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Episodic fluid movements in superimposed basin:Combined evidence from outcrop and fluid inclusions of the Majiang ancient oil reservoir,Guizhou Province

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Science China Earth Sciences 2008年第S2期51卷 78-87页

作者： XIANG CaiFu1,2,TANG LiangJie1,2,LI RuFeng1,2 & PANG XiongQi1,2 1 basin and reservoir research center,China University of Petroleum,Beijing 102249,China 2 State Key Laboratory of Petroleum Resource and Prospecting,China University of Petroleum,Beijing 102249,China basin and reservoir research center China University of Petroleum Beijing China State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing China

Combined evidence from the outcrop and the fluid inclusion assemblage (FIA) analysis indicates that there exist two episodes of fluid flow controlled by the tectonic activity. The first episode was recorded mainly in the reservoir rock of the Honghuayuan Formation,representing the fluid flow of hydrocarbon charging. The second episode occurred mainly along the fault systems,representing the fluid move-ment when the ancient oil reservoir was destroyed. The host mineral morphology,homogeneous tem-perature,and salinity of the FIAs record an episodic fluid movement. Characters of high homogenous temperature,low salinity and a quick temperature variation of the first episode fluid flow may indicate an early-stage fluid eruption,and correspondingly,fine-grained calcite was formed. Temperature of the erupted fluid tended to decrease during its mixing with the upper formation fluid and finally had the same temperature as the upper formation. From then on,the temperature was rather steady and fa-vored the growth of the coarse calcite. Due to this character of the temperature variation of the episodic fluid flow,we can use the homogenous temperature of the FIA of the coarse calcite to date the forma-tion and the destruction time of the Majiang ancient oil reservoir. Episodic fluid flow was known for its inhomogeneous trapping,which resulted in the failure of dating according to the burial history. But taking a close look at its temperature variation,we think that the latest stage of fluid flow,characterized by steady state temperature and grow of the coarser crystals,can be used for dating. It will be of great value if this method is proved to be effective. The formation and the destruction time of the Majiang ancient oil reservoir were dated to be in the Indosinian Period and the late Yanshan-early Hymalayan Period respectively. This conclusion is in great discrepancy with the common accepted idea that the Majiang ancient oil reservoir was formed and destroyed during the Cal

关键词： Majiang ancient oil reservoir episodic fluid flow marine carbonate rocks superimposed basin

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Depositional Environment of Es_4~u and Es_3~l Shales Based on Biomarkers from the Boxing Sag of Dongying Depression, East China

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Acta Geologica Sinica(English Edition) 2014年第5期88卷 1556-1564页

作者： WANG Ying LIU Luofu MENG Jianghui JIANG Zhenxue GAO Yongjin LIU Shuhui State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum basin and reservoir research center China University of Petroleum research Institute of Geological Science Shengli Oilfield Company Limited

The Boxing Sag is located in the southwest of Dongying Depression, southern Bohai Bay basin of East China. It is one of the main petroliferous sags in the Dongying Depression, and has two major source rocks, namely the upper 4th Member （Es4u） and lower 3rd Member （Es31） shales of Eocene Shahejie Formation, which are the new exploration targets in recent years. In this study, 16 core samples were collected from Es4u and Es31 shales in the Boxing Sag, and the saturate hydrocarbons were analyzed by gas chromatography （GC） and gas chromatography-mass spectrometry （GC-MS）, respectively. The results show that Es4u shale has obvious phytane and gammacerane predominance, higher concentration of tricyclic terpanes and regular steranes, and very low concentration of 4- methly steranes; Es31 shale has pristane predominance, lower concentration of tricyclic terpanes, gammacerane and regular steranes, and higher concentration of 4-methly steranes. The Es4u shale can be further divided into two types based on the distribution of n-alkanes in gas chromatograms： normal distribution and double peak pattern. The biomarker characteristics and sedimentary facies distribution show that Es4u shale was deposited in the saline-hypersaline semi-deep （Type A Es4u shale, sag center） to shallow （Type B Es4u shale, sag edge） lacustrine environments, Es31 shale was deposited in the freshwater-brackish semi-deep-deep lacustrine environments, and the former sedimentary facies maps of Es4u and Es31 in the Boxing Sag are further modified.

