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Geochemical identification of a source rock affected by migrated hydrocarbons and its geological significance:Fengcheng Formation,southern Mahu Sag,Junggar Basin,NW China

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Petroleum Science 2024年第1期21卷 100-114页

作者： Wen-Long Dang Gang Gao Xin-Cai You Ke-Ting Fan Jun Wu De-Wen Lei Wen-Jun He Yong Tang State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum(Beijing)Beijing102249China School of GeoSciences China University of Petroleum(Beijing)Beijing102249China Exploration&Development Institute Xinjiang Oil Field CompanyKaramay834000XinjiangChina

The Fengcheng Formation is a crucial source rock and the primary reservoir for oil accumulation in the Mahu Sag.Crude oils are distributed throughout the Fengcheng Formation,ranging from the edge to the interior of the sag in the southern Mahu Sag.These crude oils originate from in-situ source rocks in shallowly buried areas and the inner deep sag.During migration,the crude oil from the inner deep sag affects the source rocks close to carrier beds,leading to changes in the organic geochemical characteristics of the source rocks.These changes might alter source rock evaluations and oil-source correlation.Based on data such as total organic carbon(TOC),Rock-Eval pyrolysis of source rocks,and gas chromatography-mass spectrometry(GC-MS)of the saturated fraction,and considering the geological characteristics of the study area,we define the identification characteristics of source rock affected by migrated hydrocarbons and establish the various patterns of influence that migrated hydrocarbons have on the source rock of the Fengcheng Formation in the southern Mahu Sag.The source rocks of the Fengcheng Formation are mostly fair to good,containing mainly Type II organic matter and being thermally mature enough to generate oil.Source rocks affected by migrated hydrocarbons exhibit relatively high hydrocarbon contents(S1/TOC>110 mg HC/g TOC,Extract/TOC>30%,HC:hydrocarbon),relatively low Rock-Eval Tmax values,and relatively high tricyclic terpane contents with a descending and mountain-shaped distribution.Furthermore,biomarker composition parameters indicate a higher thermal maturity than in-situ source rocks.Through a comparison of the extract biomarker fingerprints of adjacent reservoirs and mudstones in different boreholes,three types of influence patterns of migrated hydrocarbons are identified:the edge-influence of thin sandstone-thick mudstone,the mixed-influence of sandstone-mudstone interbedded,and the full-influence of thick sandstone-thin mudstone.This finding reminds us that the influence of migrated hydrocarbons

关键词： organic geochemistry Source rock Influence of migrated hydrocarbons Fengcheng Formation Southern Mahu Sag

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Intelligent geochemical interpretation of mass chromatograms:Based on convolution neural network

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Petroleum Science 2024年第2期21卷 752-764页

作者： Kai-Ming Su Jun-Gang Lu Jian Yu Zi-Xing Lu Shi-Jia Chen Hubei Key Laboratory of Petroleum geochemistry and Environment Wuhan430100HubeiChina College of Resources and Environment Yangtze UniversityWuhan430100HubeiChina School of Geoscience and Technology Southwest Petroleum UniversityChengdu610500SichuanChina Changqing Oilfield Company PetroChinaXi©an710021ShaanxiChina

Gas chromatography-mass spectrometry(GC-MS)is an extremely important analytical technique that is widely used in organic geochemistry.It is the only approach to capture biomarker features of organic matter and provides the key evidence for oil-source correlation and thermal maturity determination.However,the conventional way of processing and interpreting the mass chromatogram is both timeconsuming and labor-intensive,which increases the research cost and restrains extensive applications of this method.To overcome this limitation,a correlation model is developed based on the convolution neural network(CNN)to link the mass chromatogram and biomarker features of samples from the Triassic Yanchang Formation,Ordos Basin,China.In this way,the mass chromatogram can be automatically interpreted.This research first performs dimensionality reduction for 15 biomarker parameters via the factor analysis and then quantifies the biomarker features using two indexes(i.e.MI and PMI)that represent the organic matter thermal maturity and parent material type,respectively.Subsequently,training,interpretation,and validation are performed multiple times using different CNN models to optimize the model structure and hyper-parameter setting,with the mass chromatogram used as the input and the obtained MI and PMI values for supervision(label).The optimized model presents high accuracy in automatically interpreting the mass chromatogram,with R2values typically above 0.85 and0.80 for the thermal maturity and parent material interpretation results,respectively.The significance of this research is twofold:(i)developing an efficient technique for geochemical research;(ii)more importantly,demonstrating the potential of artificial intelligence in organic geochemistry and providing vital references for future related studies.

