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Influence of Ordovician carbonate reservoir beds in Tarim Basin by faulting

Science china Earth Sciences 2008年第S2期51卷 53-60页

作者： L XiuXiang1,2.YANG Ning1,2.ZHOU XinYuan3.YANG HaiJun3.& LI JianJiao1,2.1 Faculty of Natural Resource & Information Technology,{3. University of Petroleum,Beijing 102.49,{3. 2.State {2. laboratory of Petroleum Resource and Prospecting,{3. University of Petroleum,Beijing 102.49,{3. 3.Tarim oilfield,{13.,Korla 841000,{3. Faculty of Natural Resource & Information Technology China University of Petroleum Beijing China State key laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing China Tarim oilfield PetroChina Korla China

The quality of the Ordovician carbonate reservoir beds in the Tarim Basin is closely related to the development of secondary pores,fractures and cavities. Karstification is important in improving the properties of reservoir beds,and karstification related to unconformity has caught wide attention. Compared with the recent research on the unconformity karst reservoir bed improvement,this paper shows a new way of carbonate reservoir bed transformation. Based on field survey,core and slices observation,transformation of Ordovician carbonate reservoir beds by faulting can be classified into three types: (1) Secondary faults and fracturs generated by faulting improved carbonate reservoir bed properties,which were named the Lunnan or Tazhong82.model; (2. upflow of deep geothermal fluids caused by faulting,with some components metasomatizing with carbonate and forming some secon-dary deposit,such as fluorite. It can improve carbonate reservoir bed properties obviously and is named the Tazhong 82.model; and (3. the faulting extending up to the surface increased the depth of supergene karstification and the thickness of reservoir bed. It is named the Hetianhe model. Trans-formation effect of carbonate reservoir beds by faulting was very significant,mainly distributed on the slopes or on the edge or plunging end of the uplift.

关键词： carbonate faulting reservoir transformation Ordovician Tarim Basin

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Science china Earth Sciences 2004年第10期47卷 886-895页

作者： TANG Liangjie1,2. JIA Chengzao3. PI Xuejun4, CHEN Suping1,2. WANG Zhiyu5, XIE Huiwen4 1. key {3. for Hydrocarbon Accumulation of Education Ministry, Beijing 102.49, {2. 2. Basin & reservoir Research Center, University of Petroleum, Beijing 102.49, {2. 3. petrochina Company Limited, Beijing 100011, {2. 4. Tarim oilfield Company, petrochina Company Ltd., Kurle 841000, {2. 5. Department of Geology, University of Petroleum, Beijing 102.49, {2. key laboratory for Hydrocarbon Accumulation of Education Ministry Beijing China Basin & reservoir Research Center University of Petroleum Beijing China petrochina Company Limited Beijing China Tarim oilfield Company PetroChina Company Ltd. Kurle China Department of Geology University of Petroleum Beijing China

The salt beds of Lower Tertiary developed in the mid-segment of Kuqa foreland fold belt, northern Tarim basin. They considerably controlled structural deformation of the belt. Ac- cording to the field observation, seismic profile interpretation and drilling data, three different structural styles of supra-salt, intra-salt and sub-salt occurred in the Kuqa foreland fold belt. Su- pra-salt structural styles mainly include thrust faults and fault-related sags. Intra-slat structural styles essentially are salt-pillows, intra-salt faults and folds, and salt weld structures. Sub-salt structural styles mainly consist of imbricated thrust faults, duplex structures, pop-up and fault-related folds. It is indicated that great differences exist among supra-salt, intra-salt and sub-salt structures of Kuqa foreland fold belt. The salt-related structures were formed in the same structural stress field. The dynamic mechanism of the salt-related structures is mainly associated with gravitation, compression and plastic flow of salt beds.

关键词： salt-related structural style, supra-salt structure, intra-salt structure, sub-salt structure, Kuga foreland fold belt.

