤与油页岩。     

The effect of organic matter type and organic carbon content on Rock-Eval hydrogen index in oil shales and source rocks

The amount of “gas-prone” kerogen (woody, fungal and “inert”) and the organic carbon content (TOC) are the two predominant factors affecting the hydrogen index (HI) in the 226 samples of lacustrine and marine oil shales and source rocks studied. HI decreases as a function of the amount of “gas-prone” kerogen and increases as a function of TOC. In addition, the type of amorphous kerogen influences the hydrogen index, and this can be roughly estimated from the fluorescence intensity of the amorphous kerogen. Nearly eighty percent of the variation in HI in these samples can be accounted for by the percentage of “gas-prone” kerogen, the TOC content, and the fluorescence of the amorphous kerogen in a multiple regression analysis.Hydrogen index increases as a function of TOC up to about 10% TOC (the relationship can be approximated by a quadratic equation) and then levels off. A possible explanation for this is that the capability of a rock to generate and expel hydrocarbons during pyrolysis increases with TOC. When the retention capacity of the rock matrix is saturated (at about 10% TOC) further increases in TOC have no effect on HI. It is also possible that the quality (i.e. oil-proneness) of the amorphous kerogen is poorer in low TOC samples than in high TOC samples.The samples came from the following oil shales and source rocks: Rundle (Queensland Eocene-Miocene), Mae Sot (northwestern Thailand, Eocene-Pliocene), River River (northwestern Colorado, Eocene), Toolebuc (western Queensland, Late Albian), the “Posidonienschiefer” (southwestern Germany, Toarcian), an Argentinian lacustrine deposit (Eocene-Miocene), the Kimmeridgian sections from four North Sea wells (blocks 21, 30, and 210), Monterey Shale (California, Miocene), and sections from six wells from the Alaskan Tertiary (North Slope, North Aleutian Shelf, Navarin Basin, Norton Sound). Most samples appear to be thermally immature (T.A.I. less than 1.8; R_o less than 0.6%) so they should be considered only potential source rocks.The lacustrine oil shales have a higher conversion ratio (yeild/TOC or S₁ + S₂/TOC) than do the marine oil shales in samples with only amorphous and algal kerogen. These, in turn, have a higher conversion ratio than the marine source rocks. These differences are roughly reflected in the fluorescence intensity of the amorphous kerogen. Free hydrocarbons are higher in the marine source rocks than in the marine oil shales, and are lowest in the lacustrine oil shales.     

焉耆盆地侏罗纪煤系源岩显微组分组合与生油潜力

焉耆盆地为我国西部含煤、含油气盆地, 侏罗系含煤地层是最重要的潜在源岩.对侏罗纪煤系中的暗色泥岩、碳质泥岩和煤层分别进行了有机岩石学、Rock-Eval热解分析和核磁共振分析.泥岩、碳质泥岩和煤层具有不同的有机岩石学和有机地球化学特征, 其中煤层具有3种有机显微组分组合类型, 不同显微组分组合类型的煤层具有不同的生油、生气潜力或倾油、倾气性.基质镜质体、角质体、孢子体等显微组分是煤中的主要生烃组分.侏罗系泥岩、碳质泥岩和煤层具有不同的生物标志物分布特征, 生物标志物组合分析表明焉耆盆地已发现原油是泥岩、碳质泥岩和煤层生成原油的混合产物.含煤地层的地球化学生烃潜力分析和已发现原油的油源对比均表明, 含煤地层不仅是重要的气源岩, 而且可成为有效的油源岩.      

陕西铜川—黄陵地区油页岩地质特征及利用前景

位于鄂尔多斯盆地东南部的陕西铜川、宜君和黄陵一带赋存着丰富的油页岩资源。主要的含油页岩层位是中—晚三叠世延长组下段上部,具体形成时间为中三叠世晚期。野外观察发现,油页岩露头主要分布于铜川—宜君—黄陵一带,主矿层厚度一般为2~36 m。测得含油率为1.8%~13.7%,发热量为1.66~11.45 M J/kg,推测干酪根类型为I-II1,产烃率为400 kg/t,中等偏好,页岩油(相当于原油)资源量约100×108t,储量近亿吨。宏观和微观资料表明,该区油页岩是在淡水、近岸、强还原、富含有机质的沉积环境下形成的,属于大型内陆湖盆的半深—深湖相,埋藏浅,储量较大,交通条件好,如果在适当时机开发,不仅可获得初步经济效益,也可为鄂尔多斯油页岩的开发利用获取开拓性的经验。该区油页岩矿位于西部最大城市西安市附近,开发利用的意义重大。     

