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Acta Geologica Sinica(English Edition) 2016年第6期90卷 2277-2278页

作者： TANG Yue TANG Dazhen DU Zhili School of Energy Resources China University of Geosciences oil & gas survey China Geological Survey

Thermochemical sulfate reduction （TSR） is the reaction between anhydrite and petroleum fluids at elevated temperatures to produce H2S and CO2. TSR has been studied in many sedimentary basins such as China＇s Sichuan and Tarim basins because it has a profound impact on the commercial viability of petroleum resources, with HzS typically being undesirable.

关键词： TSR The First Report of Thermochemical Sulfate Reduction Reaction in the Upper Paleozoic Carbonate Rocks of Southeastern Ordos Basin

Coalbed Methane Enrichment Regularity and Major Control Factors in the Xishanyao Formation in the Western Part of the Southern Junggar Basin

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Acta Geologica Sinica(English Edition) 2020年第2期94卷 485-500页

作者： YUAN Yuan SHAN Yansheng TANG Yue CAO Daiyong China University of Mining&Technology Beijing 100083China China Geological survey Oil and Gas SurveyBeijing 100083China

There are abundant coal and coalbed methane(CBM)resources in the Xishanyao Formation in the western region of the southern Junggar Basin,and the prospects for CBM exploration and development are promising.To promote the exploration and development of the CBM resources of the Xishanyao Formation in this area,we studied previous coalfield survey data and CBM geological exploration data.Then,we analyzed the relationships between the gas content and methane concentration vs.coal seam thickness,burial depth,coal reservoir physical characteristics,hydrogeological conditions,and roof and floor lithology.In addition,we briefly discuss the main factors influencing CBM accumulation.First,we found that the coal strata of the Xishanyao Formation in the study area are relatively simple in structure,and the coal seam has a large thickness and burial depth,as well as moderately good roof and floor conditions.The hydrogeological conditions and coal reservoir physical characteristics are also conducive to the enrichment and a high yield of CBM.We believe that the preservation of CBM resources in the study area is mainly controlled by the structure,burial depth,and hydrogeological conditions.Furthermore,on the basis of the above results,the coal seam of the Xishanyao Formation in the synclinal shaft and buried at depths of 700-1000 m should be the first considered for development.

关键词： coalbed methane enrichment regularity major control factors Xishanyao Formation western area of the southern Junggar Basin

Composition and distribution of NSO compounds in two different shales at the early maturity stage characterized by negative ion electrospray ionization coupled with Fourier transform ion cyclotron resonance mass spectrometry

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Petroleum Science 2018年第2期15卷 289-296页

作者： Chang-Wei Ke Yao-Hui Xu Xiang-Chun Chang Wei-Bin Liu Key Laboratory of Exploration Technologies for oil and gas Resources (Yangtze University) Ministry of Education College of Resources and Environment Yangtze University College of Earth Science and Engineering Shandong University of Science and Technology oil and gas survey China Geological Survey

gas chromatography/mass spectrometry （GC/MS） can only analyze volatile molecular compounds, and it has limitations when applied to determine the complex components of crude oils and hydrocarbon source rocks. Based on Fourier transform ion cyclotron resonance mass spectrometry （FT-ICR-MS） and GC/MS analyses, the molecular compositions of NSO compounds in extracts from the Permian Dalong Formation, Sichuan Basin and the Permian Lucaogou Formation, Junggar Basin in China were compared. Analyses of types of heteroatoms present （S~, $2, $3, OS, OS2, 02S, NS, and NOS compounds） suggest that marine shales from the Dalong Formation are mainly composed of carboxylic acids （02 com- pounds） with a high abundance of fatty acids, indicating a marine phytoplankton organic source. However, lacustrine shales from the Lucaogou Formation are dominated by pyrrolic compounds （N1 compounds） with abundant dibenzocar- bazole. It suggests that the organic source materials may be derived from lower aquatic organisms and lacustrine algae. Overall, FT-ICR-MS has potential for applications in analyses and determination of depositional environments and organic sources in petroleum geology.

