The Late Jurassic Penglaizhen Formation encompasses shoal water deltaic sedimentary system in the middle part of western Sichuan depression, which was deposited under a tectonic-stable, gently-gradient and shoal water environment. Along with high-frequently fluctuated base level, the sandbodies were regularly distributed along the lake shoreline. Using an integrated approach of core, outcrop,and drilling log data, we analyzed the sedimentary environment and proposed the mechanism of shifting lake shoreline controlling shoal water deltaic sandbodies distribution in the study area. The results show that:1 In the high stand base level stable period, re-constructed by the wave, the first complex bar was formed along the shoreline, in the low stand base level stable period, the second complex bar was formed along the relatively regressed shoreline, both complex bars were reserved at the end of lake regressive system tract; 2 Within the shoal water deltaic sedimentary system, the fluvial controlled sandbodies are thick, while the shoreline controlled sandbodies are thin; 3 Four water lines were defined, dividing the study area into five depositional districts, two shoal water deltaic sedimentary models in tectonic stable basin were set up; 4 The lake shoreline dominated sandbodies were interpreted to be significant reservoir except for fluvial dominated sandbodies, which will be the main targets in the future exploration.

This article consists of two parts.In the first part,factors affecting the saturation carrying capacity of particles and the average bed density are discussed.Based on test data from several commercial FCC units,a new correlation of the saturation carrying capacity is recommended and a new equation of average bed density is suggested.In the second part,various factors affecting the catalytic conversion of feed stocks are reviewed.Based on extensive experimental data,a new correlation has been proposed by which the change of performance of a FCC plant from existing operating conditions and feedstock composition to different conditions and/or feedstock composition can be predicted.

Sedimentary fabric analysis shows that middle member Ⅲ of Shahejie Formation (S ₃ ^m) is mainly composed of normal deltafront sediments in this study areas. Magnetic anisotropy measurements were carried out on samples from rotary drilling cores, and the results were used to calculate the direction of paleo-current oriented by magnetic polarity. The distribution of paleo-current, coinciding with the prograding direction of the Dongying Delta from the southeast to northwest, distinctly manifests that in the study areas, X, Y and Z blocks in Dongying depression are directly controlled by Dongying Delta during the sedimentary epoch of S ₃ ^m. The comprehensive analysis on the source and the sedimentary characteristics proves that area of Dongying Delta should be expanded. Thus, there will be widening area in the Dongying Delta inferred to be further prospect of lithological oil pool exploration. The method shown in this paper could be a new way to analyze the paleocurrent in paleo-limnological delta and will provide new scientific data to serve the petroleum exploration.

Coalbed methane(CBM) resource of high rank coal is the current largest CBM production in China which is accounting for 21.2% of the total resources. The study of production controlling mechanism and mode of high rank coal reservoirs is important for improving the success rate of optimization of CBM favorable region. The study showed that the tectonic and hydrodynamic are the two main controlling factors on the CBM accumulation. Degree of micro-fracture development, geo-stress and dredging of fluid of coal reservoir were three key controlling elements for CBM production. Based on this, the development index of micro-fracture, gas production controlling index of geo-stress and the dredging index of fluid were defined. Three categories with 12 CBM production modes were constructed, and the main control factors on CBM production were characterized in detail. The solid reservoir and the interaction effects with formation fluids were quantitative characterized through the dredging index of fluid. The integration controlling of the three principle stress on CBM production was also raised and break through the conventional single stress magnitude or direction(burial depth effect) control mode. Compared with the practice data of CBM development, we found that the predict gas production model fit well with actual production, which verified that the CBM controlling mechanism, the evaluation method of effect and the production controlling mode were reliable.

Tarim Basin is taken as an example to address the controls of structures and tectonics over hydrocarbon in the poly-history superimposed basins. Tarim Basin is a large composite and superimposed sedimentary basin developed upon Presinian continental basement and has undergone such three mega-cycles of extension and compression as Sinian to Middle Devonian,Late Devonian to Triassic,and Jurassic to Quaternary. The control effects of structures and tectonics on hydrocarbon in Tarim Basin include six fields: 1The proto-type basins developed during the three periods of extension have yielded three series of excellent source rocks; 2The key periods of geotectonic transformation led to three effective phases of pool formation; 3The superimposed interfaces between proto-type basins resulted in new plays; 4The superimposition of poly-history basins showed different kinds of pool formation; 5The neotectonic movement had given rise to a characterization of pool-formation in the latest geohistory on a large scale; 6The superimposed geologic framework controlled oil and gas distribution showing a character in sequential and hiberarchy.

