10 April 2019, Volume 30 Issue 4
    

  • Select all
    |
  • Evolution of Carboniferous source rocks and hydrocarbon accumulation process in the area of the Wucaiwan area in Junggar Basin
    Wang Wei-feng, Zhang Zhong-da
    Natural Gas Geoscience. 2019, 30(4): 447-455. https://doi.org/10.11764/j.issn.1672-1926.2019.01.006
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    The Carboniferous source rocks in Wucaiwan area of Junggar Basin have good hydrocarbon generation potential.They are now at the mature-high mature stage and have generated a large number of hydrocarbons.The hydrocarbon generation process since Permian has an important impact on the hydrocarbon accumulation of the Carboniferous System.This paper evaluates the basic characteristics of Carboniferous source rocks in this area，restores the evolution history，carries out the analysis of hydrocarbon accumulation conditions，and then studies the hydrocarbon accumulation process.The results show that the Carboniferous source rocks in Wucaiwan area have the conditions of large-scale hydrocarbon generation，and have undergone several important hydrocarbon generation periods.Carboniferous has undergone multi-stage reservoir formation，i.e.，the end of Permian，the end of Triassic，Late Jurassic and the end of Cretaceous.Among them，the first three are early hydrocarbon accumulation.Because of the Late Jurassic-Early Cretaceous tectonic activity，the oil and gas pools formed in the early stage were completely destroyed and lost.The Late Cretaceous is the last hydrocarbon generation peak of the Carboniferous source rocks in this area，and a large number of mature-high mature oil and gas pools were accumulated in the internal reservoirs of the Carboniferous to form the present oil and gas pools.
  • Hydrocarbon charging history of the lower petroleum system in the southern Junggar Basin: Case study of the Qigu Oil Field
    Hu Han-wen, Zhang Yuan-yuan, Zhuo Qin-gong, Jia Cheng-zao, Guo Zhao-jie
    Natural Gas Geoscience. 2019, 30(4): 456-467. https://doi.org/10.11764/j.issn.1672-1926.2019.03.003
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    The Permian-Jurassic petroleum system in the southern Junggar Basin is important and potential.However，divergence still exists in the hydrocarbon accumulation history in this area.Integrated methods，such as organic geochemistry，granular fluorescence technology，fluid inclusion analysis and basin modeling，were used to discuss the hydrocarbon charging history of the lower petroleum system in the Qigu Oil Field.The results show that the crude oil has the characteristics of gas washing like the heavy density and much wax.Hydrocarbon displays differential fluorescent properties in different formations and in the two sides of faults.The low-maturity oil charged the Lower Jurassic reservoirs at ~100Ma before it charged the Middle Jurassic reservoirs at ~45Ma.The high-maturity oil charged the Lower Jurassic-Middle Jurassic Xishanyao Formation reservoirs at ~7Ma.During the tectonic activities in the Late Cenozoic，the paleo oil reservoirs were adjusted and the gas washed the Permian-Jurassic reservoirs.Multiple stages of hydrocarbon charging resulted in the complex distributions of oil and gas.Gas and most oil escaped from shallow Middle Jurassic Xishanyao Formation reservoirs because of the absent Lower Cretaceous regional seal rocks and faults up to the ground.Fortunately，the Permian-Lower Jurassic petroleum reservoirs remained under the protection of the Lower-Middle Jurassic sealing beds.
