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含油砂体多组合油层注水开发压力恢复曲线解释

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石油学报 2002年第5期23卷 64-68页

作者：齐与峰盛建民中国石油勘探开发研究院北京100083

注水开发之后地下出现了许多新情况 ,因为井内各油砂体内注水受效程度千差万别。以叠加原理为基础而形成的求解方法不能把已观察到的情况纳入原始模型之中。为此 ,提出了一种新的解决方法 ,即 :先把系统在注采井距之半处分割 ,并设置为... 详细信息

注水开发之后地下出现了许多新情况 ,因为井内各油砂体内注水受效程度千差万别。以叠加原理为基础而形成的求解方法不能把已观察到的情况纳入原始模型之中。为此 ,提出了一种新的解决方法 ,即 :先把系统在注采井距之半处分割 ,并设置为外边界封闭条件 ;再把脱气油砂体、见水油砂体内的多相流动依据渗流力学原理化解为“扩充单相”流动。最后 ,把已观察到的新情况及分割、扩充后的结果一并纳入定解条件中去 ,经直接求解得到了压力恢复表达式。以此为基础 ,在多种条件下可计算出各自的曲线 ,为解释工作提供了理论依据。特别是文内提出的“第三段”应用方法。

关键词：含油砂体多组合油层注水开发压力恢复曲线解释计算公式

Discussion on marine source rocks thermal evolvement patterns in the Tarim Basin and Sichuan Basin,west china

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Science Bulletin 2007年第S1期 141-149页

作者： ZHANG Bin, ZHAO Zhe, ZHANG ShuiChang & CHEN JianPing Central Laboratory of petroleum Geology research, research institute of petroleum exploration and development, petrochina, beijing 100083, china

Taking marine source rocks of lower Paleozoic in the Tarim Basin and Paleozoic ones in the Sichuan Basin as examples, their sedimentation process could be classified into four styles: continuous subsidence with deep sedimentation in early stage, continuous subsidence with deep sedimentation in later stage, that deeply buried-uplift-shallowly buried, and that shallowly buried-uplift-deeply buried. Unlike that in East china, the marine source rocks evolvement patterns did not accord with sedimentation styles one by one in superimposed basins in west china. Taking local geothermal field into account, four types of source rock evolvement patterns were built: that evolved fast in early stage, evolved fast in middle stage, evolved continuously and evolved in multistage. Among them, the 1st pattern contributed little to the present industrial oil pools directly, but paleo-oil reservoirs and gases cracked from crude oils were main exploration targets. Although some gases were found in the 2nd pattern, the scale was not big enough. For the 3rd and 4th patterns, the hydrocarbon potential depended on organic matters maturity in early stage. For relatively low mature rocks, it was possible to generate some oils in later stage; otherwise the main products were gases. Paleo-oil reservoirs remained fairly well in the Sichuan Basin, and most source rocks underwent kerogen-oil-gas processes, which was useful reference to gas exploration in the Tarim Basin.

关键词： thermal evolvement patterns marine source rocks hydrocarbon potential sedimentary style superimposed basins

Preliminary study on the origin identification of natural gas by the parameters of light hydrocarbon

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Science china Earth Sciences 2008年第S1期51卷 131-139页

作者： HU GuoYi 1,2,3 ,LI Jian 1,2 ,LI Jin 1,2 ,LI ZhiSheng 1,2 ,LUO Xia 1,2 ,SUN QingWu 1,2 &MA ChengHua 1,2 1 research institute of petroleum exploration and development(Langfang Branch),petrochina,Langfang 065007,china 2 The Key Laboratory of Gas Formation and development,petrochina,Langfang 065007,china 3 College of Geo-Resources and Information,china University of petroleum,beijing 102200,china research institute of petroleum exploration and development (Langfang Branch) Petrochina Langfang China The Key Laboratory of Gas Formation and development Petrochina Langfang China College of Geo-Resources and Information China University of Petroleum Beijing China

The light hydrocarbon composition of 209 natural gas samples and individual light hydrocarbon carbon isotopes of 53 natural gas samples from typical humic-sourced gas and sapropelic-sourced gas in the four basins of china have been determined and *** identification parameters for humic-sourced gas and sapropelic-sourced gas are proposed or *** differences of compound-specificδ13C value of individual light hydrocarbon between humic-sourced gas and sapropelic-sourced gas have been *** humic-sourced gas has the distribution ofδ13C benzene > -24‰,δ13C toluene >-23‰,δ13C cyclohexane >-24‰andδ13C methyl cyclohexane >-24‰,while the sapropelicsourced gas has the distribution ofδ13C benzene 5%and relative content of MCH of more than 50%is humic-sourced *** components of C5-7 aliphatics, the gas with relative content of C5-7 normal alkane of more than 30%is sapropelic-sourced gas,while the gas with relative content of C5-7 normal alkane of less than 30%is humic-sourced *** paremeters have been suggested to identify humic-sourced gas and sapropelic-sourced gas.

