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    19 November 2010, Volume 24 Issue 6
    Water Resource and Environment
    Internal Structural Deformation of the Tazhong Lower Uplift, Tarim Basin
    YU Yi-Xin, HUANG Ta-Zhu, SHANG Liang-Jie, CHEN Xu-Yun, CUI Ze-Hong
    2010, 24(6):  1029-1034. 
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    Based on the interpretation of seismic profiles, the internal structural deformation of the Tazhong lower uplift were analyzed. The structural deformation in the study area was featured by the combined distortion of detachment and basementinvolved, as well as extension, thrusting, inversion and strike slipping. In the Tazhong lower uplift, the structural styles could be divided into five types, including compressional, strike slipping, extensional, inversion and plastic structures, and more subtypes could also be identified. Influenced by the early geological backgrounds and various kinematic mechanisms, the distribution features of the structures in the Tazhong area are different. The NWand NEstriking faults are thrust and strike slip faults, respectively. The extensional structures are mostly stituted in the Triassic, and the inversion structures are distributed in the Cambrian and Ordovician.

    Structural Features and Evolution of Yelu Fault Belt in Zhoukou Depression, Southern North China
    BAI Hua, YANG Meng-Hui, CENG Peng, WANG Jin-Xiu, HUANG Wang-Guo
    2010, 24(6):  1035-1041. 
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    Located in the southern North China Craton, Yelu fault belt is an important part of Lushan-Wuyang-Fuyang-Huainan fault belt, which controls the formation and evolution of Tanzhuang Sag and Wuyang Sag in Zhoukou depression. It was affirmed through drilling analysis, seismic profile interpretation and balanced cross section analysis that under the influence of Qinling-Dabie orogenic activity, Yelu fault belt strongly thrusted towards NNE, with about 37° fault dip and fault activity rate of -22 m/Ma during the Late Jurassic and Early Cretaceous; occurred in the Late Cretaceous and Paleogene, the negative inversion of Yelu fault belt was related to the extensional environment in Zhoukou depression. The tri-shear model is applied to stimulating the structural and evolutionary processes of Yelu fault belt nearby the well ZC 12. The result shows that during the Late Jurassic and Early Cretaceous, fault slip of Yelu fault belt amounts to 6,100 m, and fault propagation is 9,150 m as well as p/s is 1.5, with the trishear angel of 150°.

    Characteristics of Presentday Geothermal Field of Gaoyou Sag in Subei Basin
    LI Ya-Jun, LI Ru-Feng
    2010, 24(6):  1042-1047. 
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    Gaoyou sag is one of the sags with the most abundant oil and gas resources in Subei basin, but the characteristics of geothermal field of this sag have not been researched. According to the temperature data of 16 temperature wells and 53 test wells in Gaoyou sag, the temperature distribution of the main layer groups and the geothermal gradient distribution were analyzed. The result showed that temperature generally increased with depth increasing and also increased from E2s to K2t. The slope inhabited the higher temperature than the deep sag. In the same layer the temperature of the deep sag was higher than that of the slope; the temperature of the east part of slope was higher than that of the west. The phenomenon that the higher temperature in the deep sag and lower in the slope showed close relationship between temperature and depth. The buried depth was the main influence factor for the temperature. The geothermal gradient of E2s-E2d was between 23 ℃/km and 30.2 ℃/km, and that of E1f-K2t was between 28.9 ℃/km and 36.3 ℃/km. The geothermal gradient of E1f-K2t was higher than and that of E2s-E2d。The higher geothermal gradient of E1f-K2t caused by the high content of low thermal-conductivity mudstones in three sets of hydrocarbon source bed (E1f4,E1f2 and K2t2). The oil and gas reservoirs distributed from E2s to K2t in Gaoyou sag. The oil and gas reservoirs overall distributed in the region with the temperature more than 60 ℃, and individual reservoir distributed in the region with the temperature less than 60 ℃. The faults of Hanliu and Zhen 2 were the main pathway leading to oil and gas migration into the upper strata.