  • The characteristics and their controlling factors on reservoir in Permian Lower Urho Formation in Mahu Sag，Junggar Basin
    Fu Shuang, Pang Lei, Xu Xue-long, Cao Yuan-ting, Liu Zhen-yu, Zhang Shun-cun,
    Natural Gas Geoscience. 2019, 30(4): 468-477. https://doi.org/10.11764/j.issn.1672-1926.2019.01.015
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    The Permian Lower Uhro Formation is an important strata for petroleum exploration and shows good prospects in Mahu Sag，which is the highest degree in accumulation of petroleum in Juggar Basin.In order to support and offer reference for further exploration and exploitation，based on core observation，thin section，scanning electron microscopy (SEM)，mercury injection experiment，CT scanning，as well as mathematics statistics，the characteristics and controlling factors of Lower Urho Formation have been discussed.The results indicate that the reservoir of Lower Urho Formation has especially low porosity and low permeability with multiple types of rocks，which have a high content of volcanic materials and low maturity.The variety of pores with thin throats are dominated by residual intergranular pores，microcracks，intragranular dissolved pores，and reservoir heterogeneity is strong.Influencing factors on physical properties of reservoirs are sedimentation，diagenesis and tectonism.Sedimentation plays a significant role in reservoir controlling factors，and reservoirs with good physical properties are mainly developed in under-water distributary channel and upper-water distributary channel with strong hydrodynamics and less argillaceous content.Compaction is the main destructive diagenesis and cementation is the second.The compaction caused 70% primary pores to disappeare.Dissolution is the constructive diagenesis.Secondary pores formed by dissolution improve physical property，and the secondary pore zone is mainly developed in under-water distributary channel and upper-water distributary channel.Microfractures produced by tectonic activities enhance the heterogeneity of reservoir and improve effectively physical property of reservoir.
  • Influences of the deep fluid on organic matter during the hydrocarbon generation and evolution process
    Liu Jia-yi, Liu Quan-you, Zhu Dong-ya, Meng Qing-qiang, Huang Xiao-wei
    Natural Gas Geoscience. 2019, 30(4): 478-492. https://doi.org/10.11764/j.issn.1672-1926.2019.01.001
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    As the formation and development of organic-inorganic interaction，people came to realize the important role of inorganic matter during the process of organic matter maturation and hydrocarbon generation.Deep fluids act as a carrier of inner earth substances，and it carried massive inorganic matter from deep earth.The injection of deep fluids provide sedimentary basin with hydrogen sources and catalyst，which would promote the maturation and evolution of organic matters with basins.By providing essential carbon sources for inorganic reaction，deep fluids also took a part in inorganic hydrocarbon generation reaction.This paper collects recent achievements about organic matter hydrogenation reaction and inorganic hydrocarbon generation reaction such as F-T synthesis.By giving a detailed analysis of the effect extraneous hydrogen sources and catalyst exerted on organic maturation and hydrocarbon-producing process，this paper confirms the “increasing hydrocarbon yield” effect of deep fluid.
  • Research status and its significance to oilfield development of stylolite in carbonate
    Li Chang-hai, Zhao Lun, Li Wei-qiang, Li Jian-xin, Ding Yu-tao, Li Ang, Qi Yong-ping
    Natural Gas Geoscience. 2019, 30(4): 493-502. https://doi.org/10.11764/j.issn.1672-1926.2018.12.003
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Stylolite is a common geological structure in carbonate formations and has attracted more and more scholars to study its impacts on oil and gas development.This paper summarized the classification，cause，development，distribution and petrophysical characteristics of stylolite.The results show that the categorization scheme of stylolite based on connection is better than other categorization schemes，and it becomes a hot spot in recent years.The mechanism，the cause of zigzag and the formation period of the stylolite are still controversial.The solution seams can not only form fracture networks in three-dimensional space，but also have the potential to improve underground oil and gas seepage.The study of the solution seams is of great significance for limestone reservoirs，thus it is our focus for further research.
  • Relationship between elastic mechanical properties and equivalent  fracture pressure of coal reservoir near wellbore
    Chen Li-chao, Wang Sheng-wei,
    Natural Gas Geoscience. 2019, 30(4): 503-511. https://doi.org/10.11764/j.issn.1672-1926.2018.12.004
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    The elastic mechanical property of rock is a mechanical constraint for the fracture initiation in hydraulic fracturing.51 coalbed methane wells in Zhengzhuang blocks of Qinshui Basin are taken as the object in this paper，the parameters of elasticity mechanics (Young’s modulus E，shear modulus G，bulk modulus K，Poisson’s ratio v) of No.3 coal near wellbore were calculated based on the acoustic，density logging data，and meanwhile the values of equivalent fracture pressure (Pt) which represent energy consumption were figured out.Based on regression，two patterns of relationship between the elastic mechanical parameters (E，G，K) and Pt were proposed.In soft coal with medium and low modulus，there is a positive correlation between them，for high-modulus hard coal，Pt is low when the coal develops natural fracture and Pt increases with the decrease of parameters (E，G，K) with the blockage effect of coal fines，whereas Pt increases rapidly with the increase of parameters (E，G，K) when the coal is stiffness.The relationship between v and Pt in coal is inversely related to above.Pt increases rapidly with the increase of v in high modulus hard coal，while in medium and low modulus soft coal Pt increases with the decrease of  v firstly by the extrusion effect of pore water in coal，and then it is positively correlated with v.
