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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 {1. of Petroleum exploration and development,PetroChina,Beijing 1.0083,China 2 Geological Logging Subcompany of daqing Oil Field Company Ltd.,daqing 1.341.,China 3 research {1. of Petroleum exploration and development of daqing Oil field Company Ltd.,daqing 1.3732,China PetroChina Res Inst Petr Explorat & Dev Beijing 100083 Peoples R China daqing Oil Field Co Ltd Geol Logging Subco Daqing 163411 Peoples R China daqing Oil field Co Ltd Res Inst Petr Explorat & Dev Dacling 163732 Peoples R China

According to stastistic of present geotemperatures at the depths of 1.00,2000,3000 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

Transition from platemargin to intraplate environment: Geochemistry of basalts in Paleogene Liaohe basin, northeastern China

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Science China Earth Sciences 2005年第12期48卷 2069-2080页

作者： WU Changzhi1. GU Lianxing1. REN Zuowei1.2, ZHANG Zunzhong1. CHEN Zhenyan2 & ZHAO Ming1.1. State Key Laboratory of Mineral Deposit research (Nanjing University), Department of Earth Sciences, Nanjing University, Nanjing 21.093, China 2. {1. and development research institute of Liaohe oilfield Branch Company, PetroChina, Panjin 1.401., China 1. State Key Laboratory of Mineral Deposit research (Nanjing University) Department of Earth Sciences Nanjing University 210093 Nanjing China 2. exploration and {1. research institute of Liaohe oilfield Branch Company PetroChina 124010 Panjin China

Paleogene basalts from the Liaohe basin, northeastern China, are dominated by alkaline olivine basalts and olivine basalts. These basalts are generally enriched in high field strength elements (HFSE), depleted in large ion lithophile elements (LILE) and comparable to those of typical ocean island basalts (OIB). Positive anomalies of Ba, Sr and Zr with high Nb/U, U/Pb, Ce/Pb and Zr/Hf ratios imply that materials from an oceanic crust had been added to the mantle sources of the basalts. In addition, the basalts are generally depleted in Sr, Nd and Pb isotopes, indicating that an enriched mantle (EMI) and a depleted mantle (DM) sources were added to the OIB-like resource. Comprehensive research on lithosphere evolution and tectonic setting of the Liaohe basin and surrounding areas suggests that these basalts were derived by variable degrees of partial melt-ing from an upwelling asthenosphere mantle. Materials from an oceanic lithosphere were added to the source in company with Paleogene tectonic transition from platemargin to intraplate envi-ronment. Retreating and steepening of the subducting Pacific oceanic plate could be the main cause for the tectonic environment transition.

关键词： geochemistry, basalt, Paleogene, Liaohe basin, North China Block, eastern China.

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 1.2249, China 2. The institute of Oil and Gas {1. and development, Tarim oilfield Company, PetroChina Company Limited, Korla 841.00, China) [a]Ministry of Education Key Laboratory of Hydrocarbon Accumulation in China Petroleum University Beijing China [b]The institute of Oil and Gas {1. and development Tarim Oilfield Company PetroChina Company Limited Korla 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.

Detection of water in petroleum inclusions and its implications

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Science Bulletin 2006年第12期51卷 1501-1507页

作者： CAO Jian1. YAO Suping1. HU Wenxuan1. ZHANG Yijie2, WANG Xulong3, ZHANG Yueqian3 & TANG Yong3 1. State Key Laboratory for Mineral Deposit research, Department of Earth Sciences, Nanjing University, Nanjing 21.093, China 2. research institute of exploration and development, PetroChina, Bei- jing 1.0083, China 3. research institute of exploration and development, Xinjiang oilfield Company, PetroChina, Karamay 834000, China State Key Laboratory for Mineral Deposit research Department of Earth Sciences Nanjing University Nanjing 210093 China research {1. of exploration and development PetroChina Beijing 100083 China research {1. of exploration and development Xinjiang Oilfield Company PetroChina Karamay 834000 China

FTIR spectra of inclusions sampled from fault-zone reservoirs of the northwestern Junggar Basin show that water, with different abundances, does exist in petroleum inclusions. It is thus implied that petroleum inclusions can seldom form without water. Different inclusions hosted in one single grain, and formed in one oil charging phase, have a largely varied ratio of water to oil and slightly changed CH3/CH2 ratio. This likely provides evidence for fault-related episodic migration and accumulation of hydrocarbons.

关键词： water in petroleum inclusions forming mechanism of inclusions episodic migration and accumulation of hydrocarbons FTIR microspectroscopy Junggar Basin.

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, Guangzhou51.640, China 2. Tarim {1. institute of exploration and development of Petroleum, China Petroleum, Korla 841.00, China 1. State Key Laboratory of Organic Geochemistry Guangzhou Institute of Geochemistry Chinese Academy of Sciences 510640 Guangzhou China 2. Tarim research {1. of exploration and development of Petroleum China Petroleum 841000 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 (?1.0‰) and the reported δ D values (nC1.―nC27, ?1.0‰―?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 (nC1.―nC27, ?1.0‰―?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.

