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A discussion on the upper limit of maturity for gas generation by marine kerogens and the utmost of gas generative potential:Taking the study on the tarim Basin as an example

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Science Bulletin 2007年第S1期 125-132页

作者： CHEN JianPing1,2, ZHAO WenZhi1, XIAO ZhongYao3, ZHANG ShuiChang1,2, DENG ChunPing1,2, SUN YongGe4 & WANG ZhaoMing3 1 research institute of petroleum exploration & development, petrochina, Beijing 100083, china 2 Key Lab of petroleum Geochemistry, CNPC, Beijing 100083, china 3 research institute of petroleum exploration & development, tarim oilfield company, petrochina, korla 841000, china 4 State Key Lab of Organic Geochemistry, Guangzhou institute of Geochemistry, Chinese Academy of Sciences, Guangzhou 510640, china

The experimental data yielded by Rock-Eval pyrolysis, kerogen atomic H/C, Py-GC and gold-tube sealing thermal simulation on the marine Cambrian-Ordovician source rock from the tarim Basin revealed that the upper limit of maturity for natural gas generation or the "deadline of gas generation" for marine types I and II kerogens is equal to 3.0% of vitrinite reflectance (Ro); while the "deadline of gas generation" for type III kerogens typically like coals is as high as 10% Ro. Thus, different organic matter has obviously different utmost maturities for gas generation. The mass-balance calculation by kerogen elements showed that when Ro>1.5%, the utmost amount of gas generation for the marine type II kerogen is less than 185 m3/t TOC, accounting for less than 30% of its total hydrocarbon generative potential; when Ro>2.0%, it becomes 110 m3/t TOC, less than 20% of the total hydrocarbon generative potential. The amount of the gas generative potential obtained by Rock-Eval is only around one tenth of the calculated value by the mass balance of kerogen elements at the same thermal evolutionary stage, while those by Py-GC and gold-tube sealing simulation are intervenient between the above two. The utmost of gas generative potential at the over 1.3% Ro stage is around 60―90 m3/t TOC, therefore, the amount of gas generation obtained by Rock-Eval is the minimum of gas generative potential, while that by the mass-balance calculation of kerogen elements is the maximum that the actual amount of gas generation should not exceed.

关键词： marine source rock kerogen maturity natural gas deadline of gas generation utmost of gas generative potential

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Geochemical characteristics and accumulation of marine oil and gas around Halahatang depression,tarim Basin,china

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Science china Earth Sciences 2008年第S1期51卷 195-206页

作者： LU YuHong,XIAO ZhongYao,GU QiaoYuan&ZHANG QiuCha research institute of exploration and development,tarim oilfield company,petrochina,korla 841000,china research institute of exploration and development Tarim Oilfield Company PetroChina Korla China

There exists a petroleum system rich of oil and gas around Halahatang depression,where the oil and gas possess obvious local distinctions of properties in different *** research proved that the discovered crude oil and natural gas in the region derived mainly from O2+3 source rock,and the differences of its properties were controlled by the oil and gas filling *** comprehensive study result shows the oil and gas reservoirs of the region mainly underwent three important accumulation phases:late Caledonian-Early Hercynian epoch,late Hercynian epoch,and Yanshan-Himalayan epoch. In the first phase,the oil and gas derived mostly from Cambrian source rock,which formed the primary ancient oil reservoirs,then suffered strong degradation and remained a great quantity of pyrobitumen in the high position of Tabei uplift in the *** the second phase,the O2+3 source rock of Manjia'er depression started its generation of hydrocarbon,which accumulated in the high position of Tabei uplift afterwards,and then biodegradated to heavy oil in the late Hercynian *** the last phase,the O2+3 source rock of southern Halahatang depression and margin of Manjia'er depression started its peak of generating liquid hydrocarbon,which mostly accumulated in the trap formed before the Indo-china and Yanshan epoch,and in somewhere the heavy oil suffered dilutions in various degrees or serious gas invading,to lead to obvious crude oil divergence.