关键词： natural gas humic-sourced gas sapropelic-sourced gas carbon isotope light hydrocarbon parameters

Formation and evolution of the Chinese marine basins

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Science Bulletin 2007年第S1期 1-11页

作者： JIA ChengZao1, LI BenLiang2, 3, ZHANG XingYang3 & LI ChuanXin1 1 research institute of petroleum exploration and development, petrochina, beijing 100083, china 2 Resources and Information institute, china University of petroleum, beijing 102249, china 3 Central Laboratory of petroleum Geology research, research institute of petroleum exploration and development, beijing 100083, china

There are plenty of petroleum resources in the Chinese marine basins, which will be the potential exploration regions of petroleum in the 21st century. The formation and evolution of the Chinese marine basins have mainly undergone two major tectonic epochs and five tectonic evolution stages. The first major tectonic epoch is the early Paleozoic plate divergence and drifting epoch during which the marine basins were formed, and the second one is the late Paleozoic plate convergence and collision epoch during which the pre-existent marine basins were superimposed and modified. The five tectonic evolution stages include: ① the drifting of micro-continental plates in Oceans and the formation of marine basins mainly filled with carbonate rocks during Proterozoic-Middle Carboniferous; ② the northward collage and convergence of continental plates and the development of the paralic sedimentary basins during Late Carboniferous-Middle Triassic; ③ the tectonically stabilized stage after the plate collage and the superimposition of lacustrine basins controlled by the inland subsidence during Late Triassic-Early Cretaceous; ④ the stage of the inland deformation and successive deep burial, uplifting, erosion or breakage of marine basins influenced by the plate tectonic activities of Neo-Tethys Ocean and the West Pacific developed in Late Cretaceous-Paleocene; ⑤ the stage of the foreland compression and basin-range coupling in the margin of the marine basins caused by the collision between India and Eurasia Plates and its long-distance effect since Neocene. The process of the tectonic evolution has controlled the petroleum geologic characteristics of Chinese marine basins, and a material foundation for the formation of oil and gas reservoirs has been built up via the formation of Paleozoic ma- rine basins, and the Mesozoic-Cenozoic tectonic superimposition and modification have controlled the key conditions of hydrocarbon accumulation and preservation. From the Late Proterozoic to

关键词： marine basin plate tectonics tectonics evolution petroleum exploration

Main controlling factors of distribution and genetics of marine reservoirs in china

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Science Bulletin 2007年第S1期 54-61页

作者： ZHU RuKai, GUO HongLi, GAO ZhiYong, WANG XueSong & ZHANG XingYang research institute of petroleum exploration and development, petrochina, beijing 100083, china

Marine reservoirs are mainly made up of clastics and carbonate reservoirs, which are distributed widely in central Tarim, Sichuan, Ordos basins from the Pre-Cambrian to Cenozoic, mainly in Palaeozoic. Marine clastic reservoirs are developed in foreshore and nearshore, tidal flat and delta environment. The sedimentary facies are important controlling factors for reservoir quality. Compaction, pressolution and cementation are factors of decreasing porosity, and low palaeo-temperature gradient, early emplacement of oil and gas and dissolution are favorable for preservation of pore. Carbonate reservoirs are divided into reef and bank, karst, dolomite and fracture reservoirs. Dolomitization, dissolution, TSR and fracture are important factors of controlling carbonate reservoirs’ quality.

关键词： marine carbonate reservoir clastic reservoir genetics

Effects of abnormally high heat stress on petroleum in reservoir——An example from the Tazhong 18 Well in the Tarim Basin

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Science china Earth Sciences 2008年第4期51卷 515-527页

作者： ZHU DongYa1, JIN ZhiJun1, HU WenXuan2 & ZHANG XueFeng3 1 petroleum exploration and Production institute, china petroleum & Chemical Corporation, beijing 100083, china 2 Department of Earth Sciences, Nanjing University, Nanjing 210093, china 3 School of Resource and Information, china University of petroleum, beijing 102249, china petroleum exploration and Production institute China Petroleum & Chemical Corporation Beijing China Department of Earth Sciences Nanjing University Nanjing China School of Resource and Information China University of Petroleum Beijing China

An igneous intrusion of 94m thick was discovered intruding into the Silurian sandstone from Tazhong 18 Well. The petroleum previously preserved in the Silurian sandstone reservoir was altered into black carbonaceous bitumen by abnormally high heat stress induced by the igneous intrusion. The reflec-tance of the carbonaceous bitumen reaches as high as 3.54%, indicating that the bitumen had evolved into a high thermal evolution level. Similar to the Silurian samples from the neighboring Tazhong 11, Tazhong 12, Tazhong 45 and Tazhong 47 wells, the distribution of C27, C28 and C29 steranes of the car-bonaceous bitumen is still "V" -shaped and can still be employed as an efficient parameter in oil source correlation. The "V" -shaped distribution indicates that the hydrocarbons from the Tazhong 18 and the neighboring wells were all generated from the Middle-Upper Ordovician hydrocarbon source rocks. However, the oil source correlation parameters associated with and terpanes had been changed greatly by the high heat stress and can no longer be used in oil source correlation. The δ 13C values of the pe-troleum from the neighboring wells are between -32.53‰ and -33.37‰, coincident with those of the Paleozoic marine petroleum in the Tarim Basin. However, the δ 13C values of the carbonaceous bitumen from the Tazhong 18 Well are between -27.18‰ and -29.26‰, isotopically much heavier than the pe-troleum from the neighboring wells. The content of light hydrocarbons (nC14-nC20) of the saturated hydrocarbon fraction in the carbonaceous bitumen is extremely higher than the content of heavy hy-drocarbons. The light/heavy hydrocarbon ratios (ΣnC21-/ΣnC22+) are between 4.56 and 39.17. In the saturated fraction, the even numbered hydrocarbons are predominant to the odd numbered, and the OEP (Odd to Even Predominance) values are between 0.22 and 0.49. However, the content of light hy-drocarbons in the petroleum from the neighboring wells is relatively low and the content of the even numb