Troughs in faulted basins are generally taken as a province of hydrocarbon generation and expulsion instead of accumulation. Therefore, troughs are frequently neglected in the exploration focusing on the search of hydrocarbon reservoirs provided that they have been verified to be of hydrocarbon generation and expulsion capacity. Based on the practical exploration in Paleogene of Jizhong Depression and Cretaceous of Erlian Basin for years, this paper puts forward a new concept on the hydrocarbon accumulation in troughs of faulted depressions, which includs the following findings. In troughs of faulted basins, the sandbody distribution is controlled by multiple factors, lithologic accumulations are more readily to form than structural accumulations, three factors control the formation of large hydrocarbon accumulations, and structural and stratigraphic-lithological reservoirs are not only co-exist but also complement each other. Moreover, the novel concept also indicated that in troughs, fan-delta front in a flank part of an inverted structural belt, delta front on the break of a gentle slope, a sublacustrine fan and a channel sandbody along toes of faults are favorable locations for hydrocarbon accumulations in stratigraphic-lithologic traps. With the application of this concept, hundreds of million tons of oil reserves have been discovered in trough areas of the Huabei Oilfield.

The Marsel exploration area is located within the Chu-Sarysu Basin in Kazakhstan. It covers an area of 1.85×10⁴km² and mainly develops sedimentary formations of the Devonian, Carboniferous, and Permian. Previous exploration by the former Soviet Union took 35 years and discovered gas reserves of 137×10⁸m³. Later, the Canadian Condor Company explored this area for 5 years and discovered gas reserves of 60×10⁸m³. More recently, the Chinese Zhongke Huakang Oil Company obtained the exploration right and authorized research teams from the China University of Petroleum (Beijing) and China University of Geosciences (Beijing) to investigate the Marsel area over a period of 3 years. This study elucidated the characteristics of strata distribution, structure evolution, reservoir-caprock assemblages, and hydrocarbon migration and accumulation in Marsel based on the genetic model of superimposed continuous hydrocarbon reservoirs and combined with re-analysis and interpretation of the existing data. A continuous gas-bearing area larger than 2 500 km² was predicted in the exploratory area. Additionally, this study analyzed the drilling data from 77 exploration wells, re-interpreted gas-bearing layers using well logging data, specifically processed and tracked the gas-bearing property of target layers with seismic data, and further compared the occurrence of gas layers with superimposed continuous gas reservoirs elsewhere, domestically and overseas. The South Kazakhstan gas field was discovered in the exploration area, and its gas-bearing boundary and range as well as the effective thickness of gas layers were identified. According to the international evaluation system of PRMS, the recoverable reserves of natural gas resources in the new gas field can be as large as 18 049×10⁸m³. An international evolution company, GCA, has approved the 3C recoverable reserves of natural gas resources as 5 159×10⁸m³. This gas field is located in Kazakhstan, the hinterland of Central Asia, less than 150 km away from the third gas pipeline built by China. The discovery of this gas field will promote the exploration and development of similar unconventional superimposed oil and gas resources in Central Asia and other places in the world. It will also play a role in boosting the economy of the new Silk Road.

The deep-water gravity flow in the middle submember of Member 3, Shanghejie Formation, Jiyang depression was taken as the research object in this study. Based on the differences in sediment composition structure, concentration, transportation-sedimentation mode and fluid rheological characteristics, a study was carried out on the types, sedimentary characteristics and genetic mechanisms of deep-water gravity flow. In the middle submember of Member 3, Shanghejie Formation, Jiyang depression, deep-water gravity flow was classified into debris flow and turbidity current. The former was primarily divided into muddy debris flow with structural matrix effect and sandy debris flow with composition matrix effect based on the matrix content and structure difference in debris-flow sediments; according to trigger mechanism and sedimentary facies sequence characteristics, the latter was divided into two types, i.e., surge-like turbidity current resulting from sediment slump, and quasi-steady turbidity current (density flow) resulting from flood. The sediments of muddy debris flow were mostly composed of thick-massive matrix-supported conglomerate and clastics-bearing sandy mudstone, where there is abrupt contact with top and bottom surface. The sediments of sandy debris flow also mainly consisted of thick-massive sandstones and gravel-bearing sandstones, showing abrupt contact with top and bottom surface and reverse graded bed sequence. Moreover, mudstone tearing clastics and floating boulder clays were mostly developed at the middle and top of sedimentary facies sequence. The sediments of surge-like turbidity current primarily consisted of medium-fine sandstones and siltstones, where complete or incomplete Bouma sequence was developed with scouring-filling structure. The sediments of quasi-steady turbidity current were dominated by gravel-bearing coarse sandstones, medium-fine sandstones and siltstones, and developed in reversed normal graded bed sequence and normal graded bed sequence. In the inner facies sequence, abrupt contact surface or erosion interface was developed with climbing beddings and carbonaceous laminae. The sediments of deep-water gravity flow caused by slumping were dominated by an assemblage of debris flow and surge-like turbidity current, including partial sliding and slumping associated sediments. The sediments of deep-water gravity flow resulting from flood were dominated by an assemblage of debris flow and quasi-steady turbidity current.