关键词： organic geochemistry Biomarker Mass chromatographic analysis Automated interpretation Convolution neural network Machine learning

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organic geochemistry and source rock potential assessment of Late Paleocene Patala Formation in Margalla Hill Range,North Pakistan

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Global Geology 2021年第4期24卷 213-225页

作者： Shams M.Kamran WANG Pujun Nasar Khan Muhammad Hassan College of Earth Sciences Jilin UniversityChangchun 130061China Department of Geology University of MalakandChakdara 18800Khyber PakhtunkhwaPakistan

Black shales of the Paleocene Patala Formation are proven source rocks for conventional hydrocarbons in southern Potwar Basin of Pakistan and are assumed to be effective source rocks towards north in the Margalla Hill Range of Pakistan.In this regard,the current study focuses on source rock geochemistry of the Paleocene Patala Formation to assess its source rock potential,organic matter types and thermal maturity levels in the Margalla Hill Range of North Pakistan.Source rock generative potential,kerogen types and thermal maturation of the analysed rock samples were unraveled by using Rock-Eval pyrolysis T_(max),TOC(total organic carbon)and vitrinite reflectance(R_(0))analyses.TOC analysis coupled with S_(2) yield revealed poor to fair source rock quality encountered within the formation.The pyrolysis T_(max) vs Hydrogen Index(HI),showed mostly Type Ⅲ kerogen dominated by thermally immature to mature organic matter.The HI and genetic potential is low and revealed poor hydrocarbon generation potential of the formation.The S_(1) vs TOC plots confirm the indigenous nature of the hydrocarbons hosted by Patala Formation.The vitrinite reflectance outcomes indicated immature to mature source rock beds lying in dry gas zone.The HI and OI signatures and abundance of Type Ⅲ kerogen are indicating dominance of terrestrial organic matter within the formation.Overall,the investigated Patala Formation exposed at the studied section of Margalla Hill Range,Pakistan acts as a poor source rock unit for liquid hydrocarbon generation but holds prospects for dry gas generation in the study area.

关键词： Patala Formation organic geochemistry thermal maturity Margalla Hill Range North Pakistan eastern Tethys

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Reservoir Characteristics of Fine-grained Sedimentary Rocks in Saline Lakes in the Cenozoic Upper Ganchaigou Formation,Southwestern Qaidam Basin,NW China

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Acta Geologica Sinica(English Edition) 2022年第3期96卷 1070-1081页

作者： SHENG Jun LIU Jincheng LI Yunlong ZOU Haiyan LONG Anlin WANG Lin LI Jiyong QI Qingshan YANG Xiaojing LI Yanan Exploration&Development Research Institute of PetroChina Qinghai Oilfield Company DunhuangGansu 736200China No.2 Oil Production Plant of PetroChina Qinghai Oilfield Company DunhuangGansu 736200China No.1 Oil Production Plant of PetroChina Qinghai Oilfield Company DunhuangGansu 736200China

Cenozoic fine-grained sedimentary rocks in the southwestern Qaidam Basin,as typical salinized lacustrine sediments,are significantly different from those in other freshwater lakes under the impact of the high salinity in the lake.Many fine-grained sedimentary rock samples were selected from the lower member of Neogene(N_(1))in the Gaskule Oilfield,Qaidam Basin,northwest China,with the aim to analyze and test their petrology,pore structure,and organic geochemical characteristics and determine its genesis and geological significance.Based on previous results,a new genesis of mixed sedimentary rocks is proposed.The Cenozoic lacustrine fine-grained sedimentary rocks in SW Qaidam Basin belong to mixed sedimentary rocks,which can be divided into three types,including carbonate and terrigenous clastic-bearing mudstone,carbonate-bearing to terrigenous clastic mixed sedimentary rocks,and carbonate-terrigenous clastic mixed sedimentary rocks.The geneses of mixing are quite different from that of mixed marine rocks.According to the sedimentary characteristics of the salinized lakes,three new geneses of mixed deposits are proposed:syn-sedimentary mixing,varve interbedded mixing,and biogenic mixing.The reservoir spaces of the Cenozoic lacustrine fine-grained sedimentary rocks in SW Qaidam Basin include residual intergranular pores,intercrystalline pores,microfractures,and minor dissolved pores.The reservoirs have super-low porosity and ultra-low permeability,with a porosity of 1.82%-21.04%,averaging 7.71%,and permeability of(0.0028-254.86)×10^(−3)μm^(2),averaging 2.82×10^(−3)μm^(2).The test results of total organic carbon(TOC)content show that the highest content of organic carbon reached 1.41%,and those of vitrinite reflectance show that Ro ranges from 0.525%-0.824%,with an average of 0.806%.The organic geochemical characteristics show that the fine-grained mixed sedimentary rocks of SW Qaidam Basin have the potential for self-generation and self-storage.As an unconventional reservoir,it has potential industrial value.This i