关键词： biomarker lacustrine environment shale Shahejie Formation Boxing Sag Dongying Depression

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The multi-factor recombination and processes superimposition model for hydrocarbon accumulation:application to the Silurian in the Tarim basin

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Petroleum Science 2008年第1期5卷 13-19页

作者： Meng Qingyang Pang Xiongqi Gao Jianbo State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing 102249 China basin and reservoir research center China University of Petroleum Beijing 102249 China research center CNOOC Beijing 100027 China

The multi-factor recombination and processes superimposition model for hydrocarbon accumulation is put forward in view of the hydrocarbon geological characteristics of multiple episodes of structural evolution, multiple sets of source-reservoir-seal assemblage, multiple cycles of hydrocarbon accumulation and multiple episodes of readjustment and reconstruction in the complex superimposed basins in China. It is a system including theories and methods that can help to predict favorable exploration regions. According to this model, the basic discipline for hydrocarbon generation, evolution and distribution in the superimposed basins can be summarized in multi-factor recombination, processes superimposition, multiple stages of oil filling and latest stage preservation. With the Silurian of the Tarim basin as an example, based on the reconstruction of the evolution history of the four factors （paleo-anticline, source rock, regional cap rock and kinematic equilibrium belt） controlling hydrocarbon accumulation, this model was adopted to predict favorable hydrocarbon accumulation areas and favorable exploration regions following structural destruction in three stages of oil filling, to provide guidance for further exploration ofoil and gas in the Silurian of the Tarim basin.

关键词： Multi-factor recombination processes superimposition Tarim basin Silurian favorable exploration region prediction

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Gas Occurrence and Accumulation Characteristics of Cambrian–Ordovician Shales in the Tarim basin, Northwest China

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Acta Geologica Sinica(English Edition) 2018年第5期92卷 1948-1958页

作者： LIU Luofu WANG Ying CHEN Yiting SHEN Baojian GAO Xiaoyue State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum (Beijing) basin and reservoir research center China University of Petroleum (Beijing) Wuxi research Institute of Petroleum Geology SINOPEC

The Tarim basin is located in northwestern China and is the biggest basin in China with huge oil and gas resources. Especially the Lower to Middle Cambrian and Middle to Upper Ordovician possess the major marine source rocks in the Tarim basin and have large shale gas resource potential. The Cambrian–Ordovician shales were mainly deposited in basin–slope facies with thicknesses between 30–180 m. For shales buried shallower than 4500 m, there is high organic matter abundance with TOC（total organic carbon） mainly between 1.0% and 6.0%, favorable organic matter of Type I and Type II, and high thermal maturity with RoE as 1.3%–2.75%. The mineral composition of these Cambrian–Ordovician shale samples is mainly quartz and carbonate minerals while the clay minerals content is mostly lower than 30%, because these samples include siliceous and calcareous shale and marlstone. The Cambrian and Ordovician shales are compacted with mean porosity of 4% and 3%, permeability of 0.0003×10^（-3）–0.09×10^（-3） μm^2 and 0.0002×10^（-3）–0.11×10^（-3） μm^2, and density of 2.30 g/m^3 and 2.55 g/m^3, respectively. The pores in the shale samples show good connectivity and are mainly mesopore in size. Different genetic types of pores can be observed such as intercrystal, intergranular, dissolved, organic matter and shrinkage joint. The reservoir bed properties are controlled by mineral composition and diagenesis. The maximum adsorption amount to methane of these shales is 1.15–7.36 cm^3/g, with main affecting factors being organic matter abundance, porosity and thermal maturity. The accumulation characteristics of natural gas within these shales are jointly controlled by sedimentation, diagenesis, hydrocarbon generation conditions, reservoir bed properties and the occurrence process of natural gas. The natural gas underwent short-distance migration and accumulation, in-place accumulation in the early stage, and adjustment and modification in the later stage. Finally, the Yulin（well Y1） and Tazho

