10 December 2018, Volume 29 Issue 12
    

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  • Major progress of the Chinese natural gas geological theory and new exploration discovery since the Eleventh Five-year plan
    Wei Guo-qi, Li Jian, Yang Wei, Xie Zeng-ye, Dong Cai-yuan, She Yuan-qi, Ma Wei
    Natural Gas Geoscience. 2018, 29(12): 1691-1705. https://doi.org/10.11764/j.issn.1672-1926.2018.10.012
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    The progress of Chinese natural gas geological theory and new exploration discovery complement each other.Since the Eleventh Five-year plan,China natural gas geological theory has made great progress which can be concluded as the following seven aspects.There are two aspects of basic geological theory progress：(1)The formation mechanism of three types of natural gas,which are high evolution coal source rock,crude oil cracking gas and biogas,has been deepened to form coal source rocks cracking hydrocarbon-generation process mode,whole hydrocarbon-generation process of sapropelic source rock,and continuous biogas generation mode;(2)Natural gas origin identification theory of many types are furtherly improved including oil cracking gas and kerogen cracking gas,aggregated oil cracking gas and dispersed oil cracking gas,organic gas and inorganic gas,coal-formed gas and oil-formed gas.Five aspects of giant gas accumulation theory are deeply researched：(1)Innovation of old carbonate “five ancient factors controlling reservoir” accumulation theory is founded;(2)The theory of tight sandstone gas accumulation in craton basin,foreland basin and rift basin is developed and deepened;(3)An accumulation mode of "three micro carrier,near source enrichment and sustained preservation" is established;(4)Hydrocarbon accumulation theory of volcanic gas reservoirs in faulted basins with hydrocarbon-generated fractured trenches as the basic unit is improved;(5)The theory of high temperature and over pressure natural gas accumulation and deep sea natural gas accumulation in South China Sea is deepened.Development of natural gas geology theory promotes many big exploration discoveries.Innovation of old carbonate accumulation theory leads to the exploration of Chinese largest gas field of single formation which is Anyue Gas Field in Sichuan Basin;Innovation of accumulation theory in the foreland thrust belt brings about the first ultra-deep Chinese trillion cubic meters gas field in Kuqa Gas Field;Accumulation mode of super deep reef beach gas reservoir guides the exploration of Yuanba Gas Field which is the deepest buried reef gas field in China;The natural gas accumulation theory in South China Sea promotes the great discovery of Dongfang 13-2 Gas Field which is the biggest gas field in China waters and Lingshui 17-2 largest gas field in deep water.
  • Models and controlling factors of volcanic gas reservoirs forming in Dinan Salient in Junggar Basin
    Shi Xin-pu, Qin Jian-qiang, Ding Yan-xue, Yang Dan, Shi Quan-dang, Hu Qing-xiong, Li Bo, Qi Hong-yan, Zhang Ji-hui, Sun De-qiang, Zhao Zhen, Rao Yuan, Xi Cheng-wei
    Natural Gas Geoscience. 2018, 29(12): 1706-1714. https://doi.org/10.11764/j.issn.1672-1926.2018.10.027
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    Volcanic gas reservoir has become one of the important fields of oil and gas exploration and development.In recent years, new breakthroughs have been made in the research and progressive exploration and development of volcanic gas reservoirs in Dinan Salient of Junggar Basin.The comprehensive research suggests that the main controlling factors of volcanic gas reservoirs in Dinan Salient of Junggar Basin are：large nasal structure of volcanic gas reservoirs near hydrocarbon generation center was the basis of large-scale gas reservoirs;The coupling between faults and reservoir forming period was the most critical factor in forming gas reservoirs;Good space allocation of lithology and physical properties wereone of the main conditions for hydrocarbon accumulation;Tectonic controlled the scale of volcanic gas reservoirs;Sand properties controlled partial boundary of gas reservoir.Enrichment mode of volcanic gas reservoirs in Dinan Salient could be summarized as “Three Controls and One Body”.“Three Controls” were source control (sags near the source control)，height control (high points of palaeotectonic control), fault control（gas source faults control）;“One Body” meant that gas reservoirs were observed enrichment characteristics of “lithofaciesbody”.The study on forming model of volcanic gas reservoirs in DinanSalient could provide good references for the study on similar gas reservoirs at home and abroad.