    Sequence Stratigraphic Analysis of Carboniferous in Wuwei Basin
    LI Ru-Feng, LIU Guan-Di, MA Guo-Fu, GAO Gang, FANG Jing, LIU Yu-E
    2010, 24(6):  1048-1056. 
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    A systematic study on sequence stratigraphy of 13 Carboniferous outcrop sections in Wuwei Basin had been conducted to identify two type Ⅰ sequence boundaries, four type Ⅱ sequence boundaries, five sequences and 11 systems tracts. TypeⅠsequence boundary had two genetic types. One genetic type was the tectonic unconformity interface influenced by the regional tectonic movements, the other genetic type was the erosion or sequence missing influenced by the local liftdown movements. The type Ⅱ sequence boundary was mainly the structure transition interface by the significant change in the sedimentary structure. The sequence Ⅰ, sequence Ⅱ, sequence Ⅲ, sequence Ⅳ, sequenceⅤ were basically matched with Qianheishan Formation, Chouniugou Formation, Jingyuan Formation, Yanghugou Formation and Taiyuan Formation. For the first time, the low stand systems composed by downcutting stream phase complex had been discriminated in the bottom of Qianheishan Formation of the Early Carboniferous. We revealed the development characteristics of different systems tracts within the sequence and set up the sequence stratigraphic framework of Carboniferous in Wuwei Basin, analyzed the evolution of sequence and systems tracts and the change law of sedimentary environments.

    The Formation and Evolution of Weathering Reservoir of Ordovician Paleocrust in Tahe Oilfield, Tarim Basin
    Jia Zhen-Yuan, CA Zhong-Xian, XU Wei
    2010, 24(6):  1057-1064. 
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    The weathering reservoir of Ordovician paleocrust in Tahe oilfield undergoes weathering and denudation as long as 118 Ma from Middle Caledonia to Hercynian period. Cores observations and well logs explanations show that cave development in vertical is closely related to multistage tectonic movements of Northern Tianshan. The chaotic network of cave system were formed from multiphase superpositions of various dissolution such as direct runoff, vadose dissolution, underflow, mixed-water dissolution of coastal zone during 8 times uplift movements in the MidLate Caledonia and Early Hercynian movements.

    The Study of Karst Zonation in Yingshan Formation of Lower Ordovician in Xikeer, Xinjiang
    FENG Hai-Xia, LI Shu-Xin, CHEN Dong-Mei, HE Hu, ZHOU Cai-Hong
    2010, 24(6):  1065-1071. 
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    Recently,people pay more and more attention to karst fractured/caverned reservoir that has been thought as an important oil and gas reservoir in Tarim basin,but the means to predict this kind of reservoir are limited at present. The epi-karst is rich in Xikeer outcrop in Jiashi County, Xinjiang. A series of lapis were filled with Silurian by filling and levelling up,and some Silurian formation still remained in part of karst depression.All these characters express that this area develop karst of Middle Caledonian.In the light of modern geomorphology and karst theory and according to different hydrodynamic conditions,we can divide the second period karst profile into epi-karst zone, vertically filtering zone and horizontally potential flow zone. Developmental law of palaeokarstsubterranean river and developmental extent of cavern in this area are identified. Owing to the master control element of tectonic movement to vertical karst zonation,effectively fractured/caverned reservoir in Bachu area can be predicted on condition of the tectonic background.

    Distribution and Evolution of Sedimentary Microfacies and Prediction for  Favorable Facies Zones of Putaohua Reservoir in Block Zhao 35, Daqing Oilfield
    CHEN Wei, LIU Da-Meng, BANG Cheng-Wen, LI Feng, ZHANG Bai-Ren
    2010, 24(6):  1072-1078. 
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    Block Zhao 35 is a newly developed area of Songfangtun oilfield in Daqing, in which the main target horizon is Putaohua reservoir. According to various geological data and sedimentary facies analysis, it is recognized that delta front and shallow lake are main depositional facies in the study area, which are further divided into underwater distributary channel, mouth bar, sheet sand, interdistributary bay and shallow lake mudstone. A logging facies template was established. Mouth bar developed well in upper of Putaohua reservoir,and in which Layer PI2 was the main oil layer. Underwater distributary channel developed well in lower of Putaohua reservoir, and in which Layers PI51, PI52 and PI7 were the main oil layers. The deposits in the study area mainly came from northwest and north, and the sand body is thicker in the northwest than in the southeast. Underwater distributary channel was branched, and characterized by excellent connectivity along the channel direction. Sheet sand was thin and continually developed around the channel. Mouth bar distributed as lens at the end of the channel. Based on comprehensive study, three types of favorable facies zones were divided. TypeⅠis the underwater distributary channel which was distributed large in the study area; Type Ⅱis the mouth bar which was small and dispersed, Type Ⅲis sheet sand which only developed in south of the study area.