  • Microscopic characteristics of shale gas reservoirs in middle and southern coal measures of Hedong Coalfield，Shanxi Province
    Xie Wei-dong, Wang Meng, Dai Xu-guang, Wang Yan-di
    Natural Gas Geoscience. 2019, 30(4): 512-525. https://doi.org/10.11764/j.issn.1672-1926.2018.11.003
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    In order to further study the microscopic characteristics of the coal-bearing shale reservoirs in the middle south of Hedong Coalfield，discussion was carried out on the characteristics and influencing factors of reservoir pore structure parameters.In this paper，scanning electron microscopy and argon ion polishing technology were used to describe the characteristics of various reservoirs directly.The pore size distribution，pore volume and specific surface area of the samples were measured by high pressure mercury intrusion and low temperature liquid nitrogen adsorption experiments.The results show that there are four kinds of pores in shale:Organic matter pore，intergranular pore，intragranular pore and micro fissure.The pore size is mainly distributed in the nanometer scale，micropores and mesoporse are dominant，and the pore volume and specific surface area are mainly contributed by micropores and mesopores.The results of single factor analysis and SPSS multi factor analysis showed that the growth of pore volume and specific surface area positively correlated with clay mineral content，TOC and RO，and negatively correlated with the content of brittle minerals.In clay minerals and brittle minerals，the content of illite，chlorite，interlayer and plagioclase has a positive influence，while the content of quartz，potassium feldspar and kaolinite is negative.The research results have some theoretical significance for the exploration and development of coal-bearing shale gas resources in the middle and south parts of the Hedong Coalfield，with the study of the microscopic characteristics and influencing factors of the coal-bearing shale reservoirs in the middle-south Xiashihezi Formation Taiyuan Formation.
  • Gas composition and geological significance of headspace gases from the gas hydrate scientific drilling holes in Harhu Depression，southern Qilian Basin
    Fan Dong-wen, Lu Zhen-quan, Liu Hui, Xiao Rui, Wang Wei-chao, Li Yong-hong, Tang Shi-qi
    Natural Gas Geoscience. 2019, 30(4): 526-538. https://doi.org/10.11764/j.issn.1672-1926.2019.01.008
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Through the analysis of the gas components and the methane carbon isotope at different depths in headspace gases from the gas hydrate scientific drilling holes (QH-1 and QH-2) in the Harhu Depression，southern Qilian Basin，the relationship between the components content of hydrocarbon gas and the depth of the holes is compared.The correspondence between the components content of hydrocarbon gas and the lithology，fissure and fracture zones is analyzed.The genesis of hydrocarbon gas is also discussed.The geological significance of hydrocarbon gas to lithology，fissure，fracture zone and gas hydrate anomaly is pointed out.The results show that the high-content interval of the headspace gas has an indicative effect on mudstone，also the gypsum layer in the core is in accord with the high-level air content zone.It is speculated that hydrocarbon gases are trapped in mudstone in the form of adsorption (free)，and the plaster prevents the gas from escaping；Relatively high gas content in the fissure or fracture zone indicates that it has a certain control effect on the accumulation of hydrocarbon gases；Compared with the Muli，although the drilling area reached the gas hydrate stability zone conditions，but because of low hydrocarbon gas concentration，there is no drilling encountered gas hydrate；Methane carbon isotopes suggest that the hydrocarbon gas in headspace gases is genetically mainly composed of thermogenic gas，with some of mixed origin.