  • The origin and influence of the grain beach reservoirs of  Cambrian Longwangmiao Formation in Central Sichuan area,Sichuan Basin
    Xie Wu-ren, Yang Wei, Li Xi-zhe, Wei Guo-qi, Ma Shi-yu, Wen Long, Guo Zhen-hua
    Natural Gas Geoscience. 2018, 29(12): 1715-1726. https://doi.org/10.11764/j.issn.1672-1926.2018.11.010
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    Based on thorough observation of the core of Longwangmiao Formation of 12 wells in Central Sichuan area and combined with seismic and drilling data,this paper studies the deposition environment,grain shoal reservoir characteristics and the sequence and combination of grain shoal of Longwangmiao Formation in Central Sichuan area,and analyzes the relationship of the widespread grain shoal reservoir and the high production of petroleum in this area.Longwangmiao Formation in the study area was deposited in gentle slope environment,and due to the formation of Gaoshiti-Moxisyn-depositional paleo-uplift in Central Sichuan before its deposition,the paleo-uplift controlled the large-area distribution of grain shoal in Longwangmiao Formation.Owing to overall regression and decline of the sea level,grain shoals formed in four stages vertically stacked within Longwangmiao Formation.Each grain shoal has a thickness of 10-20m and spreads laterally for 5-15km.Different grain shoals vertically superimposed,covering a large area.Grain shoals is composed of shoal body and shoal margin,and their distribution is controlled by minor landform change.The shoal bodies are separated and shoal margins are inter-connected.Grain shoals are mainly sand-grain dolostone,and it is reformed by dolomitization and epigenickarstification in later periods,forming high-quality reservoir with widespread karst pores,holes and cracks formed in multiple stages.Because of their great thickness,reservoirs in shoal margin have high production in single-well testing,and thus is the target of high petroleum production and rich petroleum accumulation.
  • Dissolution of Chang 8 tight reservoir and its quantitative influence on porosity in Jiyuan area,Ordos Basin
    Li Shu-tong, Yao Yi-tong, Qiao Hua-wei, Hui Xiao, Cheng Dang-xing, Zhang Wen-xuan, Mou Wei-wei
    Natural Gas Geoscience. 2018, 29(12): 1727-1738. https://doi.org/10.11764/j.issn.1672-1926.2018.10.008
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    Chang 8 reservoir in Jiyuan area of Ordos Basin holds characteristics of high feldspar content  and common feldspar dissolution phenomenon,which is important to improve the physical properties of tight reservoirs.On the basis of identifying the basic characteristics of Chang 8 tight reservoir,utilizing the simulation experiment of fluid-rock interaction with high temperature and high pressure,combined with polarized microscope and scanning electron microscope(SEM) and X-ray diffraction(XRD) analysis techniques,this paper simulates the interaction between Chang 8 reservoir rock samples and organic acid,analyzes the types and characteristics of dissolution,explains the dissolution mechanism and quantitatively calculates the influence of dissolution on porosity of reservoir.In order to make the simulation experiment more close to the actual geological conditions,0.15mol/L acetic acid solution with pH=2.65 is used as reaction fluid.The simulation temperature range is set to 87-103℃ and the simulated pressure range is set to 24.70-30.18MPa.The research result shows that intergranular pores and feldspar dissolved pores are the main pore types,of which the feldspar dissolved pores are more developed and accounts for 39% of the total porosity.The apparent solution ratio is 37.8% to 50.0% with moderate degree of dissolution.In addition,carbonate minerals can also be dissolved under acidic condition.The relative solution ratio of carbonate minerals generally exceeds feldspar.The dissolution degree is strongest at about 95℃ and the burial depth is about 2 370-2 710m by the geothermal gradient calculation,which should be the main distribution area of favorable reservoir of Chang 8.Overall,dissolution is the main diagenesis types to improve the porosity and result in the 3.57%-3.69% increase of porosityin tight reservoirs of Chang 8.Therefore,it is also the main controlling factor for the development of “dessert” in Chang 8 tight reservoir of western Jiyuan area.