关键词： Fourier transform ion cyclotron resonance mass spectrometry Dalong Formation Lucaogou Formation NSO compounds Sedimentary environment

Triassic magmatism in the eastern part of the South China Block： Geochronological and petrogenetic constraints from Indosinian granites

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Geoscience Frontiers 2017年第3期8卷 445-456页

作者： Wanli Gao Zongxiu Wang Chunlin Li Key Lab of Shale oil and gas Geological survey Institute of GeomechanicsChinese Academy of Geological Science

The granitic dykes in the Badu Group, Zhejiang Province, South China provide important insights on tectonic setting and crustal evolution of the South China Block （SCB） and the Indochina Block during Triassic. Here we report LA-ICP-MS U-Pb data of granitic rocks from the Hucun and Kengkou which show early Triassic ages of 242 ± 2 and 232 ± 3 Ma, respectively, representing their timing of emplacement. The dyke rocks are enriched in K, AI, LREE, Rb, Th, U, and Pb, and are depleted in Nb, Ta, St, and Ti. The rocks are characterized by highly fractionated REE patterns with （La/Yb）N ratios of 28.46 -38.07 with strong negative Eu anomalies （Eu/Eu＊ = 0,65-0.73）. In situ Hf isotopic analyses of zircons from the Hucun granite yielded CHf（t） values of -13.9 to -6.4 and two-stage depleted mantle Hf model ages of 1.68-2.15 Ga, which indicate that the magma was formed by partial melting of the Paleo- proterozoic metasedimentary protoliths in the Cathaysia Block. The zircons from the Kengkou granite have eHf（t） values ranging from -40.7 to 31.5 and yield two-stage depleted mantle Hf model ages of 0.99 -2.49 Ga, indicating magma origin from a mixed source. The Hucun and Kengkou dykes, together with the Triassic A-type granites in SE China were probably generated during magmatism associated with crust-mantle decoupling along the convergent plate boundary between SCB and the Indochina Block.

关键词： Granitic dykes Geochronology Geochemistry lndosinian Eastern South China Block

Tectonic evolution of the Huangling dome and its control effect on shale gas preservation in the north margin of the Yangtze Block, South China

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China Geology 2020年第1期3卷 28-37页

作者： Jun-feng Zhang Gang-yi Zhai Da-ming Wang Shu-jing Bao Ke Chen Hao-han Li Teng Song Peng Wang Zhi Zhou oil and gas survey China Geology SurveyMinistry of Natural ResourcesBeijing 100083China

Significant breakthroughs of shale gas exploration have been made in Lower Cambrian and Sinian shale in the north margin of the Yangtze Block,South China.The drill wells with industrial gas flow located in the southern margin of the Huangling dome.Base on the geological survey,2D seismic,geochronological and drill wells data,the tectonic evolution history of Huangling dome was studied,and its control effect on the preservation condition of shale gas was discussed.The result shows that the Huangling dome might undergo four tectonic stages:(1)About 800 Ma,granite intrusion in the Huangling dome basement,primarily of granites replaced metamorphism rocks;(2)800-200 Ma,no significant tectonic movement with slowly buried history;(3)From 200 Ma,multi-phase uplift and the sedimentary rocks was eroded in the core of the Huangling dome.Shale gas in the Cambrian and Sinian strata was well preserved in the margin of the Huangling dome as the following reasons:(1)The Sinian shale was buried about 7.8 km indepth during Middle Jurassic,source rocks have a suitable thermal maturity for shale gas;(2)The rigid basement of the Huangling dome was mainly composed by homogeneity granite,without intensive deformation.As the main challenges of the widely distributed Lower Cambrian and Sinian shale are highmaturity and intensive deformation,a geological unit with a dome probably is a favorable zone for the old age shale gas.Therefore,it indicates that the adjacent zone of the Xuefengshan,Shennongjia and Hannan are the geological units with a dome and probably have potentials for the exploration of shale in the Lower Cambrian and Sinian.