China is just starting the industrial development of shale gas due to its great potential in shale gas resources although domestic researches on the comprehensive assessment, production mechanisms and production technologies of shale gas remain immature. Based on the authors' previous investigation and extensive literature search, this paper gives an overview on advances in the research and development of shale gas both at home and abroad, which discusses the following aspects: (1) the comprehensive assessment of shale-gas resources is the first step in shale-gas exploration and development and the key parameters and factors that determine the potential of shale gas are analysed; (2) production mechanisms of shale gas are fundamental to reservoir modeling, numerical simulation and hydro-fracturing design, and therefore, the complex production mechanisms and flow models are summarized. (3) some key technologies applied to shale-gas development, such as horizontal well and hydraulic fracturing, and the intrinsic correlation between reservoir characteristics and technologies chosen are discussed, which provide a reference basis for production optimization; (4) a review of the development history, characteristics and future development expectation of shale-gas resources in China.

The Changqing Oilfield Company has extensively and efficiently developed reservoirs with ultra-low permeability between 0.3mD and 1mD. Based on the practice of petroleum exploration and development in Ordos Basin, the tight oil herein refers to the oil that accumulates in oil shale or interbedded tight sandstone reservoirs adjacent to source rocks and with surface-air permeability less than 0.3mD. Generally, this accumulated oil has not yet experienced large-scale and long-distance migration, and thus its accumulation includes tight sandstone and tight shale oil reservoirs. The tight oil of Yanchang Formation mainly develops in a semi-deep to deep lake zone, typically in the oil shale and tight sandstone of Chang-7 interval and the tight sandstone of Chang-6 interval of the central lake. Tight oil in Ordos Basin is characterized by a wide distribution, superior conditions of source rocks, tight sandstone reservoirs, complex pore-throat structures, poor physical properties, high oil saturation, better oil properties and low pressure coefficient. Wide development of nano-sized pore-throat systems is one of the fundamental characteristics for the oil and gas continuous accumulation of tight oil reservoirs. Most of the connected pore-throat diameters of tight sandstone reservoirs in Yanchang Formation are greater than the critical pore-throat diameter, gratifying the need of oil and gas to migrate in tight reservoirs. Reservoirs of the tight oil in Yanchang Formation can be divided into 3 different types depending on the contact relationship between tight reservoirs and source rocks, i.e. compact massive sandstone reservoirs, sand-shale interbedded reservoirs and tight reservoirs in oil shale. Tight oil is widely distributed in Chang-6 and Chang-7 intervals of Yanchang Formation in Ordos Basin, and it is preliminarily forecasted that the total resources of tight oil in Ordos Basin are about 30×10⁸t, of which the shale oil resource in Chang-7 interval exceeds 10×10⁸t, while the tight sandstone oil resource in Chang-7 and Chang-6 intervals amounts to about 9×10⁸t and 11×10⁸t, respectively. Therefore, tight oil resources are the realistic oil replacement resources that can ensure Changqing Oilfield to achieve an annual output of 5000×10⁸tons of oil equivalent and a long term stability of oil production.

Nanostructure morphology of shale reservoirs was investigated using a field-emission environmental scanning electron microscope and adsorption-desorption isotherms were measured with low-temperature nitrogen adsorption experiments. Combined with high-pressure mercury injection, further investigation into characterization of pore structures in shale reservoirs was gained. Results show that pores in shale reservoirs are generally in a nanometer grade, it can be classified into five types: organic nanopores, interparticle pores between clay minerals, mineral pores in rock skeletons, apertures in palaeontologic fossils and microfractures, of which the most common ones are organic nanopores and interparticle pores between clay minerals. The pore-size distribution of shales are complex, which includes not only predominant mesopores (2～50nm), but also a certain amount of micropores (<2nm) and macropores (>50nm). Micropores and mesopores with a diameter less than 50nm amount to most of specific surface area and pore volume of shale pores, and mainly are places for gas adsorption and storage. Shale is characterized by high threshold pressure, good-sorting pore throats, poor connectivity and low efficiency of mercury withdrawal. In addition, mesopores in shale apparently contribute a lot to gas percolation, while micropores in shale are mainly for gas storage.

