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Application of C5-C13.light hydrocarbons in depositional environment diagnosis

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Progress in Natural Science:Materials International 2008年第9期18卷 1129-1137页

作者： Peirong Wanga,b,, Guanjun Xu a,c, Tingrong xiaoc, Dajiang Zhanga,c, Bin Zhanga,c a Key Laboratory of Petroleum Geochemistry, china National Petroleum Corporation, Beijing 100083. china b Department of Organic Geochemistry, Yangtze University, Jingzhou 43.023. china c Central Laboratory of Petroleum Geology, {3. institute of Petroleum exploration and development, petrochina, Beijing 100083. china Key Laboratory of Petroleum Geochemistry China National Petroleum Corporation Beijing 100083 China Department of Organic Geochemistry Yangtze University Jingzhou 434023 China Central Laboratory of Petroleum Geology Research Institute of Petroleum Exploration and Development PetroChina Beijing 100083 China

Based on the geological background and Gammacerane/C3.H(S + R) ratios, source rock depositional environments of the studied oil samples (194) from 13.oilfields were classified into three groups according to salinity:saline-lacustrine facies, fresh to brackish lacustrine facies (including limnetic facies), and semi-saline to saline facies (including marine facies of the Tarim Basin).C5-C13.compound groups in the crude oils were separated by GC, and about 286 compounds were qualitatively *** geochemical application of the C6-C13.compound groups and their ratios between each group with individual carbon number was *** studies show that (1) C6-C13.compound groups and their ratios in the crude oils could serve as new reliable parameters for oil-oil correlation because the C6-C13.light fractions are the major oil component, especially in light oil or condensate, in which they account for almost 90% of the whole oil;(2) the compound groups of C7 light hydrocarbons in oils derived from difierent depositional environments with difierent salinity have difierent characteristics;(3. C6-C13.compound groups and ratios may be afiected by other factors such as maturity, but they are mainly controlled by salinity of depositional waters.

关键词： Light hydrocarbons Crude oil Depositional environment Salinity

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 & {3., petrochina, Beijing 100083. china 2 Key Lab of Petroleum Geochemistry, CNPC, Beijing 100083. china 3.research institute of Petroleum exploration & {3., 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 3.% 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

Interfacial properties of Daqing crude oil-alkaline system

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Petroleum Science 2011年第1期8卷 93-98页

作者： LIN Mei-qin XU Xue-qin LV Jing Zong Hua LI Ming-yuan DONG Zhao-xia Enhanced Oil Recovery research Center China University of PetroleumBeijing 102249China research institute of Petroleum exploration ＆ {3. PetroChinaBeijing 100083China Shengli Engineering ＆ Consulting Co. Ltd.SINOPECDongyingShangdong 257026China

The oil/water interfacial properties of crude oil emulsions formed by alkaline/surfactant/ polymer（ASP） flooding in the Daqing Oilfield were investigated in this paper by the measurement of interfacial tension,interfacial shear viscosity and Zeta potential of the oil/water *** result showed that both NaOH and Na_2CO_3.could react with acid substances in the crude oil to produce interfacially active components,which are adsorbed on the interfaces between the aqueous phase and oil phase, resulting in a decrease of the interfacial tension,negatively charging the surface of oil droplets,but making little change in the interfacial shear *** the same ionic strength of NaOH and Na_2CO_3. the interfacial tension of NaOH solution-crude oil system is lower,but the interfacial shear viscosity of NaOH solution-crude oil system is higher,than that of Na_2CO_3.solution-crude oil *** negative value of the Zeta potential on the surface of the oil droplets is ***,the O/W emulsion of NaOH solution-crude oil system is more stable than that of Na_2CO_3.solution-crude oil system.