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A method of identifying effective source rocks and its application in the Bozhong Depression,Bohai Sea,china

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Petroleum Science 2010年第4期7卷 458-465页

作者： Jiang Fujie Pang Xiongqi Meng Qingyang Zhou Xiaohui Basin and reservoir Research Center China University of Petroleum Beijing 102249 China State key laboratory of Petroleum Resource and Prospecting Beijing 102249 China Research Institute of Petroleum Exploration and Development PetroChina Beijing 100083 China

Research on effective source rocks directly affects the accuracy of identifying hydrocarbon resources, and indirectly affects the exploration decisions in petroliferous basins. Although the previous evaluation methods of effective source rocks vary relatively widely, a complete quantitative evaluation approach has not yet been developed. For that reason, we redefined the concept of effective source rocks based on the existing research results. Surrounding this definition, and guided by the hydrocarbon expulsion theory, the quantitative model called ＂two stages and three steps＂ method is established to predict effective source rocks. Its application in the Bozhong Depression indicates that among the four sets source rocks in the Bozhong Depression, the Member 3.of the Shahejie Formation （Es 3.） has the largest effective source rock thickness, and the Member 1 Member 2.of the Shahejie Formation （Es 1＋2.） is the second largest .The effective part of dark mudstone is only 3.%-80% of the total volume and with the increase of buried depth and improvement of quality, the effective part increases. Comprehensive analysis indicates that the ＂two stages and three steps＂ method is a practical technique for effective source rock prediction.

关键词： Source rock effectiveness hydrocarbon expulsion threshold Bozhong Depression Bohai Sea

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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 2.0093.{2. 2.Research Institute of Exploration and Development,petrochina,Beijing 100083.{2. 3.Research Institute of Exploration and Development,petrochina Xinjiang oilfield Company,Karamay 83.000,{2. 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-{2. ***,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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Magnetic and mineralogical characteristics of reservoir rocks in the Yakela oil field, northern Tarim Basin and their implications for magnetic detection of oil and {3. accumulations

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Chinese Science Bulletin 1999年第2期44卷 174-177页

作者： LIU Qingsheng LIU ShugerDepartment of Applied Geophysics, china University of Geosciences, Wuhan 43.074, china The State {2. {3. of oil/gas reservoir Geology and Exploitation of china, Chengdu Institute of TechnologyChengdu 610059, china Department of Applied Geophysics China University of Geosciences Wuhan China The State key laboratory of {2./{3. reservoir Geology and Erploitation of china Chengdu Institute of Technology Chengdu China

The evidence about hydrocarbon migration within reservoir rocks in two wells has been obtained according to results of magnetic and mineralogical analysis of the Kapushaliang Group reservoir rocks from wells S15 and S4 located at the Yakela {2. field, Tarim Basin. Results show that the secondary alteration associated with {2. and gas accumulations above {2. and gas field is predominantly magnetite mineralization, and that sulfur alteration occurs commonly at {2.-water boundary and their products are generally pyrite and pyrrhotite, except for magnetite alteration which is closely related with hydrodynamical conditions in situ. The spherical magnetite grains of cauliflower microtexture on surface extracted from {2.-bearing cores are secondary magnetite related with hydrocarbon microseepage and their diameters are usually less than 50 μm.

关键词： hydrocarbon microseepage magnetic mineralogy magnetic hysteresis loop thermal magnetic analysis reservoir petrophysics.

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Late Yanshan-Himalayan hydrocarbon reservoir adjustment and hydrothermal fluid activity in the central Tarim Basin

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Science Bulletin 2007年第S1期 244-252页

作者： ZHANG XingYang1,2. ZHANG ShuiChang1, LUO Ping1,2. ZHU RuKai1,2. LUO Zhong1,2.& TU JianQi1 1 Central laboratory of Petroleum Geology Research, Research Institute of Petroleum Exploration and Development, petrochina, Beijing {2. china 2.key laboratory for oil and gas {13., petrochina, Beijing {2. china