  • Estimation of microbial hydrate resources based on hydrocarbon generation material balance method:Case study of deep water area in southwestern Qiongdongnan Basin
    Liu Jie, Yang Rui, Wu Dai-dai, Jin Guang-rong
    Natural Gas Geoscience. 2019, 30(4): 539-548. https://doi.org/10.11764/j.issn.1672-1926.2019.01.005
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    The excellent reservoir forming condition indicates it is a favorable exploration prospect for gas hydrate resources in the deep water area of Qiongdongnan Basin.Based on the data of bottom water temperature，geothermal gradient，organic carbon content and deposition rate，the distribution characteristics of thickness of gas hydrate stable zone are analyzed in the study area.The gas hydrate resources are preliminarily estimated by using the parameterized transfer function obtained from the numerical simulation.The results show that biogenic methane hydrates are distributed in the seabed with a depth of more than 600 m，and the maximum thickness of the stable zone is about 300m.The total abundance of methane hydrate is estimated to be 5.7×1012m3  in the study area.Among them，the prospective total amount of self-sourced diffusion biogenic gas hydrate is about 0.7×1012m3，and the total amount of gas hydrate by way of “lower-generation and upper storage”  is about 5×1012m3.The latter is about 7 times the amount of methane hydrate in situ.Therefore，the supply of hydrocarbon gas from microbial gas hydrates in the study area is dominated by deep hydrocarbon migration，and efficient fluid migration pathway is an important factor to control the accumulation of gas hydrate reservoirs in the study area.The resource estimation method based on hydrocarbon generation idea is consistent with the order of magnitude of natural gas hydrate resource calculated by volume method，which shows the effectiveness of this method.
  • Prediction model of fracture initiation pressure of open hole well considering penetration effect
    Zeng Fan-hui, Tang Bo-tao, Wang Tao, Guo Jian-chun, Xiao Yong-jun, Zhang Shou-ren
    Natural Gas Geoscience. 2019, 30(4): 549-556. https://doi.org/10.11764/j.issn.1672-1926.2019.01.010
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Accurate prediction of fracture initiation pressure is the key process in hydraulic fracturing and acid fracturing.Penetration effect plays an important role in calculating fracture initiation pressures.But at present，percolation，injection rate and liquid viscosity are seldom considered to the prediction models of initiation pressure in fractured wells.Rock is a porous medium，the fracturing fluid will infiltrate into the zone around the wellbore in fracturing，which can make the pressure distribution around the wellbore change and create additional stress interference on fracture initiation pressures in hydraulic fracturing.A prediction model for fracture initiation pressure of open-hole wellbore is established with taking penetration effect into account and combining the theory of rock mechanics，elasticity and seepage mechanics in this context.The incremental boundary iterative method is used to solve the moving boundary problem.The reliability and rationality of the model are verified by comparing with the fracture initiation pressure test and the classical Hubbert model.The influence of penetration effect on the fracture initiation pressure of an open-hole wellbore is analyzed by using the model and the calculation results show that with the increase of rock permeability，injection rate and borehole size，the fracturing fluid is easier to flow into the formation rock，resulting in the increase of pore fluid pressure and the decrease of fracture pressure obviously；with the compressibility of fracturing fluid and fracturing fluid viscosity increases，the fracturing fluid is not easy to infiltrate，and thus infiltration of fracturing fluid has little effect on the fracture initiation pressure.The model established in this paper overcomes the disadvantages that Hubbert model cannot take the effect of penetration on reservoir fracture pressure into account，and explains the mechanism of penetration effect on reducing reservoir fracture initiation pressure effectively.
  • Discussion on development mode of smaller well spacing and tridimensional development in the YS108 block，Zhaotong National Shale Gas Demonstration Area
    Huang Xiao-qing, Wang Jian-jun, Du Yue, Li Lin, Zhang Zhuo
    Natural Gas Geoscience. 2019, 30(4): 557-565. https://doi.org/10.11764/j.issn.1672-1926.2018.12.018
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Shale gas reservoir in mountainous areas of southern Sichuan Province is stable and continuous in plane but highly heterogeneous in vertical，so a reasonable well pattern model is significant for improving the degree of reserve utilization and gas recovery ratio.Therefore，by learning other fields’ experience in producing shale gas，and using the static geological information and dynamic production data，a development mode of smaller well spacing and horizontal well target within staggered bed is established in the  1st member of Longmaxi Formation(L1) of YS108 block in Zhaotong Area，with some analytical means such as unconventional hydro-fracture simulation and numerical simulation:The well spacing is reduced to 300 m，and the target of the horizontal wells should be in the staggered layers which are L111 and L131 horizons，so the well pattern is divided into two parts；In addition，“zipper” fracturing and synchronous production are also the important parts of this development mode.Through researching，the results show that this model can increase 20% reserves utilization，16% gas recovery ratio and 90×106m3 gas production in each single well.However，inter-well interference is the key factor to the application of this model and it can be reduced to less than 2% by synchronous production.