关键词： Shale gas Degree of thermal evolution Huangling dome Tectonic evolution Preservation conditions Lower Cambrian and Sinian South China

Net primary productivity and its control of the Middle Jurassic peatlands: An example from the southern Junggar coalfield

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Science China Earth Sciences 2018年第11期61卷 1633-1643页

作者： Yanan LI Longyi SHAO Zhiming YAN Haihai HOU Yue TANG David J.LARGE College of Geoscience and surveying Engineering China University of Mining and Technology oil and gas Resources survey Center China Geological Survey Administration Faculty of Engineering University of Nottingham

The Jurassic is an important period of global coal formation, including the development of several large coalfields in central Asia and northern China. Individual seams within these peatlands represent sustained periods of terrestrial carbon accumulation and a key environmental indicator attributed to this record is the rate of carbon accumulation. Determining the rate of carbon accumulation requires a measure of time contained within the coal and this study aimed at determining the rate via the identification of Milankovitch orbital cycles using spectral analysis. Spectral analyses of geophysical data from two thick coal seams, No. 43(35.9 m) and No. 3(13.2 m), of the Middle Jurassic of the southern Junggar coalfield were conducted to identify significant signals of variations in ash content. The results showed that the variations in ash content of the coal showed spatial cycles at 0.2, 0.7 and 1.1 m^(-1), which were interpreted to represent 123 ka(eccentricity), 37.1 ka(obliquity), and 21.2 ka(precession) orbital periodicities, respectively. Using this timeframe, the depositional time of the No. 43 and No. 3 coal seams were calculated to be 876–970 and 322–357 ka, respectively. In combination with an understanding of carbon loss during coalification, the carbon accumulation rates of these Middle Jurassic peatlands were calculated to be 58.6–64.9 and60.3–66.8 g C m^(-2) a^(-1) for the No. 43 and No. 3 coal seams, respectively. Given that the net primary productivity(NPP) was 4.3 times the value of the carbon accumulation in a mid-latitude region of 40°–45°N, an NPP of 251.8–279.1 and259.1–287.1 g C m^(-2) a^(-1) was calculated for the No. 43 and No. 3 coal seams, respectively. In the context of the same paleolatitude(40°–45°N) and peat type, the NPP values of the Middle Jurassic strata in the study area were higher than those of the peatlands of the Holocene and Permian, and were similar to the NPP values of Early Cretaceous peatlands. Considering the NPP of a peatland is predominantly controlled by atmospheric

关键词：生产率 Milankovitch 煤田控制个例光谱分析地球物理早白垩纪

Latest Progress and Trend Forecast of China’s Shale gas Exploration and Development

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Acta Geologica Sinica(English Edition) 2015年第A1期89卷 211-213页

作者： WANG Yufang ZHAI Gangyi BAO Shujing REN Shoumai GE Mingna ZHOU Zhi oil & gas survey China Geological Survey

1 Introduction With almost five years of efforts, we have made major breakthrough and important advances in shale gas in many areas, such as the marine and continental shale in Sichuan Basin, the continental shale in Erdos Basin and the transitional shale in North China. China has begun shale gas productivity constructions in many shale gas development demonstration areas, such as Chongqing Fuling and Sichuan Changlin-Weiyuan, where early stage large-scale development of shale gas has been started （Zhang, 2010; Li, 2012; Dong et al., 2012; Luo and Li, 2013; Pan and Huang, 2009; Wang, 2014）. China, following U.S. and Canada, has become the third country realizing commercial development of shale gas.

关键词： SHALE gas reservoirs SHALE gas NATURAL gas -- Prospecting PETROLEUM production

The influence factors of gas-bearing and geological characteristics of Niutitang Formation shale in the southern margin of Xuefeng Mountain ancient uplift: A case of Well Huangdi 1

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China Geology 2020年第4期3卷 533-544页

作者： Ming-na Ge Ke Chen Xiang-lin Chen Chao Wang Shu-jing Bao oil and gas Resources survey China Geological SurveyMinistry of Natural ResourcesBeijing 100083China