    Secondary Hydrocarbon Generation Potential of Marine Shale Source Rocks in Thermal Modeling
    XIN Yan-Peng, QIN Jian-Zhong, ZHENG Lun-Ju, QIU Nan-Sheng
    2010, 24(6):  1079-1084. 
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    Based on simulation experiments of the natural maturity marine shale samples, this article presents a brief discussion on secondary hydrocarbon generation of marine shale. The results indicate that the secondary hydrocarbon generation is not continuous with the evolution tendency of the first hydrocarbon generation of marine shale. There is a hydrocarbon generation peak during the secondary hydrocarbon generation process of low matured shale and matured shale, which is later than that of the first continuous hydrocarbon generation. The lagging is enhanced when the original maturity increases. The secondary hydrocarbon generation process of high matured shale and overmatured shale does not have a hydrocarbon generation peak.  Secondary hydrocarbon generative potential is dominated by original maturity. Marine shale which has an original maturity before being oil window has preferable secondary hydrocarbon generative potential to yield abundant oil and gas. Marine shale which has an original maturity just being in oil window has preferable secondary gas generative potential and weakened secondary oil generative potential. Marine shale which has a higher original maturity than that of oil window has poor secondary oil generative potential, but still can generate considerable quantity of gas. The marine shale which has a higher original maturity than the oil-generating dead line almost has not any secondary hydrocarbon potential. This research improves the current theory of secondary hydrocarbon generation, and can be a good guidance for evaluation on marine source rock in superimposed basin in China.

    Characteristics and Origin Classification of the Oils from the Lower Section of the 4th Member of Shahejie Formation and Kongdian Formation in the Southern Slope of Dongying Depression, Bohai Bay Basin
    MENG Jiang-hui,LIU Luo-fu,JIANG Zhen-xue,GAO Yong-jin
    2010, 24(6):  1085-1092. 
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    The lower section of the 4th member of Shahejie Formation and Kongdian Formation is a suite of purplish red and red clastic sediments in the southern slope of Dongying Depression which can not generate mass hydrocarbons. Therefore, it is significant to discuss the oil origin of the layers. Based on the biomarker characteristics analyses of the 17 oil sands and 5 crude oils, the origin of oils found in the study area was classified into four classes. Class-Ⅰ oil distributes in Pingfangwang area and Boxing subsag, being characterized by Pr/Ph>0.8, Ph/nC18<0.6, an extremely low content of gammacerane, a relatively high content of 4-methyl steranes and diasteranes and relatively high ratios of Ts/Tm and hopanes/steranes, which reflects the oil may come from a suite of mudstone rich in clay minerals deposited in the fresh water lacustrine environment. Class-Ⅱ oil distributes in Chunhua-Lean and Chenguanzhuang structural belt, characterized by Pr/Ph<0.6, Ph/nC18>2, a high content of gammacerane, a low content of 4-methyl steranes and diasteranes and relatively low ratios of Ts/Tm and hopanes/steranes, which indicates the oil sourced from a suite of mudstone or lime mudstone deposited in salt lacustrine environment. ClassⅢ oil distributes in the northern gentle slope structural belt of Qingcheng, characterized by the detection of 25-norhopanes and a middle content of gammacerane, which shows it is mixture of few biodegradated Class-Ⅱ oil charged in early stage and mass Class-Ⅰ oil charged in late stages. Class-Ⅳ oil distributes in Kongdian Formation  of Wangjiagang area, characterized by an absolute predominant content of C29 steranes and a high content of gammacerane, which reveals the oil is mixture of Class-Ⅱ oil and the oil generated by shallow lake-swamp facies source rock.