关键词： Alkali interfacial tension interfacial shear viscosity Zeta potential turbidity

developmental modes of the Neoproterozoic-Lower Paleozoic marine hydrocarbon source rocks in china

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Science Bulletin 2007年第S1期 77-91页

作者： ZHANG BaoMin1, ZHANG ShuiChang1, BIAN LiZeng2, JIN ZhiJun3.& WANG DaRui1 1 research Center of Petroleum Geology in research institute of Petroleum {3. and development, petrochina, Beijing 100083. china 2 Department of Earth Sciences, Nanjing University, Nanjing 210093. china 3.research institute of Petroleum {3. and development, Sinopec, Beijing 100083. china

Based on the researches on rock type, the mode of occurrence, diagnostic minerals and creatures, the sedimentary geochemistry and organic facies of Chinese marine source rocks from wells and outcrops, and on the research findings of developmental modes of foreign marine source rock, the authors consider that it is impossible to objectively make clear the formation mechanism of hydrocarbon source rock with high organic matter abundance by either single mode of preservation or high organic matter productivity. According to the Chinese geological features, the formation mechanism of the Neoproterozoic-Lower Paleozoic marine source rock is generalized into four modes, namely, thermal water activity-upwelling flow-anoxic; carbonate gentle slope-upwelling flow; xerothermic climate-brine euxinic milieu; and humid climate-retained euxinic milieu; as the Lower Cambrian undercompensation basin organic facies (the Tarim Basin, South {3. and southwestern margin of North {3.), carbonate gentle lime mud bound organic facies (the Upper Ordovician in Tazhong region of the Tarim Basin and the Lower Silurian in the Upper Yangtze Platform), the Middle Cambrian evaporation laggon organic facies (the Tarim Basin and the Upper Yangtze Platform), enclosed undercompensation terrigenous bay organic facies (the Middle-Upper Ordovician in the west of the Tarim Basin, the Lower Silurian Longmaxi Formation in the Upper Yangtze platform). Chinese marine sedimentations with lower organic matter abundance are generalized into two modes of consumption-dilution mode of open epicontinental sea and depletion-dilution mode of supercompensation basin.

关键词： marine source rock upwelling flow anoxic event thermal water activity xerothermic climate-brine euxinic humid climate-retained euxinic

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酒西坳陷天然气的地球化学特征及成因

新疆石油地质 2004年第3期25卷 259-261页

作者：高波程克明熊英杨智明中国石化石油勘探开发科学研究院北京100083 中国石油石油勘探开发科学研究院北京100083 中国石油玉门油田分公司勘探开发研究院甘肃玉门735200

对酒西坳陷天然气的地球化学特征进行了较为详细的研究。研究表明,酒西坳陷的天然气组分以烃类气体为主,质量分数91.82%～99.22%,平均为96.15%.其中,甲烷质量分数68.85%～85.13.,平均为75.81%.重烃含量较高,平均质量分数20.3.%,C1/C1-5... 详细信息

对酒西坳陷天然气的地球化学特征进行了较为详细的研究。研究表明,酒西坳陷的天然气组分以烃类气体为主,质量分数91.82%～99.22%,平均为96.15%.其中,甲烷质量分数68.85%～85.13.,平均为75.81%.重烃含量较高,平均质量分数20.3.%,C1/C1-5为0.75～0.87,属典型的湿气;非烃气体主要为CO2,质量分数0.78%～8.18%,平均为3.85%.天然气的δ13.1值为-45.3.～-40.2‰,平均值为-41.94‰;δ13.2为-3..1‰～-28.4‰,平均值为-3..27‰;δ13.3.-28.6‰～-26.9‰,平均值为-27.6‰,δ13.13.23.3.因此为典型的油型气。

关键词：天然气地球化学酒西坳陷碳同位素油型气

用层序地层学构建辫状河三角洲岩性油藏地质模型

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石油学报 2004年第5期25卷 29-33页

作者：方杰赵力民赵太良刘建军中国石油勘探开发研究院北京100083 华北油田勘探开发研究院河北任丘062552

近期在冀中坳陷饶阳凹陷留西地区下第三系沙三段新发现的岩性油藏是较典型的辫状河三角洲砂岩岩性油藏。应用层序地层学原理 ,对该地区层序地层进行了划分 ,建立了地震等时格架。综合分析各项资料结果表明 :留西地区下第三系沙三段为一... 详细信息