In order to evaluate the geological characteristics and gas-bearing factors of Niutitang Formation within the Lower Cambrian of northern Guizhou,the Huangping area located at the southern edge of the ancient uplift belt of Xuefeng Mountain was selected as the target area,and Well Huangdi 1 was drilled for the geological survey of shale gas.Through geological background analysis and well logging and laboratory analysis such as organic geochemical test,gas content analysis,isothermal adsorption,and specific surface area experiments on Well Huangdi 1,the results show that the Niutitang Formation is a deep-water shelf,trough-like folds and thrust fault.The thickness of black shale is 119.95 m,of which carbonaceous shale is 89.6 m.The average value of organic carbon content is 3.55%,kerogen vitrinite reflectance value is 2.37% and kerogen type is sapropel-type.The brittle mineral content is 51%(quartz 38%),clay mineral content is 38.3%.The value of porosity and permeability are 0.5%and 0.0014 mD,which the reservoir of the Niutitang Formation belongs to low permeability with characteristics of ultra-low porosity.The gas content is 0.09‒1.31 m^3/t with a high-value area and a second high-value area.By comparing with the geological parameters of adjacent wells in the adjacent area,the accumulation model of“sediment control zone,Ro control zone,structure controlling reservoir”in the study area is proposed.Therefore,deep-water shelf-slope facies,Ro is between high maturity-early stage of overmaturity and well-preserved zones in the Niutitang Formation in this area are favorable direction for the next step of shale gas exploration.

关键词： Shale gas gas-bearing Well Huangdi 1 Influence factors Niutitang Formation Xuefeng Mountain ancient uplift oil and gas exploration engineering Lower Cambrian Guizhou Province China

A New Example of Retrograde Solubility Model for Carbonate Rocks

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Acta Geologica Sinica(English Edition) 2017年第3期91卷 1145-1146页

作者： LIU Lihong WANG Chunlian WANG Daming WANG Haida oil & gas survey China Geological Survey oil and gas Research Center School of Earth and Space SciencesPeking University MLR Key Laboratory of Metallogeny and Mineral Assessment Institute of Mineral ResourcesChinese Academy of Geological Sciences China Geological survey

Objective The dissolution and precipitation of carbonate during burial diagenetic process controls the reservoir property in deep buried strata. The geological process related with it has become a research focus during recent years. The most important dissolution fluids to carbonates are probably H2S and CO2 as byproducts of sulfate reduction in deep-buried setting with sulfate minerals, but carbonates are more soluble in relatively low temperature, which is the so-called retrograde solubility. Several geological processes can result in the decrease of temperature, including the upward migration of thermal fluids and tectonic uplift.

关键词： of on with well A New Example of Retrograde Solubility Model for Carbonate Rocks for

Pre-stack seismic density inversion in marine shale reservoirs in the southern Jiaoshiba area, Sichuan Basin, China

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Petroleum Science 2018年第3期15卷 484-497页

作者： Yuan-Yin Zhang Zhi-Jun Jin Ye-Quan Chen Xi-Wu Liu Lei Han Wu-Jun Jin oil and gas survey China Geological Survey Beijing 100083 China State Key Laboratory of Shale oil and gas Enrichment Mechanisms and Effective Development Beijing 100083 China State Energy Center for Shale oil Research and Development Beijing 100083 China Sinopec Key Laboratory of Shale oil/gas Exploration and Production Technology Beijing 100083 China Petroleum Exploration and Production Research Institute Sinopec Beijing 100083 China

For a typical marine shale reservoir in the Jiaoshiba area, Sichuan Basin of China, P-impedance is sensitive for identifying lithology but not suitable for indicating good shale reservoirs. In comparison, density is an important quantity, which is sensitive for identifying the organic-rich mud shale from non-organic-rich mud shale. Due to the poor data quality and incidence angle range, density cannot be easily inverted by directly solving the ill-posed pre-stack seismic inversion in this area. Meanwhile, the traditional density regularizations implemented by directly using the more robust P-impedance inversion tend to be inaccurate for recovering density for this shale reservoir. In this paper, we combine the P-impedance and the minus uranium to construct the pseudo-P-impedance（PIp） at well locations. The PIp is observed to be sensitive for identifying organic-rich mud shale and has a good correlation with density in this area. We employ the PIp–density relation into the pre-stack inversion framework to estimate density. Three types of regularization are tested on both numerical and field data： These are no regularization, traditional regularization and the proposed approach. It is observed that the proposed method is better for recovering the density of organic-rich mud shale in the Jiaoshiba area.

关键词： Density inversion Pseudo-P-impedance Pure P-wave data Regularization