On the basis of the pool-forming theory and conditions for shale gas in the United States,the controlling factors for shale gas accumulation were analyzed and divided into internal and external factors.The internal control factors include the type,content and maturity of organic matters,and the fracture,porosity,permeability,mineral composition,thickness,humidity of shale.The external control factors include reservoir depth,temperature and pressure of formation.Among them,the type,content and maturity of organic matters,as well as the fracture,porosity and permeability of shale are the main factors for generating shale gas reservoir.The favorable areas for developing shale gas reservoirs were predicted by using parameter model.The analogical analysis based on the model suggests that the Cambrian system and the Silurian system are the most favorable strata for developing of shale gas reservoirs among the marine Paleozoic strata in South China.The most favorable areas of the Cambrian are located in Sichuan Basin,the Micangshan-Dabashan foreland,the northern Guizhou Province,West Hunan Province,East Chongqing and the north part of Jiangnan uplift.The most favorable areas of the Silurian are located in Sichuan Basin,the Micangshan-Dabashan foreland and East Chongqing,West Hubei Province of Upper-Yangtze River,North Hubei Province of Middle-Yangtze River and South Jiangsu Province of Lower-Yangtze River.The indexes of shale in the favorable areas were analyzed to provide reference for early evaluation of shale gas in China.

The fracability of shalegas reservoir rocks was evaluated according to three rock mechanics paramete which including brittleness, fracture toughness and mechanical property. Based on the elasticity modulus and Poisson’s ratio scopes, a brittleness index prediction model was specially designed for the Lower Silurian Longmaxi Formation shale in the Sichuan Basin. Calculation methods for the mode I and II fracture toughness were established through lab experiments and logging data. A method to evaluate the fracability index was preliminarily developed by employing the elasticity modulus(E), Poisson's ratio(μ) and uniaxial tensile strength(S_t) as independent variables, and the fracability index(F_rac) as a dependent variable. A 3D chart of the fracability index was compiled to assess the difficult degree of multi-stage hydraulic fracturing of gas-shale reservoirs, from which one can see that when the elasticity modulus increases and the Poisson’s ratio and uniaxial tensile strength decrease accordingly, the fracability index will definitely increase to indicate the hydraulic fracturing of a reservoir is easier. Therefore, when the whole rock mechanics parameters of a reservoir are available, the fracability index at any part of the reservoir can be calculated according to the seismic logging and vertical seismic profile(VSP) data with lab calibration, moreover, a 3D fracability distribution of shale-gas reservoirs can be achieved as well.

A series of major breakthroughs have been achieved in global deepwater oil and gas exploration since 2010, which has been the most important replaced field of conventional oil and gas discovery. The breakthroughs in new basin groups and the rediscoveries in the early discovered basin groups point out two significant exploration directions. There have been new significant discoveries of oil and gas in four deepwater basins since 2010, including Guyana Basin on the eastern continental margin of Central America, Rovuma Basin and Tanzania Basin in the deepwater area of East African continental margin, the eastern Mediterranean of the Tethys Basin Group and the deepwater area of the continental margin of eastern Canada. From 2011 to 2016, it has been confirmed that nine basin groups in global deepwaters have achieved new great oil and gas exploration discoveries, including the mid-northern deepwaters of West African continental margin, the Great Campos Basin in Brazil, the deepwater area of Gulf of Mexico Basin, the deepwaters of western continental margin of Norway and North West Shelf of Australia, the deepwaters of the South China Sea, Southeast Asia and the Bay of Bengal, and circumpolar deepwater basin group. These discoveries prove that the hydrocarbon-rich basin has the paleo-environment for the formation of high-quality source rocks with high organic matter abundance and favorable reservoirs with good properties and high productivity. The successful breakthrough in new basin is to bravely explore new areas and restricted areas. The experience gained from constant discoveries in mature basins is to break through new horizons, especially the pre-salt reservoirs. It can be seen that global deepwater hydrocarbon is always the main field of future world conventional oil and gas exploration.