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 71.065, China 2. {1. institute of Petroleum exploration and development, PetroChina, Beijing 1.0083, China 3. Tarim oilfield Company, Kuerle, Xinjiang 841.00, China Xian Petr Inst Dept Petr Geol Xian 710065 Peoples R China PetroChina Res Inst Petr Explorat & Dev Beijing 100083 Peoples R China Tarim oilfield Co Xinjiang 841000 Peoples R 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.

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 21.093,China 2 research institute of exploration and development,PetroChina,Beijing 1.0083,China 3 research institute of exploration and development,PetroChina Xinjiang oilfield Company,Karamay 834000,China 1. State Key Laboratory for Mineral Deposit research Department of Earth Sciences Nanjing University Nanjing 210093 China 2. research {1. of exploration and development PetroChina Beijing 100083 China 3. research {1. of exploration and development PetroChina Xinjiang Oilfield Company Karamay 834000 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 4.1.%,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

Characteristics of remaining oil viscosity in water-and polymer-flooding reservoirs in daqing {1.

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Science China Earth Sciences 2010年第12期53卷 72-83页

作者： XU ZhengShun,ZHANG JuHe,FENG ZiHui,FANG Wei & WANG FengLan exploration and {1. research institute,daqing oilfield Company Ltd.,daqing 1.371.,China 1. exploration and {1. research institute Daqing Oilfield Company Ltd. Daqing 163712 China

The experimental analysis of 21.crude oil samples shows a good correlation between high molecular-weight hydrocarbon components (C 40+) and ***-four remaining oil samples extracted from oil sands of oilfield {1. coring wells were analyzed by high-temperature gas chromatography (HTGC),for the relative abundance of C 21.,C 21.C 40 and C 40+ *** relationship between viscosity of crude oil and C 40+ (%) hydrocarbons abundance is used to expect the viscosity of remaining *** mobility characteristics of remaining oil,the properties of remaining oil,and the next displacement methods in reservoirs either water-flooded or polymer-flooded are studied with rock permeability,oil saturation of coring wells,*** experimental results show that the hydrocarbons composition,viscosity,and mobility of remaining oil from both polymer-flooding and water-flooding reservoirs are heterogeneous,especially the *** abundance of C 21. and C 21.C 40 hydrocarbons in polymer-flooding reservoirs is lower than that of water-flooding,but with more abundance of C 40+ *** is then suggested that polymer flooding must have driven more C 40- hydrocarbons out of reservoir,which resulted in relatively enriched C 40+,more viscous oils,and poorer *** oil in water-flooding reservoirs is dominated by moderate viscosity oil with some low viscosity oil,while polymer-flooding mainly contained moderate viscosity oil with some high viscosity *** each oilfield and reservoir,displacement methods of remaining oil,viscosity,and concentration by polymer-solution can be adjusted by current viscosity of remaining oil and mobility ratio in a favorable range.A new basis and methods are suggested for the further {1. and enhanced oil recovery of remaining oil.

关键词： remaining oil viscosity mobility ratio water-flooding polymer-flooding heterogeneity polymer-solution viscosity

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Quantitative studies of hydrocarbon loss of the Silurian bitumen sandstone in the Tarim Basin

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Science China Earth Sciences 2008年第S2期51卷 101-107页

作者： JIANG ZhenXue1.2,PANG XiongQi1.2,LIU LuoFu1.2,WANG XianDong3,ZHANG Jun4 & LI HongYi1.2 1.Basin and Reservoir research Center,China University of Petroleum,Beijing 1.2249,China 2 State Key Laboratory of Petroleum Resource and Prospecting,China University of Petroleum,Beijing 1.2249,China 3 research institute of exploration and development,daqing oilfield Company Ltd,daqing 1.371.,China 4 Petroleum exploration and Production institute of SINOPEC,Beijing 1.0083,China China Univ Petr Basin & Reservoir Res Ctr Beijing 102249 Peoples R China China Univ Petr State Key Lab Petr Resource & Prospecting Beijing 102249 Peoples R China daqing {1. Co Ltd Res Inst Explorat & Dev Daqing 163712 Peoples R China SINOPEC Petr Explorat & Prod Inst Beijing 100083 Peoples R China

The evolution of Tarim Basin experienced several tectonic movements,of which Caledonian movement caused a serious damage to reservoirs of Silurian. The earlier reservoirs size and the later hydrocarbon loss are two key factors to exploration prospect of Silurian. On the basis of net thickness of bituminous sandstone and recovery coefficient of crude oil converting to bitumen,the scale of the hydrocarbon loss of palaeo-accumulation in bitumen sandstone of Silurian was calculated (86.30×1.8t). The deter-mination of net thickness of bitumen sandstone was completed mainly by several methods,such as physical property demarcation,observing lithology,grains with oil inclusion (GOI) technology,and quantitative grains fluorescence (QGF) technology. The samples of black sandstone and white sand-stone were collected and compared by means of the methods mentioned above. The results showed that there was little hydrocarbon,or none,in the white sandstone. The recovery coefficient was ob-tained by the analyses of plentiful physical parameters of crude oil and bitumen sandstone,based on the hypothesis that nonhydrocarbon compounds and bitumen were invariable in the process of bitu-men forming. The calculated result,which is more scientific and actual,indicates the exploration pros-pect is more promising in Silurian of the Tarim Basin.

关键词： Tarim Basin Silurian bitumen sandstone hydrocarbon loss quantitative research recovery coefficient