关键词： marine facies Mid-Upper Ordovician source rock oil and gas source accumulation stage Halahatang depression tarim Basin

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Timing and history of marine hydrocarbon accumulation in tarim craton

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Chinese Science Bulletin 2002年第S1期47卷 120-127页

作者： ZHAO Jingzhou~(1,2) & LI Qiming~3 1. Department of petroleum Geology, Xi’an petroleum institute, Xi’an 710065, china 2. research institute of petroleum exploration and development, petrochina, Beijing 100083, china 3. tarim oilfield company, Kuerle, Xinjiang 841000, china Department of petroleum Geology Xi’an Petroleum Institute Xi’an China research institute of petroleum exploration and development PetroChina Beijing China tarim oilfield company Kuerle Xinjiang China

Based on the analyses of hydrocarbon inclu-sions, K-Ar dating of authigenic illites and oil/gas-watercontact retrospection as well as other methods, the marineprimary reservoirs in the cratonic region of the tarim Basinare found to have been formed in the late Caledonian toearly Hercynian, late Hercynian, and Himalayan, and oil andgas adjusted and redistributed in the Yanshanian (Jurassic toCretaceous) and Himalayan (Tertiary). The analyses alsoshow that the remaining primary oil accumulations aremostly formed in the late Hercynian, and the secondary oilreservoirs resulted from the adjustment and redistribution ofthe earlier accumulations during the Yanshanian and Hima-layan (especially late Himalayan), of which the Himalayan isalso the major stage of gas accumulation. The primary oilreservoirs formed in the late Hercynian mostly occur withinthe Paleozoic formation, whereas the secondary reservoirsformed in the Himalayan in the Mesozoic. The late adjust-ment and redistribution of reservoirs in the craton region ofthe tarim Basin is ubiquitous because of the intensified tec-tonic movements since the Mesozoic, especially Cenozoic andintrusion of the high- to over-mature gas. Furthermore, thelower amplitude of reservoirs in the craton region also makesthem easier to be adjusted and redistributed. Therefore, theremaining paleo-uplift and palaeo-slope developed in rela-tively stable tectonic regions are the main potential areas forthe middle-large marine reservoirs in the tarim Basin.

关键词： tarim Basin craton geochronology of hydrocarbon accumulation history of hydrocarbon accumulation marine reservoir primary reservoir secondary reservoir.

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Characteristics,genesis and accumulation history of natural gas in Hetianhe gasfield,tarim Basin,china

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Science china Earth Sciences 2008年第S1期51卷 84-95页

作者： WANG ZhaoMing 1 ,WANG QingHua 1 ,ZHAO MengJun 2 ,LI Yong 1 &XU ZhiMing 3 1 tarim oilfield company,petrochina,Kuerle 841000,china 2 research institute of petroleum exploration&development,petrochina,Beijing 100083,china 3 Southwest petroleum institute,Nanchong 637001,china tarim oilfield company PetroChina Kuerle China research institute of petroleum exploration & development PetroChina Beijing China Southwest petroleum institute Nanchong China

Hetianhe gasfield in Bachu region of the tarim Basin is mainly composed of three reservoir-caprock assembly,namely regional caprock of upper mudstone,middle mudstone and lower mudstone of the Carboniferous and reservoir of Bachu bioclastic limestone,glutenite and the Ordovician carbonate buried *** gas in Hetianhe gasfield sourced from the Cambrian source *** is thought that gases in Ma4 well block in the east of Hetianhe gasfield are mainly crude-oil cracked gases,while those in Ma3 and Ma8 well blocks in the west are the mixture gases of kerogen cracked gases and crude-oil cracked *** gas is rich in H2S and accumulated in multiply stages as the result of *** accumulation history is divided into three stages,namely accumulation and breakage in the late Caledonian-early Hercynian,migration and dissipation in the late Hercynian and accumulation in Himalayan. The main accumulation of reformed gas reservoir is in Himalayan.

