Most Down Articles

    Published in last 1 year | In last 2 years| In last 3 years| All| Most Downloaded in Recent Month | Most Downloaded in Recent Year|

    All
    Please wait a minute...
    For Selected: Toggle Thumbnails
    Research on Secondary Development of Old Oilfields and CO2 Flooding Technology
    HU Bin1,2, HU Wenrui3, LI Xiusheng1, BAO Jingwei4
    null    2013, 34 (4): 1-1.  
    Abstract90)      PDF(pc) (300KB)(1688)       Save
    The necessity and feasibility of EOR in old fields were analyzed and the basic concept and approaches for old fields’secondary development were elaborated, including the main mechanism, mode and efficiency of CO2 flooding and the related researches and experimental progress at home and abroad, as well as the prospects of such secondary development and technologies for CO2 flooding. The core of secondary development or "redevelopment" is to rebuild new development systems by means of new development ideas and new technologies in order to substantially tap potentials and improve ultimate oil recovery of the old or maturing oilfields, including reconstructing the geological knowledge, the well pattern and ground technological process, etc. The practices show that CO2 flooding can not only improve the old oilfields’recovery, but also restore carbon and protect environment. The researches of related theories and technologies have been carried out effectively and shown good results at home and abroad. The combination of old field redevelopment and CO2 flooding is the trend of EOR and one of the key technologies in China in the future
    Related Articles | Metrics
    Differentiated Hydrocarbon Enrichment Factors of Bedrock Gas Reservoir in Piedmont Belt of Altun Mountain, Qaidam Basin
    SUN Xiujian, MA Feng, BAI Yadong, WANG Bo, GUAN Bin, LUO Na, WEI Shunke
    Xinjiang Petroleum Geology    2020, 41 (4): 394-401.   DOI: 10.7657/XJPG20200403
    Abstract345)   HTML16)    PDF(pc) (7470KB)(1563)       Save

    The bedrock gas reservoir whose formation is closely related to structural uplift and fault activity is mainly distributed in the piedmont belt of the basin margin and has the characteristics of differentiated hydrocarbon accumulation. Based on the systematic teasing of the main reservoir-forming factors of the bedrock reservoir in the piedmont belt of the Altun Mountain in Qaidam basin and combined with the exploration status worldwide, the paper summarizes the differentiated hydrocarbon accumulation in the bedrock reservoir. The study results show that there are four main factors controlling the formation of the bedrock reservoir in the piedmont area of Altun Mountain: 1.Several local hydrocarbon generating centers in Jurassic strata control the distribution and abundance of the bedrock gas reservoir in the piedmont zone. 2.There are three tectonic steps including uplift belt, slope belt and depression area in the piedmont belt, and the bedrock traps in the slope belt near hydrocarbon generating center are featured with the priority of oil and gas charging and good preservation, which are favorable for reservoir forming. 3.The distribution of high-quality bedrock reservoir in the piedmont belt which is controlled by multiple factors such as lithology of bedrock and intensity of weathering and leaching affects the local enrichment of the bedrock gas reservoir. 4.As a result of multistage tectonic activities, the formation period and activity intensity of the faults in the piedmont belt are different, which control the bedrock trap formation and differentiated hydrocarbon accumulation. It is concluded that the differences in source rock distribution, reservoir development, structural framework and fault activity jointly contribute to the differentiated hydrocarbon accumulation in the bedrock reservoir in the piedmont belt of Altun Mountain.