Brunei Darussalam: Characteristics of selected petroleums and source rocks

The development of three Tertiary deltaic complexes has resulted in the deposition of up to 10 km of sandstones and shales comprising the sources and reservoirs for crude oils that occur onshore, near-offshore and, with future exploration efforts, those likely to be encountered in deepwater reservoirs north of the Brunei coastline. We examined a series of offshore oils and onshore rock samples in Brunei Darussalam (a) to delineate oil family groups and their source rock characteristics, and (b) to assess the source potential of the sedimentary sequence with respect to lithology and depositional setting. Twelve offshore oils and 53 shales, coaly shales and coals were examined. The oils contain indicators of allochthonous (e.g. bicadinanes, oleananes) and autochthonous (e.g. cholestanes and methylcholestanes) components in the source organic matter. Predictable geographic variations of this mixed input are clearly evident in the sample set (e.g. allochthonous input appears to increase in offshore Brunei to the northeast). Although this molecular source signature is relatively clear, migration of these oils from deep (and unidentified) source rocks has resulted in extensive migration-contamination with respect to the tetracyclic and pentacyclic hydrocarbons. This contamination has resulted in strong correlations between certain molecular maturity indicators and the present-day temperature of the reservoirs. Liquid hydrocarbon source rock potential is present in the tidal and coastal embayment facies, and is greatest in the Miocene coals. Neither the shales nor coaly shales contain significant oil generative potential. The thermal immaturity of the sample set precludes valid oil–source rock correlations without conducting artificial maturation experiments on the coals.     

Exploration prospects of oil and gas in the Northwestern part of the Offshore Indus Basin,Pakistan

Oil and gas resources are short in Pakistan and no commercially viable oil and gas sources have been yet discovered in its offshore areas up to now. In this study, the onshore-offshore stratigraphic correlation and seismic data interpretation were conducted to determine the oil and gas resource potential in the Offshore Indus Basin, Pakistan. Based on the comprehensive analysis of the results and previous data, it is considered that the Cretaceous may widely exist and three sets of source rocks may be developed in the Offshore Indus Basin. The presence of Miocene mudstones has been proven by drilling to be high-quality source rocks, while the Cretaceous and Paleocene–Eocene mudstones are potential source rocks. Tectonic-lithologic traps are developed in the northwestern part of the basin affected by the strike-slip faults along Murray Ridge. Furthermore, the Cretaceous and Paleocene–Eocene source rocks are thick and are slightly affected by volcanic activities. Therefore, it can be inferred that the northwestern part of Offshore Indus Basin enjoys good prospects of oil and gas resources.     

Organic petrology and source rock potential of sediments in the Eromanga Basin, South Australia

Cuttings and cores from the Poolowanna 1 well, Eromanga Basin, South Australia (in which oil was discovered in Lower Jurassic reservoirs) and the Macumba 1 well (no oil) have been analyzed petrographically to assess the nature of the coals and dispersed organic matter present. The Jurassic and Cretaceous coals have medium to high vitrinite contents, low to relatively high exinite, and medium to low inertinite contents. The dispersed organic matter has comparatively less vitrinite, more exinite and/or more inertinite than the associated coals. The microlithotype compositions of the coals indicate that the original vegetation was largely woody in character and was buried before much oxidation had occurred.The Jurassic sediments contain up to 2% dispersed organic matter by volume, 0–75% of which is exinite, including alginite. Vitrinite reflectances range from 0.5 to 0.7%. Where sufficiently mature, the Jurassic sediments are good potential source rocks for hydrocarbons.Statistical testing of the analytical results for the Jurassic Poolowanna Formation using Kendall's τ as a measure of dependence shows that there is a significant association between the macerals in coal and dispersed organic matter. The ratio of exinite to inertinite in dispersed organic matter is reasonably well predicted by the corresponding ratio in the associated coal.     

Organic geochemical evaluation of the oil/gas-generative potential of organic matter in Cretaceous strata from the Lower Benue Trough,Nigeria