关键词： gas characteristics gas genesis accumulation history Hetianhe gasfield tarim Basin

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Abnormal high pressure in Kuqa foreland thrust belt of tarim basin: Origin and impacts on hydrocarbon accumulation

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Progress in Natural Science:Materials International 2006年第12期16卷 1307-1314页

作者： ZENG Lianbo~1** and LIU Benming~ 1,2 (1. Key Laboratory of Hydrocarbon Accumulation in china petroleum University, Ministry of Education, Beijing 102249, china 2. The institute of Oil and Gas exploration and development, tarim oilfield company, petrochina company Limited, korla 841000, china) Key Laboratory of Hydrocarbon Accumulation in china Petroleum University Ministry of Education Beijing 102249 China The institute of Oil and Gas exploration and development Tarim Oilfield Company PetroChina Company Limited Korla 841000 China

Following analyses of the abnormal high pressure distribution characteristics, based on the geological characteristics, tectonic stress field and physical simulation, we investigated the formation mechanisms of abnormal high pressure and its impacts on hydrocarbon accumulation in the Kuqa foreland thrust belt. The abnormal high pressure appears at the bottom of the Paleogene and obviously exists in the Triassic and Jurassic. However, the pressure coefficient in the Triassic and Jurassic is lower than that in the Cretaceous and at the bottom of the Paleogene. Horizontally, the abnormal high pressure distribution is characterized by E-W orientation zoning. The maximum pressure coefficient lies in the Kelasu-Dongqiu-Dina tectonic zones in the center of the Kuqa foreland thrust belt and decreases away from the tectonic zones. The formation of abnormal high pressure was mainly related with the intense tectonic compression in the Early Pleistocene time, and tectonic uplifting, undercompaction and hydrocarbon generation were secondary factors contributing to abnormal high pressure. Under the rapid and intense tectonic compression in the Early Pleistocene, the rock framework firstly undertook 1/4 of the compression stress and the other was borne by the pore fluids. Due to the presence of great seal of gypsum-salt or gypsum-mudstone beds in the Paleogene, the pressure of pore fluids increased rapidly and led to the abnormal high pressure in the Kuqa foreland thrust belt. The abnormal high pressure has important impacts on hydrocarbon accumulation. It is one of the necessary conditions for formation of large oil and gas fields in the Kuqa foreland thrust belt.

关键词： abnormal high pressure formation mechanism oil and gas reservoir Kuqa foreland thrust belt tarim basin.

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Hydrogen isotopic compositions, distributions and source signals of individual n-alkanes for some typical crude oils in Lunnan oilfield, tarim Basin, NW china

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Science china Earth Sciences 2005年第8期48卷 1220-1226页

作者： LU Hong1, LI Chao1, SUN Yongge1, PENG Ping’an1 & XIAO Zhongyao2 1. State Key Laboratory of Organic Geochemistry, Guangzhou institute of Geochemistry, Chinese Academy of Sciences, Guangzhou510640, china 2. tarim research institute of exploration and development of petroleum, china petroleum, korla 841000, china State Key Laboratory of Organic Geochemistry Guangzhou Institute of Geochemistry Chinese Academy of Sciences Guangzhou China tarim research institute of exploration and development of petroleum China Petroleum Korla China

Isotopic compositions of carbon-bound hydrogen in individual n-alkanes from sev-eral typical crude oil samples from Lunnan oilfield, tarim Basin, NW china, were firstly measured using newly developed gas chromatography-thermal conversion-isotope ratio mass spectrometry. The similar range of δ D of individual n-alkanes of crude oils among reservoirs of different geo-logical times reflects that hydrocarbons are all derived from the same marine depositional envi-ronment. Compared to the theoretic value (?150‰) and the reported δ D values (nC13―nC27, ?160‰―?90‰) of individual n-alkanes for Ordovician-sourced crude oils in the Canadian Wil-liston Basin, the hydrogen isotopic composition of individual n-alkanes in crude oils from Lunnan oilfield is characterized by heavy hydrogen isotopic values (nC12―nC27, ?120‰―?60‰). In terms of the factors that control the fractionation of hydrogen isotopes, relatively saline deposi-tional environment and higher thermal maturation were attributed to the heavy δ D values of in-dividual n-alkanes in crude oils from Lunnan oilfield.

关键词： hydrogen isotopes, individual n-alkanes, distribution, hydrocarbon source, Lunnan oilfield.