The adjustment of primary hydrocarbon reservoirs in marine formations is an important feature of the oil pools in the Tarim Basin. Large-scale hydrocarbon adjustment is related to the strong regional tectonic movements, which is always accompanied by extensive migration of basin fluids including diagenetic and mineralizing fluids. Organic fluid inclusions are well developed in hydrothermal minerals, such as fluorite, which have been found in the dissolution-enlarged fractures or karstification caves in the Ordovician in the central Tarim Basin. Proved by well drilling, the fluorite deposit is good reservoir for oil and gas. So the peculiar accompanied or superimposed relationship between fluorite hydrothermal fluid mineralization and hydrocarbon migration and accumulation exists in the Ordovician in the central Tarim Basin. Considering regional tectonic setting and mineralization condition, through different kinds of analytic methods including electron spin resonance dating, fluid inclusion laser Raman and colonial inclusions hydrocarbon fossil analysis, we proposed that extensive mineralizing fluids and hydrocarbon migration occurred in late Yanshan-Himalayan (110.4―3..8 Ma) period, and Himalayan, especially, is an important period for hydrocarbon accumulation from 3..3.Ma to present.

关键词： hydrocarbon adjustment hydrothermal fluid activity basin fluids Himalayan period Tarim Basin

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The effects of temperature and acid number of crude oil on the wettability of acid volcanic reservoir rock from the Hailar oilfi eld

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Petroleum Science 2010年第1期7卷 93-99页

作者： Xie Quan He Shunli Pu Wanfeng key laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China State key laboratory of {2. and {3. reservoir Geology and Exploitation Southwest Petroleum University Chengdu Siehuan 610500 China

Wettability of acid volcanic reservoir rock from the Hailar oilfield, {2., was studied with crude oils of different acid numbers generated from an original crude oil with an acid number of 3.05 mg KOH/g. The modifed oils and their resultant acid numbers were： A （2.09 mg KOH/g）, B （0.75 mg KOH/g）, C （0.47 mg KOH/g）, D （0.3. mg KOH/g）, and E （0.18 mg KOH/g）. Contact angles and improved Amott water indexes were measured to study the effects of temperature and acid number on the wettability of the acid volcanic reservoir rock. Experimental results indicated that the wettability was not sensitive to variation in temperature when using the same oil, but the acid number of the crude oil was a key factor in changing the wettability of the rock. The Amott water index, Iw was an exponential function of the acid number, and the Amott water index increased as the acid number decreased （i.e. Amott water index exponentially decreased with the acid number increase）. The Iw value of the core saturated with oil A, with an acid number of 2.09 mg KOH/g, ranged from 0.06 to 0.11, which indicated low water wetness. If the acid number of the oil decreased to 0.18 mg KOH/g, the Iw value increased to 0.95, which indicated strong water wetness. The contact angle decreased from 80~ to 3.~ when the aid number decreased from 0.75 to 0.18 mg KOH/g, indicating a change towards more water wet conditions. The oil recovery by spontaneous imbibition of water also increased as the acid number of the oil decreased. As an example, at 80 ~C, the recovery of oil A with an acid number of 2.09 mg KOH/g was only 7.6%, while oil E with an acid number of 0.18 mg KOH/g produced 56.4%, i.e. an increase of 48.8%.

关键词： Acid volcanic reservoir rock Amott wettability index wetting angle temperature acid number wettability

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Characteristics,genesis and accumulation history of natural gas in Hetianhe gasfield,Tarim Basin,{2.

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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,{2. 2.Research Institute of Petroleum Exploration&Development,petrochina,Beijing 100083.{2. 3.Southwest Petroleum Institute,Nanchong 63.001,{2. 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 H{13. 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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Analysis of the ambiguity of log-constrained seismic impedance inversion

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Petroleum Science 2011年第2期8卷 151-156页

作者： Li Guofa Li Hao Ma Yanyan Xiong Jinliang State key laboratory of Petroleum Resources and Prospecting China University of Petroleum (Beijing) Beijing 102249 China key laboratory of Geophysical Prospecting China National Petroleum Corporation Beijing 102249 China Dagang oil field PetroChina Tianjin 300280 China