  • Quantitative classification and characteristic difference of diagenetic facies in He 8 reservoir of the Su 48 block,west area of Sulige Gas Field,Ordos Basin
    Bai Yun-yun, Sun Wei, Ren Da-zhong, Han Jin
    Natural Gas Geoscience. 2018, 29(12): 1739-1747. https://doi.org/10.11764/j.issn.1672-1926.2018.08.002
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    The He 8 reservoir of Shihezi Formation in the Su 48 block of the west area of Sulige Gas Field of Ordos Basin belongs to braided river delta plain sedimentary subfacies.The development of reservoir is difficult because of the strong heterogeneity.This paper is based on the knowledge of oil and gas reservoir geology,sedimentology,etc.The quantitative characterization of diagenetic effects on pore densification were studied by conducting various experiments including cast thin section,cathode luminescence,image particle size,X-ray diffraction,scanning electron microscope.The quantitative classification standard for diagenetic faciesis established by diagenetic,physical and pore parameters,and the differences in characteristics of different diagenetic facies are described.The study shows that the study area belongs to ultra-low porosity and ultra-low permeability oilfield mainly composed of lithic quartz sandstone and quartz sandstone.The qualitative characteristics of diagenesis indicate that the study area is mainly in the middle diagenetic stage B.Mechanical compaction is the main controlling factor for reservoir densification under a series of diagenetic evolutions such as compaction-early cementation-dissolution-late cementation.Four types of diagenetic faciescan be classified according to the diagenetic parameters.The moderate compaction,quartz weakening,intergranular pore,and dissolution pore facies are distributing in the middle of the diversion channel,belonging to high-quality diagenetic facies.Followed by the moderate compaction,moderate kaolinite cementation,dissolution phase,and  intercrystalline hole.The mechanism of ultra-low porosity in study area has been clarified and it can provide a reference for advanced description of micro-pore of Sulige Gas Field.
  • Development patterns of karst reservoir of Ma 5 member in Fuxian area,Ordos Basin
    Hu Xin, Ding Xiao-qi, Liang Chang-jian, Zhu Ying, Liu Xuan, Xu Xiao-yu, Chen Yi-lai
    Natural Gas Geoscience. 2018, 29(12): 1748-1756. https://doi.org/10.11764/j.issn.1672-1926.2018.08.001
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    Fuxian area of Ordos Basin is located in the palaeokarst upland.The karstification of Fuxianwas characterized by long duration and high intensity of action.The main gas production layer of Fuxian is not continuous in transverse direction.In order to find out the regularities of distribution of reservoirs in Ma 5 member,karst reservoirs in the Ma 5 member are studied through data analysis of cores,well logging and various tests.The results show that:(1)Ma 5 member is severely brecated,and can be divided into 4 karst facies and 3 cave facies.The intensity of karstification gradually increases from west to east.(2)The Ma 5 member has poor physical properties,and the reservoir space is mainly constituted of vugs,gypsum moldic pores,fractures that are not completely filled,intercrystalline pores and intercrystalline pores.High-quality reservoirs mainly distributed in the crackle-mosaic breccia facies at the top of Mawu-6 in the north.(3)The development of reservoirs in Ma 5 member is mainly controlled by three factors:Lithology,karst and cave facies,and paleotopography.Lithology and paleotopography control the development and distribution of karst facies and cave facies,and further control the distribution of reservoirs.
  • Division and distribution of flow units of Chang 613reservoir in Huaqing area,Ordos Basin
    Xu Zheng, Fu Qiang, Hui Xiao, Li Jing, Li Shi-xiang, Li Xiang-tong
    Natural Gas Geoscience. 2018, 29(12): 1757-1766. https://doi.org/10.11764/j.issn.1672-1926.2018.09.008
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    The Chang613  sand set of Triassic Yanchang Formation in Huaqing area of Ordos Basin is a typical tight sandstone reservoir with low porosity and low permeability.Through the analysis of casting thin sections and scanning electron microscope and combined with main diagenesis,the sandstone reservoir of this sand set can be divided into eight diagenetic facies which corresponding to 5 diagenetic assemblages：constructive cementation and dissolution,constructive cementation or dissolution,destructive cementation and dissolution,destructive cementation and mechanical compaction. A new idea and method for dividing the flow unit is proposed on the basis of the diagenetic assemblage background. By using the K-means clustering method,the flow unit is divided into 5 categories through 608 wells’ reservoir parameter data and the sedimentary microfacies in this area,which can provide important application values for the prediction of favorable exploration area.