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Mn content of reservoir calcite cement: A novel inorganic geotracer of secondary petroleum migration in the tectonically complex Junggar Basin (NW china)

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Science china Earth Sciences 2007年第12期50卷 1796-1809页

作者： CAO Jian1,HU WenXuan1,YAO SuPing1,ZHANG YiJie2,WANG XuLong3,ZHANG YueQian3,TANG Yong3 & SHI XinPu3 1 State Key Laboratory for Mineral Deposit research,Department of Earth Sciences,Nanjing University,Nanjing 210093,china 2 research institute of exploration and development,petrochina,Beijing 100083,china 3 research institute of exploration and development,petrochina Xinjiang oilfield company,Karamay 834000,china State Key Laboratory for Mineral Deposit research Department of Earth Sciences Nanjing University Nanjing China research institute of exploration and development PetroChina Beijing China research institute of exploration and development PetroChina Xinjiang Oilfield Company Karamay China

Electronic probe microanalysis(EPMA) results of reservoir calcite cement from fourteen core samples in the Junggar Basin show that Mn-content varies largely between different samples from below the detect limitation to 4.14%,while it displays a generally good correlation with oil-gas ***,therefore,likely indicates that concentration of the Mn-content of the calcite cement has a close rela-tion to the intensity of petroleum fluid charging during hydrocarbon secondary *** order to assess this hypothesis,oxygen and strontium isotopic measurements on sixteen calcite veins host in source sequences were carried out to investigate the feature of the oil-source petroleum *** results imply that during hydrocarbon generation and migration,deep hot fluid has dissolved volcanic minerals interlined between mudstone source *** Mn is a kind of typical trace element enriched in volcanic rocks,it is reasonable to conclude that the petroleum fluid formed in the source sequences would be ***,calcite cements precipitated from such Mn-rich petroleum fluid would be Mn-rich *** to the geologic chromatographic effect during migration along reservoir rocks,the decreasing of the Mn-content of the reservoir calcite cements indicates the migration ***,this novel geotracer was further successfully applied in the study of hydrocarbon migration in the Junggar Basin in combination with organic geochemical analyses during the hydrocarbon *** Mn content of the reservoir calcite cement appears promising as a novel inorganic geotracer for the petroleum *** paper represents a search for novel indicators of secondary petroleum migration in tectonically complex basins based on fundamentals of the reservoir fluid-rock interactions.

关键词： petroleum migration, inorganic geochemistry, water-rock interaction, reservoir calcite cement, the Junggar Basin

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Geochemical characteristics and origin of gases from the Upper,Lower Paleozoic and the Mesozoic reservoirs in the Ordos Basin,china

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Science china Earth Sciences 2008年第S1期51卷 183-194页

作者： HU AnPing 1 ,Li Jian 2 ,ZHANG WenZheng 3 ,LI ZhiSheng 2 ,HOU Lu 4 &LIU QuanYou 5 1 Department of Earth Sciences,Zhejiang University,Hangzhou 310027,china 2 Langfang Branch,Reasearch institute of petroleum exploration and development,petrochina,Langfang 065007,china 3 institute of exploration and development,petrochina Changqing oilfield company,Xi’an 710021,china 4 University of petroleum,Beijing102249,china 5 petrochina research institute of petroleum exploration and development,Beijing 100083,china Department of Earth Sciences Zhejiang University Hangzhou China Langfang Branch Reasearch Institute of Petroleum Exploration and Development PetroChina Langfang China institute of exploration and development PetroChina Changqing Oilfield Company Xi’an China University of petroleum Beijing China petrochina research institute of petroleum exploration and development Beijing China

The Ordos Basin,the second largest sedimentary basin in china,contains the broad distribution of natural gas *** far,several giant gas fields have been discovered in the Upper and Lower Paleozoic in this basin,each having over 1000×10 8 m 3 of proven gas reserves,and several gas pools have also been discovered in the *** paper collected the data of natural gases and elucidated the geochemical characteristics of gases from different reservoirs,and then discussed their *** hydrocarbons preserved in the Upper Paleozoic,the elevatedδ13C values of methane,ethane and propane indicate that the gases would be mainly coal-formed gases;the singular reversal in the stable carbon isotopes of gaseous alkanes suggests the mixed gases from humic sources with different *** the Lower Paleozoic,theδ13C 1 values are mostly similar with those in the Upper Paleozoic,but theδ13C 2 andδ13C 3 values are slightly lighter,suggesting that the gases would be mixing of coal-type gases as a main member and oil-type *** are multiple reversals in carbon isotopes for gaseous alkanes,especially abnormal reversal for methane and ethane(i.e.δ13C 1 >δ13C 2 ),inferring that gases would be mixed between high-mature coal-formed gases and oil-type *** the Mesozoic,the δ13Cvalues for gaseous alkanes are enriched in 12C,indicating that the gases are mainly derived from sapropelic sources;the carbon isotopic reversal for propane and butane in the Mesozoic is caused by microbial oxidation and mixing of gases from sapropelic sources with different *** contrast to the Upper Paleozoic gases,the Mesozoic gases are characterized by heavier carbon isotopes of iso-butane than normal butane,which may be caused by gases generated from different kerogen types. Finally,according toδ13C 1 -Ro relationship and extremely low total organic carbon contents,the Low Paleozoic gases would not be generated from the Ordovician source as a main gas source,bycontrast, the Upper Pale