An analytical procedure involving Rock-Eval pyrolysis of whole-rocks was adopted on fresh outcrop samples covering the three lithostratigraphic units in the Afikpo Basin of the Lower Benue Trough. Three petroleum systems are present in the Cretaceous delta frame: the Asu-River Group, the Eze-Aku Group and proto-Niger Delta sequences. The Afikpo Basin has been correlated to three petroleum systems in the Lower Congo Basin, Niger Delta and the Anambra Basin. The organic geochemistry of the shales, carbonaceous mudstones and coal beds show relatively moderate to high total organic carbon contents. The best potential hydrocarbon source rocks are the Eze-Aku Group and proto-Niger Delta shales, carbonaceous mudstones and coal beds where maturation was attained. The high total or-ganic contents, thermal maturity and terrigenous characters of the Asu-River Group, Eze-Aku Group and proto-Niger Delta sediments, suggest the presence of a large amount of natural gas with a small quantity of oil accumulation. Variations in source rock facies were observed from one lithostratigraphic unit to another, and initial HI values as a function of TOC were proposed for each lithostratigraphic unit. The results also show that TOC, HI, OI, S2 and Tmax vary from older to younger rocks. The Tmax values discriminate the rocks into immature and mature source rocks. Source rocks with high Tmax suggest high geothermal gradient/or recycled organic matter. Also high Tmax and S2 yield indicate late and post maturity. Recycled organic matter is characterized by low Tmax. The principal source rocks for gas in the Afikpo Basin are the Eze-Aku Group and proto-Niger Delta beds deltaic systems, consisting mainly of III to IV kerogens with a subordinate amount of type II organic matter. Based on the obtained results, it is concluded that the Cretaceous shales, carbonaceous mudstones and coals in the Afikpo Basin of the Lower Benue Trough are capable of generating and expelling hydrocarbons in the case of sufficient maturity.     

Rare Earth Elements in Coal-Bearing Deposits: Distribution Features and Geochemical Significance

The examination of Lower Cretaceous coals and clayey fractions of terrigenous host rocks of the Zyryanka Basin has revealed a generally negative type of the relative REE distribution (with a predominance of LREE over HREE) and a similar behavior of Th and U. Analogous characteristics are typical for metamorphic and igneous rocks of intermediate composition dominating in the provenance. In terms of the concentration and distribution of REE, Th, and U coal-bearing terrigenous rocks of the Zyryanka Basin are close to Phanerozoic clays and silty sandstones of the Russian Platform, while coals of the Zyryanka Basin are similar to metal-free coals of various basins (Kizel, Pennsylvanian, and others). Average REE and Th contents in the studied coals are five times lower than those in host terrigenous rocks. The coals differ from these rocks by relatively elevated HREE concentrations largely due to adsorption mechanism of the HREE accumulation. Data obtained on the REE, Th, and U distribution in coals and clayey fractions of host rocks are of fundamental significance for the comparitive analysis of the behavior of these elements in metal-bearing coals of various basins.     

罗子沟盆地大砬子组油页岩有机地球化学特征及其地质意义

通过对罗子沟盆地大砬子组上段油页岩干酪根镜检、热解、GC 和GC-MS 等分析,并对其有机地球化学多项特征参数进行研究,讨论罗子沟油页岩有机地化特征及其地质意义。根据姥植比及伽马蜡烷、孕甾烷、重排甾烷、重排藿烷等参数特征分析,推测油页岩形成的古湖泊水体性质为淡水--微咸水的还原沉积环境。综合分析显微组分镜检和热解结果及甾烷( C27--C29 ) 分布等参数,认为研究区油页岩有机质主要为混合母源输入。依据热解、Ro、甾烷和C31 升藿烷异构化程度、C29 莫烷/C29 藿烷、 Ts 与Tm 相对含量比值等指标的对比,指出研究区油页岩处于未熟－ 低熟热演化阶段。     

中国南方晚震旦世沉积相及磷块岩的时空分布

本文扼要阐述扬子地台及邻区晚震旦世地层的研究现状,沉积相带(台地相、斜坡相及盆地相)及古地理轮廓、磷块岩的时空分布(包括地理、地层及沉积相的分布)。同时还着重指出了台地边缘及斜坡相带的上部是寻找磷块岩的有利地区。     

西藏伦坡拉盆地丁青湖组油页岩特征及勘探有利区评价

西藏伦坡拉盆地出露大规模的油页岩。通过研究油页岩的剖面、探槽、钻井及相关实验数据,根据油页岩厚度、分布范围及沉积相特征,结合油页岩品质特征,对蒋日阿错、伦坡日及爬爬3个油页岩分布区进行了评价。研究表明,伦坡拉油页岩总体为高灰分(平均81.76%)、中高含油率(平均7.2%)、特低含硫量(小于1%)型油页岩,其有机碳含量高(平均8.07%),产烃潜量较大,可作为烃源岩为伦坡拉盆地的油藏提供油源。油页岩厚度受沉积相带控制,主要呈北西-南东向断续分布于盆地半深湖-深湖相区。油页岩平均含油率、有机碳含量总体呈北西部低、南东部较高的趋势。综合油页岩厚度及油页岩展布范围,爬爬地区油页岩具有厚度较大、东西向展布最广、平均含油率及有机碳含量高的特征,是最有利的油页岩勘探区,伦坡日、蒋日阿错地区则次之。     

Organic Geochemical and Petrographic Characteristics of the Coal Measure Source Rocks of Pinghu Formation in the Xihu Sag of the East China Sea Shelf Basin: Implications for Coal Measure Gas Potential