Comprehensively based on the aeromagnetic, seismic, geological and geochemical data, this paper studies the surficial structures, deposition, distribution characteristics and the deep-seated dynamical mechanism for the north-south differentiation of Neoproterozoic rift basin of Tarim Basin, and reveals the evolutionary characteristics of the rift basin and its controlling effect on the distribution of the early Cambrian sedimentary basin and the deep hydrocarbon source rocks. The southern rift basin of Tarim is the product of superplume activity occurred in the early break-up period of Rodinia Supercontinent, starting from the early Nanhua period (about 780 Ma)and shown as the NE-trending aulacogens that extended deeply inside of Tarim basin. The northern rift belongs to the back-arc rift basin derived from the subduction of Pan-Rodinia oceanic slab, starting from the late Nanhua period (about 740 Ma)and shown as the nearly EW-trending narrow band zone traversing the whole Tarim basin. The formation and evolution process of the Neoproterozoic back-arc rift basin, northern Tarim is quite similar to that of the late Mesozoic-Cenozoic back-arc rift basins in East Asia, both showing the evolutionary characteristics of oceanward migration. Nevertheless, the Tarim rift basin was finally evolved from the early fault depression-sag into the passive continental margin. The Neoproterozoic rift basin of Tarim controlled not only the distribution of syn-rifting hydrocarbon source rocks, but also the development of early Cambrian sedimentary basin, which made the latter similar to the rift basin. Thus, hydrocarbon source rocks in the nearly EW-trending Nanhua-Sinian syn-rift period and the post-rifting period of Lower Cambrian Yuertusi Formation are likely developed between the north Tarim uplift and the central uplift belt.

It is an inevitable trend for oil and gas industry to transform exploration & development domain from conventional hydrocarbon accumulations to unconventional hydrocarbon ones, which are obviously different in types, geological features and genesis. Conventional petroleum focuses on accumulation mechanism, and the key answer is whether the trap contains petroleum, otherwise, unconventional petroleum focuses on the reservoir space, and the key answer is how much the reservoirs capture petroleum. Unconventional hydrocarbon resources are mainly characterized by continuous distribution and no natural oil and gas production from per well. Currently, unconventional problems occur in the exploration and development of conventional hydrocarbon resources, thus it is necessary to transform unconventional hydrocarbon resources into new “conventional” hydrocarbon resources. With technology development, unconventional hydrocarbons can be transformed into conventional ones. Generally, conventional hydrocarbon deposits consist of structural and litho-stratigraphic hydrocarbon reservoirs, where oil and gas are distributed in an isolated structure or a larger structure group with clear trap boundaries and pore-throat systems in millimeter-micrometer scale. Oil and gas in this case accumulate by buoyancy to form hydrocarbon pools. However, unconventional hydrocarbon accumulations, including tight sandstone oil and gas, tight carbonate oil and gas, shale oil and gas, coal-bed methane, oil shale, oil sand, hydrate, etc., are distributed continuously or quasi-continuously in basin's slopes or centers. Commonly, they are characterized by source-reservoir paragenesis and have no distinct trap boundaries. Pore-throat systems in nanometer scale are well-developed in unconventional reservoir rocks, and related hydrocarbons are mainly detained in situ or migrate for a short distance into reservoirs that are close to source rocks because buoyancy is limited. The present paper systematically analyzed geological characteristics and exploration potential of tight hydrocarbons in some typical basins of China, where pores in nanometer scale with partial micrometer-millimeter pores dominate the reservoir space of unconventional hydrocarbons, the diameter of reservoir pores is 5~200 nm in gas shale, 40~500 nm in tight oil limestone, 50~900 nm in tight oil sandstone and 40~700 nm in tight gas sand. In terms of the rapid development of globe petroleum industry and nano-technology, a concept of nano-hydrocarbons is proposed in this paper that indicates that “nano-hydrocarbon” is the development direction of oil and gas industry in the future, urgently requiring developing vicarious technologies, such as nano-hydrocarbon perspective viewing mirror, nano-hydrocarbon displacement agent and nano-hydrocarbon exploitation robots. Petroleum intellectualization times will come in following.