近期在冀中坳陷饶阳凹陷留西地区下第三系沙三段新发现的岩性油藏是较典型的辫状河三角洲砂岩岩性油藏。应用层序地层学原理 ,对该地区层序地层进行了划分 ,建立了地震等时格架。综合分析各项资料结果表明 :留西地区下第三系沙三段为一个三级层序 ,发育低位、湖侵和高位 3.完整的体系域。通过大量的岩心观察、岩电组合特征分析和识别 ,将辫状河三角洲前缘亚相划分出分流水道、分流河口坝和楔状砂等沉积微相。用Jason等多种地震反演方法识别出辫状河三角洲的平面形态和空间展布 ,预测出辫状河三角洲的前缘亚相的储集性能 ,指出了有利的储集相带。对留西地区辫状河三角洲砂体形成的沉积环境、构造背景、砂体类型等岩性油藏的成藏条件进行了系统剖析 ,构建了该区岩性油藏的成藏地质模型。

关键词：留西地区层序地层学辫状河三角洲岩性油藏地质模型

Two accumulation modes of marine-origin natural gas in the Tarim Basin

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Science Bulletin 2007年第S1期 215-223页

作者： WANG HongJun1, ZHAO WenZhi1, HU GuoYi1 & HU JianFeng2 1 research institute of petrochina {3. and development, Beijing 100083. china 2 research institute of the Tarim Oilfield Corporation, petrochina, Korla 841000, china

Hetianhe gas field, Lungudong gas field and Tazhong gas field are marine marine-origin natural gas reservoirs in the craton area in the Tarim Basin. The natural gas is generated from Cambrian source rocks. The simulation experiment indicated that the cracking of the dispersedly dissoluble organic matter remaining in the source rocks is the main origin of marine natural gas. There are two modes to form gas reservoirs, one is the dry gas reservoir such as Hetianhe gas field, in which gas accumulated on the fault belt with violent tectonic movement, the other is condensate gas reservoir formed on the inheriting uplift such as Lunnan and Tazhong gas fields. The hybrid simulation experiment of cracking gas and crude oil indicated that crude oil accumulated on a large scale in those uplift belts at the early stage, and natural gas filled the ancient oil reservoir at the late stage, and the gas reservoirs were formed after the gas mixed with the crude oil.

关键词： Tarim Basin marine natural gas origin cracking accumulation

A discussion on gas sources of the Feixianguan Formation H2S-rich giant gas fields in the northeastern Sichuan Basin

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Science Bulletin 2007年第S1期 113-124页

作者： ZHANG ShuiChang, ZHU GuangYou, CHEN JianPing & LIANG YingBo research institute of Petroleum exploration & {3., petrochina, Beijing 100083. china

In recent years several H2S-rich oolite giant gas pools have been discovered in the Lower Triassic Feixianguan Formation of the northeastern Sichuan basin, and their explored gas reserves have been over 5000×108 m3. However, gas sources remain unsolved due to multiple source horizons with high maturity in this area and TSR alterations. By integrating analytical data of natural gas samples with conprehensive investigations on many factors, such as oil-gas geology, distribution and evolution of source rocks, charging and adjustment of gas pools, mixture of natural gases and secondery alterations, the present study concluded that the dominant source for the Feixianguan Fr. gas pools is the Permian Longtan Fr. source rock and secondly the Silurian Longmaxi Fr. source rock. Natural gases from the various gas pools differ genetically due to the matching diversity of seal configurations with phases of hydrocarbon generation and expulsion by different source rocks, among which natural gases in Puguang Gasfield are dominated by the trapped gas generated from the Longtan Fr. source rock and commingled with the gas cracked from the Silurian crude oil, while those in Dukouhe, Tieshangpo and Luojiazhai Gasfields are composed mainly of the Silurian oil-cracking gas and commingled with the natural gas derived from the Longtan Fr. source rock.

关键词： Feixianguan Formation gasfield group gas source hydrogen sulfide TSR the Sichuan Basin

Panorama of petrochina's exploration Results in 2002

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china Oil & Gas 2002年第3期9卷 4-8页

作者： Li xiaoguangexploration and development research {3. of petrochina Liaohe Oil Field company exploration and development research {3. of petrochina Liaohe Oil Field company

petrochina has made a number of important strategic breakthroughs and progress in the country's onshore oil and gas exploration in the January-October period of 2002, creating the conditions for a sustainable developm... 详细信息

关键词： 2002年中国油气储量油气资源勘探概况钻探可持续发展