  • Optimization of perforated interval of multilayer commingled  fracturing in coal measure strata
    Sun Wei, Xiong Yuan-gui, Wang Qian, Zhang Tian-xiang, Wang Xiao-hua, Zhen Huai-bin, Zhu Wei-ping
    Natural Gas Geoscience. 2019, 30(4): 566-573. https://doi.org/10.11764/j.issn.1672-1926.2019.01.002
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Based on the 3D fracture model of multilayer hydraulic fracturing，the fracture morphology and conductivity were obtained by MFrac software.The expert-based weighting method was used to consider the strata physical properties and production characteristics in coal measures.Combined with the fuzzy synthetic evaluation method，the optimizing method of perforated interval and perforation length of multiple layers commingled fracturing was proposed.We found that perforation interval determines whether the multilayer combined fracturing of the coal measures can be achieved，and the perforated length decides the quality of the multilayer fracturing effect.Several optimization principles of perforated interval were proposed.In order to reduce the excessive advantage of crack propagation in the coal seam，the perforation horizon should be avoided in the coalbed，or a small amount of perforation is perforated in the coal seam；The appropriate perforation should be applied to the high-stress interval to ensure the normal fracturing construction and the high fracturing effect；Taking into account the sediment gravity of the proppant，the fracturing crack should be as much as possible initiate from the upper part of the commingled fracturing sections；On the basis of the previous three points，the target reservoirs should be perforated as much as possible to increase the fracturing effect.We consider that the coal seam should have a high crack-area-conductivity through the weighted method.The study results can provide a new method and basis for the perforation optimization of the multilayer combined fracturing in coal measure strata.
  • Geochemical characteristics and implication for gas and oil source correlation in the Tugeerming area of the Kuqa Depression，Tarim Basin
    Liu Ru-hong, Li Jian, Xiao Zhong-yao, Li Jin, Zhang Hai-zu, Lu Yu-hong, Zhang Bao-shou, Ma Wei, Li De-jiang, Liu Man-cang
    Natural Gas Geoscience. 2019, 30(4): 574-581. https://doi.org/10.11764/j.issn.1672-1926.2018.12.019
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Tugeerming area is located in the eastern part of the Kuqa Depression，Tarim Basin.In recent years，prolific oil and gas flow in Jurassic Yangxia Formation of Well Tudong 2 indicates broad prospects of exploration in this area.This paper carries out the oil-gas and source correlation in the Tugeerming area.The results are as follows.The biomarker characteristics of the crude oil of the Yangxia Formation of the Tugereming Jurassic group showed that the hydrocarbon precursor type was a typical freshwater source of terrestrial organic matters，Yangxia Formation.The natural gas of the group is coal-type condensate with associated gas.The maturity of the natural gas is the same as that of the crude oil and both of them are derived from the same hydrocarbon source rocks.In this paper，the biomarker comparison technique，n-alkane carbon isotope comparison technique，kerogen carbon isotope-crude carbon isotope comparison technology system was used to study the Jurassic Yangxia Formation oil in the Tugereming area and the hydrocarbon source rocks of Jurassic and Triassic in the area.The differences between the source rocks are comprehensive.The results show that there is a maternal relationship between the Yangxia Formation crude oil and the Jurassic Yangxia Formation and Kezilenur Formation source rocks，which provides an important reference for the evaluation of oil and gas resources in this area.