关键词： energy resources unconventional reservoir sedimentary petrology organic geochemistry salinization lacustrine sediments Neogene

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Geochemical Characteristics and Origin of Crude Oil and Natural Gas in the Southern Slope Zone,Kuqa Foreland Basin,NW China

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Journal of Earth Science 2022年第3期33卷 820-830页

作者： Chun Liu Shijia Chen Jilong Zhao Zhou Su Hui Rong School of Geoscience and Technology Southwest Petroleum UniversityChengdu 610500China PetroChina Research Institute of Geology in Hangzhou Hangzhou 310023China Exploration and Development Research Institute PetroChina Tarim Oilfield CompanyKorla 841000China Key Laboratory of Tectonics and Petroleum Resources of Ministry of Education China University of GeosciencesWuhan 430074China

Continuous exploration has triggered a heated debate on hydrocarbon resource potential in the southern slope zone of the Kuqa foreland basin,and sources of the Mesozoic-Cenozoic oil and gas have become a key problem to be solved in this region.Composition and organic geochemical parameters of crude oil and natural gas from the southern slope zone of the Kuqa foreland basin were illustrated in order to reveal their origin by using a combination of gas chromatograph(GC),gas chromatogram-mass spectrum(GC-MS)and carbon isotope analyses.The characteristics of crude oil,such as low density,viscosity,solidification point and sulfur content,and high wax content,indicate that source of the crude oil is continental.The biomarker compositions of crude oil are characterized by low to medium molecular weight compounds(n-C_(12) to n-C_(20)),high Pr/Ph ratios(>1.0),low phytane/n-C18 ratios(0.06-0.54),and predominant regular sterane C_(29).All biomarker parameters clearly indicate that the crude oil was derived mainly from algae and aquatic plankton and deposited under weak reduction-oxidation environment,and has the characteristics of mixed kerogens.The Cretaceous crude oil was mainly derived from the Triassic lacustrine source rocks,which also contributed to the Paleogene crude oil together with Jurassic coal source rocks.Natural gas is characterized by moderate methane content,high heavy hydrocarbon and nitrogen content,and no hydrogen sulfide.The methane and ethane in Paleogene natural gas are relatively rich in ^(13)C withδ^(13)C_(1) andδ^(13)C_(2) values ranging from-37.3‰to-31.2‰(mean=-34.25‰)and from-25‰to-21.3‰(mean=-23.09‰),respectively,indicating the coal-derived gas from the Middle and Lower Jurassic strata.Hydrocarbon products in the southern slope zone of the Kuqa foreland basin are primarily generated from source rocks in the mature stage.The low-amplitude structural and lithologic traps with the updip pinch-out sand bodies or plugging secondary fault at relatively high tectonic positions are the most favorable ar

关键词： crude oil natural gas oil and gas source organic geochemistry Kuqa foreland basin

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Use of petrological and organic geochemical data in determining hydrocarbon generation potential of coals:miocene coals of Malatya Basin(Eastern Anatolia-Turkey)

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International Journal of Coal Science & Technology 2021年第4期8卷 510-533页

作者： Nazan Yalcin Erik Faruk Ay Department of Geological Engineering Cumhuriyet University58140 SivasTurkey Department of Anthropology Cumhuriyet University58140 SivasTurkey