  • Study of the method of portrayed the river by calculating the tooth rate of logging curve
    Zhang Guang-quan, Li Hao, Hu Xiang-yang, Chen Shu-wei, Gao Yang
    Natural Gas Geoscience. 2018, 29(12): 1767-1774. https://doi.org/10.11764/j.issn.1672-1926.2018.10.023
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    In order to accurately describe the reservoir distribution of the oil and gas field，the precision of the portrayal of the channel microfacies is getting higher and higher.Aiming at the existing problems and difficulties in sedimentary microfacies，a method of determining the location of river channels and describing the river channels with high accuracy is proposed by calculating the tooth rate of logging curves.The tooth rate is characterized by the amplitude of the tooth，the density of the tooth and the frequency of the tooth distribution.The general idea is to calculate the three parameters of logging first，and then give eachparameter a certain weight coefficient，and get the tooth rate of the curve section of the log.According to the size of the tooth rate，the specific location of the log in the channel is analyzed，and the channel is finely depicted. Compared with traditional method of sedimentary facies research，the method has improved the accuracy of the boundary characterization and achieved semi-quantitative or quantitative accuracy.In the application of sedimentary research of X Gasfield in Ordos Basin，the position of the river is determined by the tooth rate，and the accuracy of the boundary is obviously improved.The research results can be applied directly to the production and guide the optimization of the favorable area and the deployment of the well position.
  • Geostress logging evaluation method of Longmaxi Formation shale in Fuling area based on transversely isotropic model，Sichuan Basin
    Zou Xian-jun, Chen Ya-lin
    Natural Gas Geoscience. 2018, 29(12): 1775-1780. https://doi.org/10.11764/j.issn.1672-1926.2018.10.017
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    Shale exhibits anisotropy because of preferred alignment of clay particles and tabular bedding.It is not appropriate to compute stress with isotropic model.We introduce a stress logging evaluation method for Longmaxi Formation shale based on transversely isotropic model by analyzing the relation between vertical effective stress and shear wave velocity to predict formation pressure，building rock physics model to compute Biot coefficient and using velocity-regression method to calculate stiffness coefficients.The application results indicate that transversely isotropic model reflects the actual formation more accurately.
  • The influence of Permian igneous rock on the seismic imaging of underlying strata in Hanilcatam area,Tarim Basin
    Sun Dong, Shi Xiao-qian, Wang Zhen-qing, Chen Li-xin, Wang Jing, Sun Jia-qing, Dai Dong-dong, Fang Qi-fei
    Natural Gas Geoscience. 2018, 29(12): 1781-1787. https://doi.org/10.11764/j.issn.1672-1926.2018.10.019
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    In order to get an accurate view of the influence of thick igneous rock on the seismic imaging of the underlying strata,based on the actual drilling and logging data and the 3D seismic data,the Cambrian-Cretaceous simplified geologic model,and the finite difference method are used to solve the elastic wave equation.The forward equation simulation of the wave equation is carried out,the true restoration seismic imaging process is carried out,and the influence of the Permian igneous rock body on the seismic imaging of the underlying strata is discussed.Paleozoic oil and gas exploration and development play a certain reference.The results show that the high-speed and high-density Permian dacite have shielding effect on the seismic imaging of the underlying strata,and the amplitude of the reflected wave of the underlying strata is obviously weakened relative to the periphery of the covering area.Due to the lateral mutation of the lithology,the seismic imaging of the layers has obvious deformation and tectonic anomalies,rather than the seismic response of the fault zones or volcanic channels.The wavefield of fracture-cavern body in the disorder reflection region and underlying region of volcanics is very complex and the imaging velocity is difficult to pick accurately,which leads to distorted migration results and not convergent bead-like reflection.