关键词： shale gas occurrence accumulation Cambrian Ordovician Tarim basin Urumqi China

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Formation mechanism of deep natural hydrogen in the Sichuan basin

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Science China Earth Sciences 2025年

作者： Xiaomei WANG Kun HE Chunlong YANG Hao XIE Xiaobo WANG Yitong LYU Linfeng XIE Shuichang ZHANG research Institute of Petroleum Exploration & Development PetroChina Key Laboratory of Petroleum Geochemistry China National Petroleum Corporation International center for Isotope Effects research School of Earth Science and Engineering Nanjing University

As a potential renewable and clean energy source,the distribution and exploration prospects of natural hydrogen have garnered widespread ***,the limitations in understanding the formation mechanisms and accumulation patterns of underground natural hydrogen have significantly constrained its efficient exploration and *** study reports H2content and isotopes in natural gas from deep formations in sedimentary basins through geochemical analysis of 58 conventional gas samples from the Sinian to Triassic strata in the central Sichuan *** discovered that H2content in deep natural gas in central Sichuan generally exceeds 0.1%,with a maximum of 1.6%,and hydrogen isotopes (δ2HH2) range from-850‰to-586‰.Analysis of the geological conditions,hydrogen generation mechanisms,and isotope fractionation characteristics in the study area confirms that microbial fermentation or in-situ organic matter cracking are not effective pathways for deep *** with helium content and isotope analysis of the natural gas,it is inferred that the volcanic basement in the central Sichuan area is the potential source rock for natural H2in the Sinian to Triassic ***,H2originates from the radiolysis of water and hydrothermal reactions of Fe（II） in the basement ***,a diffusion fractionation model reveals significant isotope fractionation during the migration and accumulation of deep H2into sedimentary reservoirs,which lead to anomalously light δ2HH2in deep natural gas in central *** indicates that the underground natural hydrogen accumulation is in a long-term dynamic process,with simultaneous H2accumulation and dissipation in the gas *** research not only elucidates the formation mechanism of deep H2but also provides insights for the resource potential of natural hydrogen in sedimentary basins.

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Distribution of major hydrocarbon source rocks in the major oil-gas-bearing basins in China

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Chinese Journal Of Geochemistry 2005年第2期24卷 116-128页

作者：刘洛夫赵素平陈利新霍红 Key Lab. for Hydrocarbon Accumulation Mechanism University of Petroleum Ministry of Education basin and reservoir research center University of Petroleum Changping Beijing 102249 China

The distribution characteristics of major hydrocarbon source rocks in the major oil-gas-bearing basins in China were discussed in this paper, and differences between the East and the West basins in tectonic setting, age, lithology, sedimentary environment, and hydrocarbon generation feature and potential were also studied. Considering the Lüliang Mountains-Dalou Mountains as the boundary, source rocks in the East basins are distributed mainly in three NNE-trend subsiding belts, and those in the West basins are distributed in the north and south of the Tianshan Mountains and Qilian Mountains. They are mainly NWW trending and can be divided into four basin groups.

关键词：石油-天然气受力盆地烃源岩中国分布规律

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Reply to ‘Calculation of depth to detachment and its significance in the Kuqa Depression:A discussion’

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Petroleum Science 2009年第1期6卷 21-23页

作者： Yu Yixin Tang Liangjie He Chunbo Chen Xuyun State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing 102249 China Basin ＆ Reservoir Research Center China University of Petroleum Beijing 102249 China

This paper mainly replies to the discussion by Li et al （2009） on the calculation of the detachment depths in the Kuqa Depression. We think that viscous material flowing into or out of the cross section can affect the validity of the calculation method, yet the number of detachment levels does not bring any drawbacks to the calculation. In the Kuqa Depression, the salt flow influenced the structural deformation to some extent, and affected slightly the accuracy of the calculated depths of the true detachment levels. However, it does not mean that the calculation method loses effectiveness in the study area. Therefore, the calculation results are still relatively believable.