    The Evolution of Paleohydrodynamics of Dabashan Foreland Thrust Belt and Its Influence on Formation and Preservation of Oil and Gas Reservoirs
    ZENG Jian-hui, SUN Zhan-qiang, XU Tian-wu, GUO Kai
    2010, 24(6):  1093-1101. 
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    Concerning the problems in the traditional division of paleohydrodynamic stage, this paper takes account of the specific tectonic characteristics of Dabashan foreland thrust belt, and divides its evolution into sedimentary hydrodynamic stage, infiltrating hydrodynamic stage, tectonic hydrodynamic stage and burial hydrodynamic stage in the unit of hydrocarbon accumulation play. The lower play had gone through one sedimentary hydrodynamic stage, four infiltration hydrodynamic stages, four bury hydrodynamic stages and three tectonic hydrodynamic stages; The middle play, one sedimentary hydrodynamic stage, three infiltration hydrodynamic stages, two bury hydrodynamic stages and three tectonic hydrodynamic stages, and the upper one, mainly infiltration hydrodynamic stage. The burial hydrodynamic stage from Permian to Early Cretaceous was favorable for hydrocarbon generation, migration and accumulation, but the reservoirs were adjusted and reformed a lot during the tectonic hydrodynamic stage. They were further adjusted and destroyed during the infiltrating hydrodynamic stage after Late Cretaceous. Oil crack were common in the middle hydrocarbon play in burial/connate hydrodynamic stage and tectonic hydrodynamic stage from the end of Late Triassic to Late Cretaceous, in the meantime, lots of adjustedandreformed oil and gas reservoirs were formed; after Late Cretaceous, many adjustments and reforms of oil and gas reservoirs took place in the middle hydrocarbon play in Dabashan foreland depression belt during burial/connate hydrodynamic stage and tectonic hydrodynamic stage, while the plays in Dabashan foreland basement detachment tectonic belt and Dabashan foreland decollement tectonic belt in cover strata were mainly destroyed and reformed.

    Synopsis of Petroliferous Basins and Petroleum Distribution in South America
    BAI Guo-ping, QIN Yang-zhen
    2010, 24(6):  1102-1111. 
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    South America is one of the major oil and gas producing regions. It has recorded a number of significant exploration breakthroughs recently. Since 2007, several giant fields have been discovered in the sub-salt sequences in the Santos Basin, which indicates the promising exploration potential of sedimentary basins in South America, particularly deep water sub-salt play in the passive margin basins. Based on the up to date reserve data of oil and gas fields, this paper documents the oil and gas distribution features in terms of basin type. It also characterizes the areal and stratigraphic distribution of discovered oil and gas reserves. In South America, the foreland basin is the basin type with the richest oil and gas resources, followed by the passive margin basin. The foreland basins are located along the Andes Mountains. The ones in the northern and southern sectors are Cenozoic foreland basins and those in the middle sector Paleozoic foreland basins. The foreland basins which evolved from a proceeding passive margin basin development stage are the most prolific oil and gasbearing basins. They are represented by the East Venezuela and Maracaibo Basins. Along the Andes foreland basins, the main reservoir intervals vary from the Jurassic-Cretaceous in the south, through the Carboniferous in the middle, to the Cretaceous-Tertiary in the north. The passive margin basins lie along the South Atlantic margin. In this type of basins, oil and gas are mainly concentrated in the Cretaceous-Tertiary. Of them, the ones with evaporites tend to be richer in oil and gas and they are represented by Campos and Santos Basins.

    Dominant Petroleum Migration Pathways of Fuyang Reservoir in Binbei Area, Songliao Basin
    JIANG Fu-jie, PANG Xiong-qi, LIU Guang-di, JIANG Zhen-xue,JIANG Wenli
    2010, 24(6):  1112-1116. 
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    Binbei area possesses a certain kind of petroleum resources potential. However, exploration directions and prospect targets of this district are not clear, which calls for a research of oil and gas migration directions. Analysis of the affecting factors resistance to the oil and gas pathway directions ascertains 4 types of controlling factors, which are structural features of the cap rock bottom layer, sand bodies, faults, hydrodynamics, respectively. By systematic analysis of correlations between each controlling factor and the petroleum migration direction, the paper predicts dominant petroleum migration directions qualitatively using single factor overlay method and quantitatively using multiinformation superposition method, respectively. The results indicate the existence of two dominant migration directions in Fuyang reservoir in Binbei area, which are direction trends along the Suileng anticlinal zones from the north part of Sanzhao Depression to northeast, and direction trends from the south part of KeshanYilong anticlinal zone to the northeast.