  • Water-yielding pattern and influencing factors of gas wells of Changling volcanic gas reservoir，Songliao Basin
    Song Wen-li, Dong Jia-xin, Sun Yuan-hui, Huang Yu-xin, Wang Jun-yu
    Natural Gas Geoscience. 2018, 29(12): 1788-1794. https://doi.org/10.11764/j.issn.1672-1926.2018.08.007
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    Changling volcanic gas reservoir is rich in natural gas resources. However water production in gas wells is a common phenomenon in the development process. Accurate analysis of producing water law，water-yielding pattern and its influencing factors of gas wells have great significance in optimizing development plan and improving development effect. This paper studied the geological characteristics and comprehensively analyzes water producing dynamic characteristics of gas reservoir of Yingcheng Formation，Changling Gasfield. The result shows that the main sources of producing water in gas wells are condensate water and bottom water. Numerical simulation technology was used to study the mechanism of different types of water production output. This paper analyzed the water-yielding law of the gas wells and used numerical simulation to forecast the quantity of gas wells water production.On this basis，the paper summarized 4 kinds of water-yielding patterns，i.e.,fracture in the longitudinal strong water channeling，fracture in the longitudinal weak water channeling，fracture-pore in the longitudinal water coning，and high water saturation pattern. Moreover this paper made clear the influencing factors of gas wells water-yielding.There are four main factors，i.e.，tectonic characteristics，gas wells peaking，inter-well interference，gas wells production.Finally the paper proposed a water-yielding development strategy which is overall consideration，classification management.
  • Seepage model of volume fracturing horizontal well in shale gas reservoir
    Wang Yan-chen, Chen Jun, Deng Ya, Xiao Cong
    Natural Gas Geoscience. 2018, 29(12): 1795-1802. https://doi.org/10.11764/j.issn.1672-1926.2018.07.013
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    The seepage mechanism and productivity model of shale gas reservoirs is the critical and scientific issue to develop the shale gas reservoirs effectively.The pore structures of shale possess the strong multi-scale characteristic,and complexity of seepage mechanisms.Knudsen diffusion,matrix deformation,stress sensitivity,non-Darcy flow and complex fracture network stimulated by hydraulic fracturing technology have certain effects on the multi-scale flow characteristic and productivity model. Firstly,this paper establishes a model of apparent permeability with the consideration of adsorption,diffusion,viscous flow,rock deformation,adsorption layer.On the basis of this proposed models,the influences of some related parameters,such as rock deformation,adsorption layer,on capillary radius and apparent permeability are analyzed.Secondly,for the different fracture pattern of multi-stage fractured horizontal well and volumetric fracturing horizontal well,with the consideration of gas adsorption,diffusion,matrix deformation,stress sensitivity and non-Darcy flow,two productivity prediction models are established based on the coupled hydraulic fractures and natural fractures.Finite difference method,Newton-Rapson iterative method and embed discrete fracture method are respectively employed to solve those two models.Finally,the orthogonal test design is employed to identify and analyze the dominated factors among the relevant parameters,such as fracture spacing,fracture half length,fracture numbers,fracture conductivity,permeability,and so on.The results can provide some certain guidance for the optimization of stimulated treatment in shale gas reservoirs.
  • Integrated method for calculating water influx and dynamic geological reserves in water-drive gas reservoirs
    Du Ling-yun, Wang Nu-tao, Chen Hui, Zhang Meng-li, Li Fang
    Natural Gas Geoscience. 2018, 29(12): 1803-1808. https://doi.org/10.11764/j.issn.1672-1926.2018.10.018
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    When calculating the water influx and geological reserves of the water-drive gas reservoir by using the material balance method，large errors will occur due to artificial selection of the regression points and the identification of the chart，and of ten results in different calculation results of geological reserves and water influx by different methods. In view of the above problems，this paper analyzes the difference method，chart method and apparent geologic reserves method in the material balance method of water influx calculation，establishes the constraint conditions between the three methods，forms a new calculation method and carries out the example calculation. The error sources of conventional material balance method have been calculated and analyzed by examples，and the new method has been verified. The calculation results show that the new method has good practicability and reliability，which can be applied to the calculation of geological reserves and water influx of water-drive gas reservoirs.