The tight oil refers to an oil that accumulates in source rocks in a free or adsorbed state or in tight sandstones and carbonates interbedded with or adjacent to source rocks. Generally, this oil accumulation has not yet experienced a large-scale, long-distance migration. Based on the clarity of the tight oil concept and connotation, we proposed ten key indices to evaluate the tight oil. Tight oil reservoirs can be generally divided into 3 different types based on porosity and permeability, while the tight oil itself can be also classified into 3 types depending on the genetic relationship of a close contact between tight reservoirs and source rocks, i.e. ①tight oil in lacustrine carbonate rocks; ②tight oil in deep-lake gravity flow sandstones and ③tight oil in deep-lake delta sandstones. The tight oil is widely distributed in China, currently, a number of important exploration discoveries of the tight oil have been achieved in the Triassic Chang-6 and Chang-7 sections of Yanchang Formation in the Ordos Basin, the Permian Lucaogou Formation in the Junggar Basin, the Middle-Lower Jurassic of the Sichuan Basin and the Cretaceous Qingshankou-Quantou Formation of the Songliao Basin. To expect the tight oil prospect in China, we preliminary forecast that the tight oil geological resources in China are about (106.7~111.5 ) ×10⁸ t. Combined with the analysis of future prospects of petroleum development, we can come to a conclusion that the tight oil in China should be a realistic replacement resource of the conventional oil.

The consumption and production of conventional energy set a new record high in 2012, oil and gas are still the mainstays in energy consumption structure, while the drastic increase in unconventional oil and gas production make a near balance between demand and supply of oil and gas. However, a lot of basic theoretical questions about unconventional oil and gas are still waiting to be answered, and little is known about the accumulation pattern and exploration -development features of unconventional oil and gas. The paper reviews the recent situation of oil and gas exploration across the world, and points out four key theoretical questions in unconventional oil and gas geology: (1) deeper understanding on "oil and gas system": "whole accumulation" mode of "whole oil and gas system" for petroliferous basins was proposed, the unconventional oil and gas accumulation mechanisms were analyzed by quantifying the generation, expulsion, migration, and accumulation; (2) fine grain sediments and tight facies sedimentology: by dissecting fine grain deposition and unconventional oil and gas generation, the integration points of three studies were put forward; (3) micro-to nano-pore system and fluid behavior in shale and tight reservoirs: five aspects of micro-to nano-pore system that should be focused in unconventional oil and gas study were proposed, and development features of micro-to nano-pores and fluid behavior in micro-to nano-pores were dissected; (4) unconventional oil and gas accumulation pattern and resource evaluation: starting from the features of unconventional oil and gas accumulation, the evaluation system for unconventional oil and gas resources were set up.

LiuPan Shui,one of the most important coal-bed methane areas,is located in the central part of the Upper Yantze coal-bearing of the Late Permian in the Western Guizhou-Eastern Yunnan and Southern Sichuan regions.Coal and coal-bed methane accumulated in many synclinoria of the region.The geological characteristics study of the Liupan Shui coal-bed methane indicated the wide distribution of coalbeds with large thickness in the synclinoria or basins,high vitrinite amount in the anthropological composition,moderate coalification degree,high gas content in coal-bed,fractures well developed in coal bed situated in the regional magnetic-metamorphic belt,very good seality of caprock trapped in the confined ground water area with high pressure of coal-bed.Pan Xian Basin and Gemu,Langdai,Liuzhi, Bulang and Qingshan synclines have good geological conditions for coal-bed methane formation and enrichment.Coal-bed methane resource are estimated to be from 7,500 to 9,130×10m.

Non-tropical carbonate is a significant component of carbonate sedimentology. Combined with latest carbonate research achievements, this paper focuses on the connotation of non-tropical carbonate realm with surface marine water temperature <20℃, which could be divided to warm-temperate realm (15-20℃), temperate-cool water realm (5-15℃) and polar cold water realm (<5℃). The biota types in non-tropical carbonate are mainly heterozoan association, which is different from the phtozoan association in tropical carbonate. The non-tropical carbonate has very low accumulation rate. The accumulation rate of cool-water carbonate is no more than 1m/ka, mostly only some centimeters per millennium. Because of the lack of reef-building organisms, there is reef deficiency in non-tropical carbonate, mainly are ramp with no barrier and open shelf. Lack of lime mud supporting, it is grain-supporting structure in non-tropical carbonate. There is little Mg-calcite or aragonite cementation in early stage diagenesis of non-tropical carbonate. Because the cementation is mainly in deep burial environments, the non-tropical carbonate system with abundant carbonate bioclasts accumulation can preserve plenty of high-quality intra-grain pores and inter-grain pores, which might be the new field of future petroleum exploration. The appearance of the concept non-tropical carbonate has significant influence on lithofacies paleogeography analysis. If the modern non-tropical carbonate study, paleontological material and paleo-ocean water study were applied into the ancient carbonate study, the present paleo-latitude division might be greatly changed.