With this study,the hydrocarbon generation potential of Miocene aged coals around Arguvan-Parçikan in the northern district of Malatya province was evaluated with the aid of petrological and organic geochemical data.According to organic petrography,coal quality data,and low thermal maturity,the Arguvan-Parçikan coals are of high-ash,high-sulfur subbituminous B/C rank.The organic fraction of the coals is mostly comprised of humic group macerals,with small percentages derived from the inertinite and liptinite groups.The mineral matter of the coals is comprised mainly of calcite and clay minerals.The total organic carbon(TOC,wt%)values of the shale and coal samples are between 2.61 wt%and 43.02 wt%,and the hydrogen index values are between 73 and 229 mg HC/g TOC.Pyrolysis(T_(max),PI),huminite/vitrinite reflectance(R_(o),%),and biomarker ratios CPI,Pr/Ph ratio,Ts/(Ts+Tm)ratio,C_(32) homohopane ratio(22S/22S+22R)and C_(29)ββ/(ββ+ααsterane ratio)indicate that the organic matter of the studied coals is thermally immature.When all these data are taken together,Miocene aged coals around Arguvan are suitable for hydrocarbon generation,especially gas,in terms of organic matter type(Type III and Type II/III mixed),organic matter amount(>10 wt%TOC),however,low liptinitic macerals(<15%–20%),low hydrogen index(<200 mg HC/g TOC)and low thermal maturity values inhibit the hyrocarbon generation.

关键词： Arguvan Malatya basin Eastern Anatolia organic geochemistry organic petrography Miocene coal

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Prospects of Carboniferous Shale Gas Exploitation in the Eastern Qaidam Basin

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Acta Geologica Sinica(English Edition) 2014年第2期88卷 620-634页

作者： LI Yingjie SUN Yanling ZHAO Yan CHANG Chun YU Qingchun MA Yinsheng School of Water Resources and Environment China University of Geosciences Institute of Geomechanics Chinese Academy of Geological Sciences

Shale gas is a resource of emerging importance in the energy field.Many countries in the world have been making big financial investments in this area.Carboniferous shale in the eastern Qaidam Basin shows good exploration prospects,but limited research and exploration work for shale oil and gas resources has been undertaken.Geochemical analyses were performed on shale derived from the Upper Carboniferous Hurleg Formation in the eastern Qaidam Basin,Qinghai Province,and secondary electron imaging capability of a Field Emission scanning electron microscope （FE-SEM） was used to characterize the microstructure of the shale.The reservoir and exploitation potential of the studied shale was assessed by comparison with research results obtained from the Barnett Formation shale in Fort Worth Basin,North America and the Basin shale of Sichuan province.The results indicate that the eastern Qaidam Basin Carboniferous shale is high-quality source rock.There are four major microstructural types in the study area：matrix intergranular pores,dissolution pores,intergranular pores,and micro-fractures.The size of the micropores varies from 6-633 nm,the majority of which is between 39-200 nm,with a relatively small number of micro-scale pores ranging from 0.13-1 μtm.The pore characteristics of the studied shales are similar to the North American and Sichuanese shales,indicating that they have good reservoir potential.No micropores are present in the organic matter,which is induced by its composition; instead we found an important lamellar structure in the organic matter.These micropores and microfractures are abundant,and are connected to natural visible cracks that form the network pore system,which controls the storage and migration of shale gas.This connectivity is favorable for shale gas exploitation,providing great scientific potential and practical value.

关键词： Scanning microscopy pore structure organic geochemistry Carboniferous shale gas Hurleg Formation Qinghai-Tibet plateau

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Characteristics of source rocks and paleoenvironment of Lower Silurian Longmaxi Formation in western Hubei

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Global Geology 2022年第4期25卷 264-276页

作者： WANG Neng DU Jiangfeng LIU Rong ZHANG Kun YAN Xu LIU Gaofei College of Earth Sciences Jilin UniversityChangchun 130061China CNOOC Research Institute Co. Ltd.Beijing 100028China School of Geographical Sciences Northeast Normal UniversityChangchun 130024China

Based on feild outcrop survey,lithology observation and systematic sampling,and with the scanning electron microscope,rock pyrolysis,biomarker compound test and analysis,this paper discussed source rock characteristics and paleoenvironment in western Hubei.The lithology at the bottom of Lower Silurian Longmaxi Formationn in this study area is mainly dark carbonaceous shale,the mineral composition is mostly clay minerals,quartz and feldspar,the content of illite and kaolinite is high,but also contains a minor amount of strawberry pyrite and graptolite fossils.The test and analysishow that the total organic carbon content(TOC)of the source rock is 0.8-6.32%,the average value is 3.42%,and the vitrinite reflectance(Ro)is 1.57-2.95%.The type of organic matter is mainly typeⅡ2.The overall abundance of organic matter is high,and the degree of thermal evolution has reached the stage of high maturity and over maturity.All these have become the good material basis and conditions for the formation of shale gas.The paleoenvironment of the source rocks indicates that the organic matter is a mixed source of planktonic algae and bacteria material.The large amount of hopane also indicates that the bacterial activity is strong during the deposition of organic matter;The water of the ancient lake is almost freshwater and brackishwater in some parts;The redox property of the water is in a strong reduction environment and with a stable stratification,which is also conducive to the preservation of organic matter.The above research results will provide the application of shale gas exploration in western Hubei.