    Gas-water Distribution Characteristics and Genetic Mechanism of the Second Sector of the Upper Triassic Xujiahe Formation in the Middle of the Western Sichuan Depression
    CHEN Dong-xia, PANG Xiong-qi, LI Lin-tao, DENG Ke, ZHANG Jian-hua
    2010, 24(6):  1117-1125. 
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    Severe densification and complicated gas-water distribution of the Upper Triassic Xujiahe Formation reservoir have become the key issues to natural gas exploration and development of the Western Sichuan depression. Based on the research of geological characteristics of the gas reservoirs, fluids and gas-water distribution, combined the comprehensive analysis of the regional geological conditions and physical modeling experiments, the genetic mechanism of the complicated gas-water distribution is discussed in this paper. The results show that the natural gas in the second sector of the Xujiahe Formation is coal-type cracking gas, and the water is CaCl2type belonging to the high-sealed environment. The gas testing and logging explanation results shows that the reservoir of the second sector of the Xujiahe Formation is primary gas layer or gasbearing layer that only a few wells show gaswater layers or water layer, and the water displays no layering and the characteristics of stringlike stratigraphic water. The stratigraphic water distribution is not controlled by structure, and not showing up gas and down water or up water and down gas. In the formation process of deep basin gas, due to strong heterogeneity, the gas driving water firstly enters the reservoir with relatively high porosity and permeability, but the stratigraphic water completely sealed in super tight sandstone is not easily expelled to form residual stratigraphic water. This genetic mechanism was approved by physical modeling experiments.

    Characteristics of Abnormal Pressure and Its Relationship with Hydrocarbon Accumulation in Nanpu Sag, Bohai Bay Basin
    SUN Ming-liang, LIU Guang-di2, DONG Yue-xia
    2010, 24(6):  1126-1131. 
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    Characteristics of abnormal pressure were investigated in Cenozoic, Nanpu sag by means of geophysical data and DST/RFT data. The top of overpressure occurs under 2.8 km, more overpressure under 3 km. Overpressured formation is always comprised of Ed and Es. Overpressured section could be divided into 3 segments vertically, which are hydrostatic segment, top overpressured segment and bottom overpressured segment. Excess pressure is horizontally charactered by successive distribution in different Cenozoic formations: Linque sub-sag and Caofeidian sub-sag are located in the central overpressured part, and from center of Nanpu sag to south shelving region, western Beipu structural belt and Laoyemiao structural belt the excess pressure decreases. The distribution of abnormal pressure is mainly controlled by the burial depth. Most hydrocarbons are distributed beyond the top overpressured segment. Overpressure is a significant controlling factor of hydrocarbon accumulation.

    Hydrocarbon Reservoir-forming Processes and Patterns in Deep Strata of Shiwu Fault Depression in the Songliao Basin
    LIU Xiao-ping, Lv Xiu-xiang, XIE Qi-lai , YU Shun
    2010, 24(6):  1132-1139. 
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    Deep reservoirs of Shiwu fault depression in the Songliao Basin experienced multi-stage hydrocarbon accumulation and multi-stage evolutions. Basin simulation of hydrocarbon generation and expulsion history of source rock and reservoir fluid inclusion analysis show three periods of reservoir forming. Primary oil-gas pools formed at the end of Denglouku period. At the end of Quantou period, many kinds of oil and gas pools formed on a large scale. Former oil-gas pools enlarged with continuous charging of hydrocarbons generating by local mature source rocks, and the former crude oils cracked into gases. At the end of Nenjiang period, primary oil and gas pools reconstructed intensively. A lot of gas pools and secondary oil-gas pools were formed in this period. Two different accumulation patterns are developed in the Shiwu fault depression. One pattern is developed in central uplift called  multi-stage forming and middle-late-stage strong adjustments type, and another pattern is developed in deep zones and slopes called  early-stage forming and late-stage weak adjustments type.

    Distribution Rules of CO2  in Shallow Gas Reservoir and Relevant Causes in the Yinggehai Basin
    HUANG Zhi-long, HUANG Bao-jia, GAO Gang, TONG Chuan-xin, LIU Jiang-tao
    2010, 24(6):  1140-1147. 
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    Based on research of origin and filled periods of  CO2   and development characteristics of diapirs, the distribution rules of  CO2    in different types of diapirs and relevant causes are analyzed. The result shows that CO2  of shallow gas reservoirs is mainly originated from pyrolysis of the crustal carbonate rocks, and the major causes of distribution diversity are differences of fluid components and filled periods, and difference of diapiric activity intensity. In low amplitude and weak energy diapirs,  CO2   has mainly accumulated in underside of hydrocarbonriched reservoir. In high amplitude and middle energy diapirs, the distribution of  CO2   shows apparent characteristics of blocksubregion: hydrocarbon gas rich is in shallow reservoir but  CO2   is rich in deep reservoir on the same side of fault, and hydrocarbon gas is relatively  rich in reservoirs on hanging wall of fault but  CO2  is rich in reservoir on footwall of fault, and CO2 hydrocarbon gas is relatively rich nearby fault but  is rich far away from fault. In eruptiontyped high energy diapirs, the distribution rule of  CO2    is not apparent. Distribution depth of  CO2   is relevant to its solubility in water:   CO2  is relatively large in deep formation water, so the possibility of forming free  CO2   gas reservoir is very small.