Although the ambiguity of seismic inversion is widely recognized in both theory and practice, so far as a concrete inversion example is concerned, there is not any objective, controllable method or any standard for how to evaluate and determine its ambiguity and reliability, especially for the high frequency components beyond the effective seismic frequency band. Taking log-constrained impedance inversion as an example, a new appraisal method is proposed on the basis of analyzing a simple geological model. Firstly, the inverted impedance model is transformed to a reflection coefficient series. Secondly, the maximum effective frequency of the real seismic data is chosen as a cutoff point and the reflection coefficient series is decomposed into two components by low-pass and high-pass filters. Thirdly, the geometrical reflection characteristics of the high-frequency components and that of the real seismic data are compared and analyzed. Then, the reliability of the inverted impedance model is appraised according to the similarity of geometrical characteristics between the high-frequency components and the real seismic data. The new method avoids some subjectivity in appraising the inverted result, and helps to enhance the reliability of reservoir prediction by impedance inversion technology.

关键词： Log-constrained impedance reflection coefficients seismic inversion ambiguity

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Total alkyl dibenzothiophenes content tracing the filling pathway of condensate reservoir in the Fushan Depression,South china Sea

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Science china Earth Sciences 2008年第S2期51卷 138-145页

作者： LI MeiJun1,WANG TieGuan1,LIU Ju2.ZHANG MeiZhu2.LU Hong3.MA QinLin2.& GAO LiHui2.1 State key laboratory of Petroleum Resources and Prospecting,Earth Sciences and Geoinformatics School,{2. University of Petroleum,Beijing 102.49,{2. 2.Southern oil Exploration and Development Company,petrochina,Guangzhou 510640,{2. 3.Guangzhou Institute of Geochemistry,Chinese Academy of Sciences,Guangzhou 5102.0,{2. State key laboratory of Petroleum Resources and Prospecting Earth Sciences and Geoinformatics School China University of Petroleum Beijing China Southern oil Exploration and Development Company PetroChina Guangzhou China Guangzhou Institute of Geochemistry Chinese Academy of Sciences Guangzhou China

The condensates are generally characterized by high maturity,low concentration of steranes and ter-panes biomarkers and low content of non-hydrocarbon fraction. In this case commonly used steranes,terpanes and carbazoles parameters cannot be effectively applied in the reservoir-filling tracing. The hydrogen bond formed by sulfur atom in the dibenzothiophenes (DBTs) results in molecule adsorption and fractionation during oil migration in reservoir. Like carbazoles,total DBTs content decreases with the increasing of oil migration distance. Therefore,a new parameter——total DBTs content is proposed to be used to trace the oil migration orientation and filling pathway. In present study,total DBTs con-tents of condensates and light oils are obtained by adding internal standard——eight deuterium atoms substituted DBT during gas Chromatography-Mass Spectrometry analysis of aromatic fraction. Except for a few samples with much lower content of non-hydrocarbon fraction,the total DBTs content shows a fine positive correlation with that of carbazoles. Large errors can be caused in the process of pyrrolic nitrogen compounds separation. The application of this new parameter in the Fushan Depression of Beibu Gulf Basin,South china Sea indicates that this parameter is a reliable one to trace filling pathway in condensate reservoirs. Combined with other DBTs-related parameters,such as 4-/1-methydibenzo-thiophene and 2.4-/1,4-dimethyldibenzothiophene,oil migration orientation and filling pathway of the Fushan Depression was determined. The accumulations of Huachang oil field in the Fushan Depres-sion are mainly migrated and charged from northeast to southeast along the Huachang uplift. It can be predicated that the light oil and condensates in the Huachang oil field should be sourced from the source kitchen at the Bailian Sag. It shows that total DBTs content is an effective parameter to tracing oil migration orientation and filling pathway.

关键词： dibenzothiophene alkyl dibenzothiophene condensate reservoir filling pathway molecular markers the Fushan Depression

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