  • Characteristics and implications of diamondoids in crude oils from the Xihu Depression，East Sea Basin，China
    Wang Yong-gang, Tian Yan-kuan, Zhan Zhao-wen, Tang Rui
    Natural Gas Geoscience. 2019, 30(4): 582-592. https://doi.org/10.11764/j.issn.1672-1926.2018.12.017
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Molecular geochemical characteristics of thirty-one crude oil samples recovered from the Xihu Depression in the East China Sea were studied comprehensively by GC-MS analysis.The result shows that the oils have relatively high Pr/Ph ratios，heavier carbon isotope，C29 steranes preference in C27-C28-C29 series，diterpane preference such as abundant nor-isopotonane，isopotonane，phyllocladene，also abundant C24 tetracyclic terpanes and oleanane，while low abundance of gammacerane.The molecular composition characteristics indicate an oxydic sedimentary environment and a higher-plant organic source input.Adamantanes presents in abundance with a total amount reached 877-9 797μg/goil，dominated by monoamantane series，showing a characteristic of high-mature oil.Maturity parameters of adamantanes and alkylphenanthrene implied that the crude oils from Pinghu Formation distributed in the East Slope mainly originated from the Pinghu source rock at a late generation period and had experienced variable degrees of thermal-cracking.The crude oil in the Huagang Formation of the central depression belt is a mixture mainly composed of highly-matured oil or cracking oil and uncracked maturity oil，which sourced from the Huagang Formation during the main oil generation window.A large amount of condensate oil，natural gas generated from the high-over mature source rocks in the Pinghu Formation and light oil cracked from the lower reservoir oils contribute to the high abundance of adamantanes in shallow oil reservoirs distributed in Xihu Depression.


  • Experimental study on thermal evolution of kerogen in Paleozoic#br# #br# Experimental study on thermal evolution of kerogen in Paleozoic#br#
    Kang Guang-xing, Xu Xue-min, Wang Shuang-qing, Yang Jia-jia, Sun Wei-lin, Shen Bin, Qin Jing, Lu Ran, Zhang Xiao-tao, Guo Wang
    Natural Gas Geoscience. 2019, 30(4): 593-602. https://doi.org/10.11764/j.issn.1672-1926.2018.11.005
    Abstract ( ) Download PDF ( )   Knowledge map   Save
    Shale gas resources are abundant in the Lower Paleozoic shales in southern China，which are of very old age，high maturity and are lack of vitrinite，and thus lead to a technical problem for evaluating the thermal evolution degree of organic matter in them.Previous studies have shown that the H/C and O/C atomic ratios of kerogen decrease regularly with the increase of its maturity，but there is little research on high maturity stage kerogens，or kerogens lack of virinite，therefore，it remains unclear that how their element evolves and does the evolution of element composition quantitatively reflect to RO value? These are worthy of study.For this purpose，a series of simulation experiments of thermal evolution of kerogen have been carried out at temperatures ranging from 350℃ to 550℃ with Paleozoic source rocks，and the RO value and C，H，O composition of the kerogens were determined.The results show that: (1)to calibrate thermal evolution degree of kerogen of the Middle-Upper Proterozoic and Lower Paleozoic source rocks lack of vitrinite，coal with similar maturity to the source rock can be used by reacting together with the source rock throughout the thermal simulation experiment process，and it is efficient；(2) H/C and O/C atomic ratios of kerogen correlate highly to its maturity by exhibiting a consistent decrease of H/C atomic ratio with the increase of thermal maturity for all types of kerogens，whereas O/C atomic ratio decreases separately along individual paths for types Ⅰ，Ⅱ and Ⅲ kerogens with the increase of thermal maturity that meets at last at a high maturity with RO value around 3.5%；(3) there is a mathematical correlation betwe en H/C and O/C atomic ratios of kerogen (RH/C and RO/C) and the thermal maturity of organic matter characterized by vitrinite reflectance (RO) can be expressed as LgRO=0.133 1-1.190 5 LgRH/C-0.054 4 LgRO/C，which is suitable for all types of kerogens.


  • Specification of abstract writing
    Natural Gas Geoscience. 2019, 30(4): 603-604.
    Abstract ( ) Download PDF ( )   Knowledge map   Save
  • Natural Gas geoscience 2019-4 covers and titles
    Natural Gas Geoscience. 2019, 30(4): 9014-9042.
    Abstract ( ) Download PDF ( )   Knowledge map   Save
陇ICP备2021001824号-7　 甘公网安备 62010202000678号
Copyright © Natural Gas Geoscience, All Rights Reserved.
Tel: (0931)8277790　
E-mail：geogas@lzb.ac.cn
Total visitors:　 Visitors of today: 　 Now online:
Powered by Beijing Magtech Co. Ltd,.