关键词： Ordos Basin natural gas chemical composition carbon isotope genesis

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Two conceptual models of displacement transfer and examples

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Science china Earth Sciences 2005年第7期48卷 900-911页

作者： GUAN Shuwei1,2, WANG Xin2, YANG Shufeng2, HE Dengfa1 & ZHAO Weidong3 1. research institute of petroleum exploration and development, Beijing 100083, china 2. Department of Geosciences, Zhejiang University, Hangzhou 310027, china 3. tarim oilfield company, korla 841000, china research institute of petroleum exploration and development Beijing 100083 China Department of Geosciences Zhejiang University Hangzhou 310027 China tarim oilfield company Korla 841000 China

This paper presents two conceptual models of displacement transfer, reverse sym- metry model and infinitely equal division model, based on the fault-bend folding theory. If the fault shape is held constant in the trend, then the distribution of slip magnitude, geometry of imbricate structures and its axial surface map all display reverse symmetry on the process of displacement transfer, as called reverse symmetry model in this paper. However, if the ramp height of thrust fault decreases gradually along its strike, the displacement is postulated to be equally and infinitely divided to every thrust that is formed subsequently, this kinematic process is described using infinitely equal division model. In both models, displacement transfer is characterized by the regular changes of imbricate thrusting in the trend. Geometric analysis indicates that the displacement transfer grads can be estimated using the tangent of deflective angle of hinterland structures. Displacement transfer is often responsible for the distortion and branching of the surface anticlines, especially in the region where the multi-level detachment structures is developed. We also present some examples from the frontal structures of the Southern Tianshan fold-and-thrust belt, Xinjiang, china. Displacement transfer between deep imbricate thrusts in the middle segment of Qiulitag anticline zone causes the Kuqatawu and Southern Qiulitag deep an- ticlines left-lateral echelon. The region, where these two deep anticlines overlap, is characterized by duplex structures, and extends about 18 km. The shallow anticline is migrated southward displaying obvious “S” form in this area.

关键词： displacement transfer fault-bend folding reverse symmetry model infinitely equal division model Qiulitag zone.

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Present geotemperature and its suggestion to natural gas generation in Xujiaweizi fault-depression of the northern Songliao Basin

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Science china Earth Sciences 2008年第S1期51卷 207-220页

作者： ZHOU QingHua 1,2 ,FENG ZiHui 3 &MEN GuangTian 3 1 research institute of petroleum exploration and development,petrochina,Beijing 100083,china 2 Geological Logging Subcompany of Daqing Oil Field company Ltd.,Daqing 163411,china 3 research institute of petroleum exploration and development of Daqing Oil field company Ltd.,Daqing 163732,china research institute of petroleum exploration and development PetroChina Beijing China Geological Logging Subcompany of Daqing Oil Field company Ltd. Daqing China research institute of petroleum exploration and development of Daqing Oil field company Ltd. Daqing China

According to stastistic of present geotemperatures at the depths of 1000,2000,3000 and 4000 m,respectively in the Xujiaweizi fault-depression of the north Songliao Basin,the result indicates that Xujiaweizi fault-depression falls in the high geotemperature area,with the higher geothermal gradient in the depression layer than that in the fault-depression *** geothermal gradient decreases with the increasing of the *** thermal conductivity of rock greatly controls the geothermal *** main factors constraining the current geotemperature include thermal configuration of the earth's crust, deep faults,distribution and abundance of *** high geotemperature is in favour of generation of deep gas.

关键词： Xujiaweizi fault-depression geotemperature geothermal gradient thermal conductivity of rock deep layer natural gas

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