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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 {2. of Petroleum exploration&Development,Petrochina,beijing 100083,china 3 Southwest Petroleum {2.,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 H2. 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

Effect of stress sensitivity on displacement efficiency in CO_2.flooding for fractured low permeability reservoirs

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Petroleum Science 2009年第3期6卷 277-283页

作者： Wang Rui Yue Xiang＇an Zhao Renbao Yan Pingxiang Dave Freeman Key Laboratory of Petroleum Engineering Ministry of Education China University of Petroleum Beijing 102249 China sinopec exploration ＆ {2. Research institute Beijing 100083 China china Power Complete Equipment Co. Ltd. Beijing 100011 China Edwy R. Brown Department of Petroleum Engineering Marietta College U.S.A.

Carbon dioxide flooding is an effective means of enhanced oil recovery for low permeability reservoirs. If fractures are present in the reservoir, CO2.may flow along the fractures, resulting in low gas displacement efficiency. Reservoir pore pressure will fluctuate to some extent during a CO2.flood, causing a change in effective confining pressure. The result is rock deformation and a reduction in permeability with the reduction in fracture permeability, causing increased flow resistance in the fracture space. Simultaneously, gas cross flowing along the fractures is partially restrained. In this work, the effect of stress changes on permeability was studied through a series of flow experiments. The change in the flowrate distribution in a matrix block and contained fracture with an increase in effective pressure were analyzed. The results lead to an implicit comparison which shows that permeability of fractured core decreases sharply with an increase in effective confining pressure. The fracture flowrate ratio declines and the matrix flowrate ratio increases. Fracture flow will partially divert to the matrix block with the increase in effective confining pressure, improving gas displacement efficiency.

关键词： Stress sensitivity flowrate distribution matrix fracture CO2.flooding displacement efficiency

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 102.49, 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.

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,china 2.Research institute of {2. and Development,Petrochina,beijing 100083,china 3 Research institute of {2. 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

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,Petro{2.,beijing 100083,{2. 2.Geological Logging Subcompany of Daqing Oil Field Company Ltd.,Daqing 163411,{2. 3 Research institute of Petroleum exploration and Development of Daqing Oil field Company Ltd.,Daqing 163732.{2. 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 1000,2.00,3000 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

TTHE METHODOLOGY OF PETROLEUM DEVELOPMENT GEOLOGY(Ⅲ)

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石油勘探与开发 1996年第4期 78-82页

作者： Qiu Yinan (Research institute of Petroleum exploration and Development, CNPC, {2., 100083, P.R.china)

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Controlling Factors Affecting Pressure Differential Development of the Upper Paleozoic Gas Reservoir in the Sulige and Yulin Area of the Ordos Basin

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地学前缘 2009年第S1期16卷 126-127页

作者： Hao Xu~1,Junfeng Zhang~2.Chengzao Jia~3,Dazhen Tang~1,Ming Li~3,Wenzhong Zhang~1 1.Key Laboratory of Marine Reservoir Evolution and Hydrocarbon Accumulation Mechanism,Ministry of Education,china University of Geosciences(beijing),{2.,china. 2.Petrochina exploration and production Company,beijing 10072.,china 3.Research institute of Petroleum exploration & Development,{2.,china

The origin and distribution of Upper Paleozoic reservoirs pressure in mid-northem Ordos Basin has attracted widespread attention in recent *** reservoir pressure of Sulige area shows characteristics of basically subnormal pressure,and the reservoir pressure of Yulin area shows characteristics of basically normal hydrostatic *** the sense of structural location,

关键词： Ordos Basin Sulige area Yulin area formation pressure controlling factors

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 2.0093, china 2. Research institute of {2. and Development, Petrochina, Bei- jing 100083, china 3. Research institute of {2. and Development, Xinjiang Oilfield Company, Petrochina, 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 Xinjiang Oilfield Company PetroChina Karamay 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.

Petrophysical and capillary pressure properties of the upper Triassic Xujiahe Formation tight gas sandstones in western Sichuan,china

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Petroleum Science 2011年第1期8卷 34-42页

作者： Ye Sujuan Lu Zhengxiang Li Rong exploration and production Research {2. Sinopec Southwest CompanySichuan 610081China Chengdu institute of Geology and Mineral Resources Sichuan 610081China

The tight sandstones of the Upper Triassic Xujiahe Formation（T_3x） constitute important gas reservoirs in western *** Xujiahe sandstones are characterized by low to very low porosity （av.5.2.%and 3.62.） for the T_3x^4 and T_3x^2.sandstones,respectively）,extremely low permeability（av. 0.060 mD and 0.058 mD for the T_3x^4 and T_3x^2.sandstones,respectively）,strong heterogeneity,micronano pore throat,and poor pore throat *** a result of complex pore structure and the occurrence of fractures,weak correlations exist between petrophysical properties and pore throat size,demonstrating that porosity or pore throat size alone does not serve as a good permeability *** improved correlations can be obtained between permeability and porosity when pore throat radii are incorporated. Correlations between porosity,permeability,and pore throat radii corresponding to different saturations of mercury were established,showing that the pore throat radius at 2.%mercury saturation（R_（2.）） is the best permeability *** regression analysis and artificial neural network（ANN） methods were used to establish permeability prediction models and the unique characteristics of neural networks enable them to be more successful in predicting permeability than the multivariate regression *** addition, four petrophysical rock types can be identified based on the distributions of R_（2.）,each exhibiting distinct petrophysical properties and corresponding to different flow units.

关键词： Western Sichuan upper Triassic Xujiahe Formation tight sandstones permeability porosity pore throat radius regression analysis artificial neural network