  • Molecular simulation of methane adsorption within illite minerals in the shale of the Longmaxi Formation based on a grand canonical Monte Carlo method and pore size distribution
    Tang Xin, Zhu Yan-ming, Guo Yuan-chen, Liu Yu, Zhou Xiao-yi
    Natural Gas Geoscience. 2018, 29(12): 1809-1816. https://doi.org/10.11764/j.issn.1672-1926.2018.10.006
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    To investigate the pore structure and adsorption capacity of illite with respect to methane in the Longmaxi Formation，isothermal adsorption experiments utilizing mercury intrusion，liquid nitrogen and low-temperature carbon dioxide techniques were applied to shale samples from Sichuan Basin.The adsorption characteristics of illite slit pores with different diameters were simulated using the Monte Carlo method.The results demonstrate that the pore volume and specific surface area of the shale are primarily supplied by pore diameters of less than 2nm.Illite is one of the primary components of the clay mineralogy within the shale and forms parallel or nearly-parallel plate pores.For pore sizes ranging from 0.5nm to 0.9nm (at 303.15K and 8MPa)，the methane molecules are affected by van der Waals and electrostatic forces，and the excess adsorption capacity of methane is big.When the pore size is bigger than 0.9nm，the methane adsorption is primarily affected by van der Waals forces，and the excessadsorption capacity of methane initially decreases，after which it remains unchanged with anincrease in the pore size.The free gas content increases with increasing pore diameters.The average equivalent adsorption heat reflects that the adsorption of methane onto illite is characterized by physical adsorption.During the adsorption process，when the pore size is between 0.5nm and 1.2nm，the average equivalent adsorption heat decreases rapidly with an increase of the pore diameter.When the pore size exceeds 1.2nm，the adsorption intensity between the methane molecules and the illite slit is essentially stable，and the average adsorption heat is 6.72kJ/mol.When the pore size is between 0.5nm and 0.8nm，the monolayer of methane is adsorbed onto the pore wall，and the local density of methane exhibits the characteristics of a single peak.When the pore size is between 0.8nm and 1.2nm，the adsorption mode changes from single-layer adsorption to double-layer adsorption，and the local density curve changes from unimodal to bimodal.When the pore size is bigger than 1.2nm，the free volume of methane adsorption can be big，and the local density curve is bimodal.
  • The porous evolution and fractal dimension of the organic-rich shale at the stage of hydrocarbon generation
    Yin Na, Xue Lian-hua, Jiang Cheng-fu, Yang Shuang, Gao Chao, Chen Guo-jun
    Natural Gas Geoscience. 2018, 29(12): 1817-1828. https://doi.org/10.11764/j.issn.1672-1926.2018.08.009
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    To study the micro pore shale thermal evolution，this paper takes Triassic black shale of different maturity (RO=0.53%-1.09%) in Ordos Basin as the research object，characterizingshale pore evolution by scanning electron microscopy，N2 adsorption method,X-ray，and exploring the fractal characteristics of shale based on the thermal evolution of the FHH fractal model.The results show that as the maturity of organic matter increases，the pores of organic matter increase，the average pore size decreases,the total pore volume，mainly controlled by the volume of the large pores and mesoporous pores，decreases first and then slightly increases; and the specific surface area first decreases and then increases，which is in accordance with the evolution trend of the mesoporous volume.The above phenomena may be closely related to compaction and hydrocarbon generation and expulsion byorganic matter.Furthermore,the pore size of organic matter is closely related to RO and is the largest contributor to mesopores.The fractal dimension (calculated by FHH model)which is negatively correlated with pore volume and average pore size，and positively related to specific surface areaincreases generally(between 2.513 and 2.745)，indicating that shale pore structure tends to be complex，and the adsorption capacity is improved.
  • 《天然气地球科学》2018年第12期封面及目次
    《天然气地球科学》年第期封面及目次
    Natural Gas Geoscience. 2018, 29(12): 8121-8122.
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    《天然气地球科学》2018年第12期封面及目次
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