关键词： Tarim Basin igneous intrusive abnormally high heat stress bitumen carbon isotope PAH

Effect and mechanism of stresses on rock permeability at different scales

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Science china Earth Sciences 2006年第7期49卷 714-723页

作者： YIN Shangxian1 & WANG Shangxu2 1. Safety Engineering College, North china institute of Science and Technology, Yanjiao, beijing 101601, china 2. Key Laboratory of Geophysics exploration, china University of petroleum, beijing 100083, china Safety Engineering College North China Institute of Science and Technology Yanjiao Beijing China Key Laboratory of Geophysics exploration China University of Petroleum Beijing China

The effect of geo-stress fields on macroscopic hydro-geological conditions or micro-cosmic permeability of water-bearing media should follow some laws or principles. Cases study and tests show that: (1) At macro-geologic large scale, deformed and crashed rocks which were induced by geo-stress fields changing provided space for groundwater storage and flow. Groundwater adjusts water-bearing space and dilatants fractures by flowing and press transferring. Coupling of liquid and solid can be implemented for rocks and groundwater. Although tectonic fields witness several times of change and build-up in geological time, stress fields forming regional tectonic framework are coherent with seepage fields, orientation of the maximum horizontal stress demonstrates main seepage direc-tions. (2) At macro-geologic middle scale, zones of stresses changing sharply, quite low stresses, stress or shear concentration can be used to show locations and types of main fractures, zones of geo-stresses changing equably can be acted as normal base media zones of tri-porosity media. (3) At micro-geologic small scale, tri-porosity media include fractured rocks, porous rocks and capillary rocks. Investigations indicate that porosity or permeability is functions of effective stresses, and po-rosity or permeability changing rules of porous rocks with variation of effective stresses can be de-scribed as the index model, the model of power exponent functions is suitable for those of fractured rocks, the model of the second power parabola for capillary rocks. The porosity and permeability loss in fractured rocks, which are greater than that in porous rocks, are shown by calculation of effective compressive coefficient and closing pressure in cracks. The calculations can also explain the mecha-nism why porosity changes are always larger than permeability changes. It is proved by the thick wall cylinder theory that the second power parabola relation between porosity or permeability loss and effective

关键词： geo-stress fields, seepage fields, tri-porosity media, effective stresses, permeability, porosity,scale.

APPlication and Derivation of Weng's Prediction Model

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天然气工业 1996年第2期16卷 97-99页

作者： Chen Yuanqian (research institute of petroleum exploration and development of CNPC) Li Chongri

In this paper,the generalized Weng’s prediction model is derived based on the x~2 distribution in the probability *** model may be used to predict production rate,recoverable reserves,annual maximum production rate and its occuring time. At the same time,a method of linear solution for the model is provided in this paper. Application of two actual oilfields indicates that the generalized Weng’s prediction model is very practical and efficient.

关键词： APPlication and Derivation of Weng’s Prediction Model

The Cretaceous tectonic event in the Qiangtang Basin and its implications for hydrocarbon accumulation

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petroleum Science 2010年第4期7卷 466-471页

作者： Li Yalin Wang Chengshan Li Yongtie Ma Chao Wang Licheng Peng Shaonan State Key Laboratory of Geological Processes and Mineral Resources research Center for Tibetan Plateau Geology China University of Geosciences Beijing 100083 China petroleum exploration and development research institute PetroChina Beijing 100083 China

The tectonic event during Cretaceous and its relationship with hydrocarbon accumulation in the Qiangtang Basin is discussed based on zircon U-Pb dating and the study of deformation, thermochronology and hydrocarbon formation. LA-ICPMS zircon U-Pb dating indicates that the tectonic event took place during the Early-Late Cretaceous （125-75Ma）. The event not only established the framework and the styles of structural traps in the basin, but also led to the cessation of the first hydrocarbon formation and the destruction of previous oil pools. The light crude oil in the basin was formed during the second hydrocarbon formation stage in the Cenozoic, and ancient structural traps formed during the Cretaceous event are promising targets for oil and gas exploration.

关键词： Qinghai-Tibet plateau Qiangtang Basin tectonic event Cretaceous hydrocarbon accumulation