    Table and Figures | Reference | Related Articles | Metrics
    The Physical Chemistry Explanation of the Capillary Condensation and the Circuit of Adsorption-Desorption
    WANG Zheng-de, ZHANG Mao-lin, MEI Hai-yan, SUN Liang-tian, LI Shi-lun, WU Qing-song
    Xinjiang Petroleum Geology    2002, 23 (3): 233-235.  
    Abstract321)      PDF(pc) (886KB)(1462)       Save
    The desorption lag phenomenon is often appeared when measuring the adsorption isotherm of the porous media, that is the desorption isotherm is higher than the adsorption isotherm at the same pressure, shaping the circuit of adsorption and desorption. The Kelvin equation to be used for describing the relationship between a small drop and a plane of liquid is derived from the basic metastabel state theory of physical chemistry. The capillary condensation phenomenon, the adsorption-desorption circuit, and the capillary pressure effect on the phase equilibrium of the oil-gas system are well explained by using the Kelvin equation.
    Reference | Related Articles | Metrics
    New Classification Scheme of Limestones
    JIN ZhenkuiShao Guanming
    null    2014, 35 (2): 1-1.  
    Abstract102)      PDF(pc) (300KB)(1043)       Save
    Classification of limestones is the foundation for study of limestone origin and sedimentary facies. Because of the existence of various problems in previous classification schemes of limestones, no classification scheme of limestones is widely accepted at present in China. So different scholars adopt different classification schemes, resulting in chaos in naming and classification of limestones, such as different names for one limestone, or different implications for one name. On the basis of analysis of previous classification schemes, this paper proposes a new classification scheme of limestones. Based on the types and content of textural components, limestones are divided into limemudstone, grain?bearing limemudstone, grainy limemudstone, grainstone (including limemud grainstone and sparry grainstone), reef limestone (including limemud reef limestone and sparry reef limestone), reef clast limestone (including sparry reefclast limestone and limemud reefclast limestone). Each type can be divided further based on grain type and reef?building organism type or based on mineral components by Class?3 nomenclature
    Related Articles | Metrics
    EMPIRICAL STATISTIC M ETHOD OF OIL-W ATER INTERFACIAL TENSION
    Bi Haibin, Wang Yinghui, Lu Guoming
    Xinjiang Petroleum Geology    1996, 17 (2): 173-176+205.  
    Abstract149)      PDF(pc) (336KB)(999)       Save
    Reference | Related Articles | Metrics
    The Discovery, Characteristics and Prospects of Commercial Oil and Gas Layers/Reservoirs in Sichuan Basin
    LUO Zhili1, HAN Jianhui1, LUO Chao1, LUO Qihou2, HAN Keyou2
    null    2013, 34 (5): 1-1.  
    Abstract215)      PDF(pc) (2515KB)(967)       Save
    The oil and gas exploration efforts in Sichuan basin have been more than half a century. As a mature exploration or high mature basin, eight industrial/commercial gas reservoirs and one oil reservoir were found from the Late Proterozoic Sinian system to the Jurassic red bed, people called it“full basin gas and half pot of oil”, so Sichuan basin is a unique basin among petroleum basins in China. The discoveries and experiences of the oil and gas explorations are worth reviewing and summarizing, the hydrocarbon accumulation characteristics and prospects are worthy of probe and outlook, so as to strengthen the confidence that more oil and gas resources will be found. According to the experiences of the researches and explorations of the oil and gas fields in Sichuan basin, the authors consulted a large number of relevant information, analyzed the main characteristics and current situations of various industrial/commercial oil and gas reservoirs and accumulation, and put forward some conclusions and suggestions that Sichuan basin still has great oil and gas prospects, their exploration is promising, etc., which could be as references for the colleagues and decision makers
    Related Articles | Metrics
    EOR Study in Beibu Gulf Oilfield by Associated CO2 Injection Process
    XU Huai-yin, ZHANG Bao-sheng
    Xinjiang Petroleum Geology    2011, 32 (6): 627-628.  
    Abstract129)      PDF(pc) (218KB)(894)       Save
    By screening and assessment, the C oil field located in Beibu Gulf is chosen as the place for EOR to inject the CO2 discharged from the terminal of gas field in Hainan Island. According to the oilfield conditions, when the rate of injected CO2 reaches 1 000 t/d, it is just accordant with the requirement of stable CO2 injection for 20 years. Although paving 180 km pipeline is expensive, the benefit from EOR by CO2 injection process will be greater, not only offsetting the cost invested at the early stage, but also gaining a lot of profit. If carbon tax and carbon trade are implemented in China, the CO2 injection process for EOR will be more promising.
    Reference | Related Articles | Metrics
    Chaotic Theory and Its Application in Fluid Mechanics
    NING Zheng-fu, YAO Yue-dong, LI Guo-zhen, GE Jia-li
    Xinjiang Petroleum Geology    2002, 23 (2): 170-172.  
    Abstract171)      PDF(pc) (156KB)(890)       Save
    This paper reviews the importance and advantages of chaotic theory applied in nonlinear science. The basic principle,research methods and the application in solving complex natural science of this theory are described. The application in fluid mechanics is highlighted. The possibility of using chaotic theory in complex system of oil and gas flow in porous media is analyzed, showing that taken the theory as a guide,the study of percolation mechanics will be deepened further.
    Reference | Related Articles | Metrics
    Exploration History and Enlightenment in Junggar Basin
    CHEN Lei, YANG Yiting, WANG Fei, LU Hui, ZHANG Yidan, WANG Xin, LI Yanping, LI Chen
    Xinjiang Petroleum Geology    2020, 41 (5): 505-518.   DOI: 10.7657/XJPG20200501
    Abstract811)   HTML40)    PDF(pc) (5958KB)(857)       Save