    Coupling of Driving Force and Resistance for the Migration of Oil and Gas at the Periods of Hydrocarbon Accumulation in Southern Slope of Dongying Sag:Taking the Jin 8Bin 188 Section as an Example
    GAO Yong-jin, WANG Yong-shi, YU Yong-li, JIANG Zhen-xue, TIAN Miao
    2010, 24(6):  1148-1156. 
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    Taking the Jin 8-Bin 188 section in the west of Dongying sag as an example, this research rebuilt the evolution of driving force for hydrocarbon accumulation by basin modeling  with the constrained procedure. The porosity and permeability of reservoir were recovered with charts of porosity evolution. The capillary force of reservoir was calculated, and the evolution of driving force for hydrocarbon accumulation was recovered when the capillary force was taken as the resistance force, and the evolution of the dynamic gradient for hydrocarbon accumulation was also simulated by coupling the driving force and resistance force. After the comprehensive analysis of the relationship between the evolution of dynamic gradient and the discovered hydrocarbons, this research predicted the favorable oil and gas accumulation zones. In the Jin 8-Bin 188 section, the damandbeach sands are the first-class favorable zone for the reason that the sands have the best condition for hydrocarbon accumulation; the turbidite fan lens at the slope and the delta sands at the gentle slope are the second-class favorable zone; the damandbeach sands at the bottom of slope are the third-class favorable zone.

    Gas Composition Differentiation during Natural Gas Hydrate Formation and Its Geological Significance
    LIN Xiao-ying, ZENG Jian-hui
    2010, 24(6):  1157-1163. 
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    The different gas sources have different gas compositions under geological conditions, which have different effects on formation conditions of natural gas hydrate reservoir. In this paper, the simulation experiments of gas hydrate formation were carried on onedimensional gas hydrate experiment device in China University of Petroleum. The two experiment samples are conventional natural gas. The gas compositions, including original gas samples, free gas samples after gas hydrate formation, and decomposition gas of gas hydrate, were analyzed. The experimental results show that CH4 and N2 volume content reduces in the decomposition gas of hydrates, and C2H6、C3H8、iC4H10、nC4H10、CO2volume content increases, and it is contrary in free gas. This means that C2H6、C3H8、iC4H10、nC4H10、CO2more easily form gas hydrate compared with CH4 and N2 under the condition of the same temperature and pressure. Based on relative volume variation of the decomposition gas to the original gas composition, it can be concluded that the ability of forming hydrate from hydrocarbon ordinarily increases from methane, ethane, propane to isobutene in experimental temperature and pressure conditions (temperature range is from 4 to 10 ℃, gas inlet pressure is 5 MPa). The different hydrocarbons have different hydrate formation conditions, which results in gas compositions differentiation during hydrate formation. The content of methane decreases in hydrate, but that of wet gas increases, which is contrary in the free gas. The hydrate zone can be divided into dissolved gas zone, gas hydrate stable zone and free zone (or conventional natural gas zone) from top to bottom. The methane content is middlelowhigh, and wet gas and dioxide content is lowhighmiddle in the three zones. The results show that the same gas source have different gas composition characteristics under different zones.