关键词： source rock organic geochemistry paleoenvironment western Hubei Longmaxi Formation

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organic Geochemical and Fluid Inclusion Evidence for Filling Stages of Natural Gas and Bitumen in Volcanic Reservoir of Changling Faulted Depression,Southeastern Songliao Basin

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Journal of Earth Science 2010年第3期21卷 303-320页

作者：秦黎明张枝焕吴聿元冯如进昝灵 State Key Laboratory of Petroleum Source and Prospecting China University of Petroleum BeijingChina East China Branch of SINOPEC

Recently,volcanic gas reservoirs in Yaoyingtai （腰英台） and Daerhan （达尔罕） tectonic belts in Changling （长岭） faulted depression of southeastern Songliao （松辽） basin have been discovered.Based on the compositions and isotopic values,the natural gas is characterized by high content of methane,low content of C2＋,and C1/C1-5 beyond 0.95.Also,the natural gas contains nonhydrocarbons including carbon dioxide with the content from 20% to 40% and minor amount of N2.Combined with the isotopic values,the natural gas is generated by humic kerogen and coal-derived type,but in Daerhan,the natural gas is probably mixed by oil type gas.From the measurement of lithology and fluid inclusions in volcanic rocks,the bitumen,liquid hydrocarbon,and gas hydrocarbon inclusions are present.Through the analysis of the single gas inclusion in volcanic reservoir,the content of carbon dioxide is low,so the carbon dioxide and hydrocarbon gas of the reservoirs are not accumulated at the same time.In addition,minor amount of bitumen in the reservoirs is formed by thermal evolution of the crude oils sourced from the Yingcheng （营城） Formation mudstones through the characterizations of the biomarkers.The distribution of homogenization temperatures presents two peaks,one with the liquid hydrocarbon filling stage,and the other with gas filling stage.However,in Daerhan tectonic belt,the second peak is gas and carbon dioxide mixed filling period probably.Combined with the homogenization temperatures of salt water inclusions,the oil and gas filling period is from Qingshankou （青山口） Formation to Nenjiang （嫩江） Formation in the research area.During the charging period,minor amount of inorganic carbon dioxide filled into the trap,but plenty of inorganic carbon dioxide from the end of Sifangtai （四方台） to Eogene periods was related with the structural movement.

关键词： fluid inclusion organic geochemistry natural gas bitumen filling stage Changling faulted depression

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organic geochemical characteristics of bark coal in Changguang area: evidence from aromatic hydrocarbons

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International Journal of Coal Science & Technology 2020年第2期7卷 288-298页

作者： Yuhan Lin Shaoqing Wang Yuming Sha Kun Yang College of Geoscience and Surveying Engineering China University of Mining and TechnologyBeijingBeijing100083China

Seven coal samples were collected from Changguang area,a typical bark coal field in Zhejiang Province,China.The organic geochemical characteristics and depositional environment of bark coal were studied by Rock–Eval pyrolysis,gas chromatography(GC),and gas chromatography–mass spectrometry(GC–MS)analysis.The results show that all samples are type II kerogen.The values of total organic carbon(TOC),potential yield(S1+S2),and hydrogen index of these samples ranged from 65.80 wt%–87.00 wt%,170.43–232.89 mg HC/g,and 234–295 mg HC/g TOC,respectively.In aromatic hydrocarbons compounds of bark coal samples,the phenanthrene series occupy the largest proportion(43.48%–53.74%),followed by the dibenzothiophens(7.33%–16.53%).The distributions of naphthalenes,diphenyls,and chrysene of the samples indicate the source inputs are mainly derived from terrestrial higher plants.Furthermore,the ratios of naphthalene and phenanthrene series compounds reveal the samples are in the mature stage.Some biomarkers(Pr/Ph and C35/C31–35 homohopane),aromatic hydrocarbons(fluorene,dibenzofuran and dibenzothiophene),and high inertinite contents(14.7%–41.8%)suggest that bark coal was formed under relatively oxic conditions and was influenced by marine or brackish lakes environment.

关键词： Bark coal Aromatic hydrocarbon organic geochemistry Maturity

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