Coal measure source rocks, located in the Xihu Sag of the East China Sea Shelf Basin, were analyzed to define the hydrocarbon generation potential, organic geochemistry/petrology characteristics, and coal preservation conditions. The Pinghu source rocks in the Xihu Sag are mainly gas-prone accompany with condensate oil generation. The coals and shales of the Pinghu Formation are classified from "fair" to "excellent" source rocks with total organic carbon(TOC) contents ranging from 25.2% to 77.2% and 1.29% to 20.9%, respectively. The coals are richer in TOC and S1+S2 than the shales, indicating that the coals have more generation potential per unit mass. Moreover, the kerogen type of the organic matter consists of types Ⅱ-Ⅲ and Ⅲ, which the maturity Ro ranges from 0.59% to 0.83%. Petrographically, the coals and shales are dominated by vitrinite macerals(69.1%–96.8%) with minor proportions of liptinite(2.5%–17.55%) and inertinite(0.2%–6.2%). The correlation between maceral composition and S1+S2 indicates that the main contributor to the generation potential is vitrinite. Therefore, the coals and shales of the Pinghu Formation has good hydrocarbon generation potential, which provided a good foundation for coal measure gas accumulation. Furthermore, coal facies models indicates that the Pinghu coal was deposited in limno-telmatic environment under high water levels, with low tree density(mainly herbaceous) and with low-moderate nutrient supply. Fluctuating water levels and intermittent flooding during the deposition of peat resulted in the inter-layering of coal, shale and sandstone, which potentially providing favorable preservation conditions for coal measure gas.     

The Distribution of Petroleum Resources and Characteristics of Main Petroliferous Basins along the Silk Road Economic Belt and the 21st-Century Maritime Silk Road

The Silk Road Economic Belt and the 21st-Century Maritime Silk Road Initiative, abbreviated as the Belt and Road Initiative, is a primary development strategy of China’s future international cooperation. Especially, the energy resource cooperation, including oil and gas resources cooperation, is an important part of this initiative. The Belt and Road has undergone complicated geological evolution, and contains abundant mineral resources such as oil, gas, coal, uranium, iron, copper, gold and manganese ore resources. Among these, Africa holds 7.8% of the world’s total proven oil reserves. The oil and gas resources in Africa are relatively concentrated, with an overall low exploration degree and small consumption demand. Nigeria and Libya contain the most abundant oil resources in Africa, accounting for 2.2% and 2.9% of the world’s total reserves, respectively. Nigeria and Algeria hold the richest natural gas resources in Africa, occupying 2.8% and 2.4% of the world’s total reserves, respectively. Africa’s oil and gas resources are mainly concentrated in Egypt, Sultan and Western Sahara regions in the northern Africa, and the Gulf of Guinea, Niger River and Congo River area in the western Africa. The Russia–Central Asia area holds rich petroleum resources in Russia, Kazakhstan, Turkmenistan and Uzbekistan. The potential oil and gas areas include the West Siberia Basin, East Siberia Basin and sea continental shelf in Russia, the northern and central Caspian Basin in Kazakhstan, the right bank of the Amu-Darya Basin, the East Karakum uplift and the South Caspian Basin in Turkmenistan, and the Amu–Daria Basin, Fergana Basin, Afghan–Tajik Basin and North Ustyurt Basin in Uzbekistan. The Middle East oil and gas resources are mainly distributed in the Zagros foreland basin and Arabian continental margin basin, and the main oil-producing countries include Saudi Arabia, Iran and Iraq. The Asia Pacific region is a new oil and gas consumption center, with rapid growth of oil and gas demand. In 2012, this region consumed about 33.6% of the world’s total oil consumption and 18.9% of the world’s total natural gas consumption, which has been ranked the world’s largest oil and gas consumption center. The oil and gas resources are concentrated in China, Indosinian, Malaysia, Australia and India. The abundant European proven crude oil reserves are in Norway, Britain and Denmark and also rich natural gas resources in Norway, Holland and Britain. Norway and Britain contain about 77.5% of European proven oil reserves, which accounts for only 0.9% of the world’s proven reserves. The Europe includes main petroliferous basins of the Voring Basin, Anglo–Dutch Basin, Northwest German Basin, Northeast German–Polish Basin and Carpathian Basin. According to the analysis of source rocks, reservoir rocks, cap rocks and traps for the main petroliferous basins, the potential oil and gas prospecting targets in the Belt and Road are mainly the Zagros Basin and Arabic Platform in the Middle East, the East Barents Sea Basin and the East Siberia Basin in Russia–Central Asia, the Niger Delta Basin, East African rift system and the Australia Northwest Shelf. With the development of oil and gas theory and exploration technology, unconventional petroleum resources will play an increasingly important role in oil and gas industry.