    An Experimental Study of Oil Migration Controlled by Vertical Conduction of Faults and Reservoir Heterogeneity
    GUO Kai , ZENG Jian-hui , LU Xue-jun , CUI Zhou-qi , SHI Yu-lei
    2010, 24(6):  1164-1170. 
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    Based on physical simulation experiments, the impacts of conduction capacity of faults and reservoir heterogeneity on the mechanism and patterns of the vertical migration and lateral diversion of oil along faults are researched. The results reveal that the control of conduction capacity of faults and reservoir heterogeneity to oil migration essentially is the coupling control of physical properties (ratios of faults permeability to reservoirs permeability) and charging forces to the vertical migration and lateral diversion of oil. Three patterns, which are controlled by fault with high conduction capacity and reservoirs of inverted rhythm, fault with low conduction capacity and reservoirs of inverted rhythm, or fault with high conduction capacity and reservoirs of positive rhythm, can summarize the coupling control of the two elements to oil migration and distribution. In the first pattern, lateral diversion can hardly occur as the oil migrates vertically along the fault, and oil mostly accumulates in the reservoir beneath the cap rock. In the second pattern, lateral diversion can occur easily as the oil migrates vertically along the fault, and every reservoir can assemble some oil. In the third pattern, lateral diversion can occur more easily as the oil migrates vertically along the fault, and oil mostly accumulates in the lower reservoir with best physical property.

    Quantitative Gas Washing Evaluation on Reservoirs in TZ83 Well Block in Tarim Basin
    LI Zhuo , JIANG Zhen-xue , YANG Hai-jun , ZHANG Bao-shou , HUANG Yu-yan
    2010, 24(6):  1171-1177. 
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    In Himalayan period, the dry-gas washing to the ancient reservoirs in the Tazhong No.1 slope break is an important reason that leads to the oil and gas fractionation and the formation of secondary gas condensate reservoir. Most of the previous study on the gas washing in Tazhong is qualitative description, but quantitative research is less, which pulls off the further accumulation research. This paper analyzed the regional structure conditions, summed up the oil and gas properties and component characteristics, made the quantitative description of gas washing by carrying out the n-alkanes quantitative measurement and calculating the loss rate of n-alkanes (Q) in the TZ83 well block. The results of the loss rate of n-alkanes show that all reservoirs in the study area had experienced gas washing (range of Q is 12% to 86%), and the intensity of gas washing gradually decrease from the northwest to southeast in the plane and from deap to shallow in the cross section. Furthermore, during the gas washing, the lower carbon number n-alkane dissolved in gas and separated from oil, led to the formation of condensate gas reservoirs with high wax content. It is confirmed that the gas washing of high-maturity dry gas to TZ83 well block along the interchange of Tazhong 82 and the Tazhong No.1 slope break and provides quantitative evidence for the accumulation research.

    Identification and Correlation of Base-level Cycles  of Coal-bearing Strata in Paleogene System of China Seas: Taking the Case of Qiongdongnan  Basin as an Example
    LI Zeng-xue, ZHANG Gong-cheng, WANG Dong-dong, LI-Ying, LIU Hai-Yan, L- Da-wei
    2010, 24(6):  1178-1185. 
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    This paper researched coal-bearing strata depositional systems of Paleogene System in Qiongdongnan basin. The main depositional systems in the study area are alluvial fan(fan delta)abyssal fan system, shore marine and middle-deep lake and turbidite fan system, braided stream-braided channel deltasubsea apron system, tide flatlagoon system, offshore-epeiric sea-turbidite fan system, etc. Among the above depositional systems, the braided stream-braided channel delta-subsea apron system and tide flat-lagoon system have undergone great coal-forming actions. With high resolution sequence stratigraphy theory and technology, the middleand shortterm basal levels were identified. The main boundary types of shortterm basal level are erosion and the overlying lag sediments, soil sediments and peatification event sediments, microfacies and lithofacies types or facies group changes in vertical, abrupt interfaces in well logging curves, etc. In the Paleogene strata of Qiongdongnan basin, the shortterm basal level cycle types, controlled by different genetic feature boundaries,are deepeningupward asymmetric shortterm basal level cycle(type A), shallowing-upward asymmetric shortterm basal level cycle(type B) and symmetric shortterm basal level cycle(type C).