关键词： Excess area detachment level reply discussion Kuqa Depression

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Accelerating Oil and Gas Exploration in Western China by Studies of Formations of Hydrocarbon Accumulations in Superimposed basins—A Preface

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Acta Geologica Sinica(English Edition) 2010年第5期84卷 I0001-I0002页

作者： PANG Xiongqi State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing 102249 basin and reservoir research center China University of Petroleum Beijing 102249

The superimposed basins in the western region of China are a hot research topic for earth scientists home and abroad for their vast area and rich oil and gas resources. Their complex geological conditions and resultant great exploration difficulties have received much attention of the scientists. This issue presents the advances of several scholars in their long-term research on the mechanisms of oil and gas accumulation and the patterns of oil and gas distribution.

关键词： Studies Western China oil and gas accumulation Oil and Gas Distribution geological conditions research western region difficulties exploration attention presents Typical studies complex Chinese topic vast area

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Multi-origin alkanes related to CO_2-rich, mantle-derived fluid in Dongying Sag, Bohai Bay basin

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Chinese Science Bulletin 2002年第20期47卷 1756-1760页

作者： JIN Zhijun, ZHANG Liuping, ZENG Jianhui & YANG Leibasin & reservoir research center, University of Petroleum, Beijing 102249, China Key Laboratory for Hydrocarbon Accumulation Mechanism of Chinese Ministry of Education, University of Petroleum, Beijing 1 basin & reservoir research center University of Petroleum Beijing China Key Laboratory for Hydrocarbon Accumulation Mechanism of Chinese Ministry of Education University of Petroleum Beijing China

With the newly obtained carbon isotope data for the natural gas, a pilot study of multiple-sourced alkanes related to the mantled-derived fluid is presented. The carbon isotope values of alkanes in the Dongying Sag possess the features indicating a general organic origin. However, there are two sub-populations in the isotopic data set, which reflect two specific types of origins. In general, the sub-population with high δ13CCH4 values is related to the CO2-rich, mantle-derived fluid, and it is distributed in the belts where mantle-derived fluid flow and basic volcanic activities have occurred. Geological and geochemical studies demonstrate that this variation of methane carbon isotope values in the Dongying Sag is unrelated with the basin bury and thermal histories, types of source rocks, and reactions between basin fluid and rocks. Mixing of mantle-derived fluid and organic sourced hydrocarbons is probably the cause for the variation.

关键词： mantle-derived fluid organic origin hydrocarbons in-teraction carbon isotope.

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Activity and Formation of Sand Waves on Northern South China Sea Shelf

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Journal of Earth Science 2010年第1期21卷 55-70页

作者：栾锡武彭学超王英民邱燕 Key Laboratory of Marine Geology and Environment Institute of OceanologyChinese Academy of Sciences Guangzhou Marine Geological Survey Ministry of Land and Resources basin and reservoir research center China University of Petroleum(Beijing)

Sand waves on the northern South China Sea shelf had been considered as stable relict bed form. For the industry use of sea bed between stations LF13-2 and LF13-1, a new round of explorations were conducted. The newly obtained data show that both spacings and amplitudes of sand waves are all systematically changing with water depth. Repeated observations since 2003 to 2004 showed that the sea bed is currently active. Due to strong erosion of surface sediment since Dongsha （东沙） uplifting, there are almost no modern sediments on the shelf of Dongsha area. Sand materials in the study area mainly originate from the erosion of the bed sediment formation. The water depth increment revealed by repeated echo sounder data is mainly due to erosion. Bottom currents are quite complex in the area of Dongsha underwater plateaus. At site 9MKH, the southward ebb current is stronger than the north- ward flood current, while at site AEM-HR, the WNW-ward flood current is slightly stronger than the ESE-ward ebb current. At site 9MKII, the maximum bottom current speed is 48 cm/s, and 22% of the observed bottom current speeds are larger than 20 cm/s, which meet the minimum bottom current speed required for the creation of sand wave. This article points out that present-day oceanographic condition couples well with the sand-wave morphologies, and that the sand waves are to a great extent in equilibrium with the ongoing present-day oceanographic bottom current condition and active.

关键词： sand wave northern South China Sea shelf activity formation.

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