    Characteristics of Coal Petrology and Genesis of Jurassic Coal in Ordos Basin
    HUANG Wen-hui, AO Wei-hua, WENG Chen-min, XIAO Xiu-ling, LIU Da-meng
    2010, 24(6):  1186-1197. 
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    Multiple thick coal beds occur in Jurassic, Ordos basin. They have good coal qualities, huge reserves, simple structures, and relatively shallow burial depth. As a result, they possess large exploitation values. The characteristics of coal petrology are specific in Jurassic coal sequences in Ordos basin. Their genetic swamp environment was mainly a series of high-stand swamps on the upper fluvial system that was related with the development of typical inland lakes. The sand bodies were developed. The peat, after the  burial, continued to undergo oxidation conditions with different degrees. As a result, the content of inert components is widely higher than normal values. The vitreous coal component had extensively undergone specific-degree fusainization and became semi vitrinite.The study shows that in Ordos basin, the coal petrology in Jurassic is mainly semidull coal and dull coal, and semilustrous coal and lustrous coal as follows. It is also found that the contents of semidull coal and dull coal have higher percentages in the basin margin, especially in the area near the provenance of northern basin; the semilustrous coal and lustrous coal become more and more southwards towards the central basin. This result explains that the depositional environment and coal-generating swamp environment have the major controlling effects on the coal components.Another result is that in these coal sequences, the fusinite content is higher in coal macerals with thicker sandstone and coarser grain sizes, moreover, its texture is complete and clear, especially in lower coal beds. The semi vitrinite has the same regularity. The cell texture of plants becomes more complete and regular. After the burial, the lithology of roof and floor rocks can continue to affect the evolution of coal petrology. The sand bodies in the roof and the floor of coal beds have good physical conditions so that the pore water can still be in the state of oxidizing, circulating and connecting in a long term. It makes the coal components stay in the oxidation phase for a long time, which is favorable for the process of fusinitization. On the contrary, the development of lacustrine facies and peat rapidly covered by mudstone after the burial swiftly, make the coal beds in reduction and anoxic environment. As a result, the gelatification can be done abundantly and the vitrinite content increases. Exinite often accumulates in a specific position of coal bed, and its average content is not high in the whole coal bed, but it has great contribution to the total hydrocarbon generated capacity of coal beds.In the past research results, the exinite content is often underestimated, especially amorphous bitumen in fluid state, for the reason that it is easiest to flow into the fusinite with strong rigidity or several fissures. The exinite content deserves to be emphasized in the further research.

    Characteristics of Porosity and Permeability and Their Geological Control of Permo-Carboniferous Coals in North China
    LIU Da-meng, YAO Yan-bin, CAI Yi-dong, ZHANG Bai-ren, ZHANG Ke-ming, LI Jun-qian
    2010, 24(6):  1198-1203. 
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    The low porosity and low permeability of coal reservoirs have brought about a big problem for the exploration and exploitation of coalbed methane in China. Based on the coal proximate, coal maceral composition and low-temperature N2 adsorption analyses, microfracture analysis by fluorescence microscope, helium porosity and air permeability analyses, this study investigated the geological control of porosity and permeability of coals in Hedong, Weibei, Yangquan, Jincheng, Datong and Huainan.Huaibei coalfields. The results showed that coal porosity ranged from 2% to 10%, and strongly related to the coalification degree. The porosity reached a minimum value when Ro,r  was about 1.2%. The filling and mineralization of pores by minerals were proven to decrease the coal porosity. Coal permeability is commonly less than 5×10-3μm2, and shows an exponential increment relationship with porosity. The anthracite porosity is commonly less than 6%, which dominated by the micro and meso-pores porosity. The anthracite permeability mainly related to the development of micro and macro-fractures, while the permeability of bituminous and sub-bituminous coals related not only to the fractures but also to the pores.

    Sedimentary Characteristics and Coalaccumulation Pattern of the Xishanyao Formation in Southern Margin Area of Junggar Basin
    JIANG Ke-qing, TIAN Ji-jun, WANG Li-jin, PENG Xue-feng, WANG Wei
    2010, 24(6):  1204-1212. 
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    Based on the analyses of data about drills, loggings, outcrops and palaeophytes, this paper studied the sequence stratigraphy of the Xishanyao Formation in southern margin area of Junggar basin. Two sequences of SQ1 and SQ2 were identified with the classic sequence stratigraphy method, and six system tracts were subdivided according to the superposition style of strata and sedimentation cycle. The characteristics of sedimentary evolution of the Xishanyao Formation were also defined by analyzing the sedimentary environment. In sequence SQ1, a river-dominated delta was developed; a stable peat swamp was formed in the lake edge and flood plain area,and stable and thick coal seams were also formed after a long-time and wide-range intense coal accumulation. In sequence SQ2, owing to the tectonic transformation and the strong denudation, the coal accumulation was gradually weakened. The result provides the basis for further exploration of coal resources in the Xishanyao Formation in southern margin area of Junggar basin.