    To write the book of Petroleum Geology of China, first we summarize the petroleum geological theory, exploration targets and results, review the exploration history and analyze the drilling, seismic, reserves and other historical data, then divide the exploration history of the Junggar basin into five stages — surface geological survey and drilling in the southern margin (before 1954), discovery and expansion of Karamay oilfield (1955-1977), strategic development of eastern oil and gas fields (1978-1989), fast breakthrough to desert oil and gas fields in the hinterland (1990-2002) and large-scale development of hydrocarbon-rich sags (2003-), and finally based on the important exploration results and milestone data of all stages, point out the exploration enlightenment and accumulation models that have important influences on exploration, including structural oil-bearing model in overthrust fault zones, large-area above-source and fan-controlled accumulation model in sags, stepped outer-source, along ridge and fault-controlled accumulation model, inner-source self-generation and self-preservation accumulation model of volcanic rocks, and accumulation models with upper, middle and lower assemblages in the southern margin. These findings are expected to have important enlightenment for future exploration.

    Table and Figures | Reference | Related Articles | Metrics
    Fluvial Facies Styles and Their Sedimentary Facies Models
    ZHANG Jinliang
    null    2019, 40 (2): 1-1.   DOI: 10.7657/XJPG20190220
    Abstract346)      PDF(pc) (300KB)(845)       Save
    The paper carries out the sedimentological analysis on fluvial styles and divides the channel system into single channel and multiple channel (or composite channel) systems. Straight channel, meandering channel and braided channel belong to single channel system, while anastomosed channel and other distributive fluvial systems belong to multiple channel system. Thick point bar, channel thalweg-filling sediment and counter point bar are the parts of meandering fluvial facies. An upward-finning meandering channel sequence is mainly composed of several microfacies such as thalweg deposit, sand bar complexes and over-bank fines. The architecture of a braided channel sandbody is very complex, and various large scale bedforms are distributed crisscrossly, the sandbodies in the channel can be divided into mid-channel sand bar, mid-channel sand sheet and several non-framework microfacies. The anastomosed river may be composed of braided river, meandering river and straight river, in another word, the single channel of anastomosed river can be divided into bedload channel, mixed-load channel and suspended-load channel. Terminal fan, meandering river fan, braided river fan and even some subaerial delta systems can be summarized into the distributive fluvial system. In fact, in the distributive fluvial system, the nature of the river has changed and the channel has been transformed from a confined channel to an unconfined channel. The concept of the distributive fluvial system is too general and broad, across the boundaries of different systems. There are many limitations in precise characterization of fluvial microfacies due to the great differences among different fluvial sand bodies
    Related Articles | Metrics
    Application of Petrel Software to 3D Fine Geologic Modeling
    SHI Xiao-yan
    Xinjiang Petroleum Geology    2007, 28 (6): 773-774.  
    Abstract554)      PDF(pc) (202KB)(782)       Save
    The precision of a geologic model is the most critical step for fine reservoir description, not only relating directly to the accuracy of numerical reservoir simulation, but also affecting the validity of a prediction scheme. The Cretaceous reservoir in Lianmuqin oil field is one with complicated fault system and edge-bottom water. Petrel software is used for the 3D geologic modeling in this block, which features a full use of drilling, seismic, well log and stratigraphic correlation data. This paper presents a practical 3D geologic model through seismic inversion, integrated with lithofacies curves and porosity and permeability curves as well as evaluations of various stochastic models and modeling methods available
    Reference | Related Articles | Metrics
    Formation Conditions and Segment Corelation of the Giant OilGas Fields in Passive Continental Margin Basins in West Africa
    WEN Zhixin1, WAN Lunkun1, WU Yadong2, HE Zhengjun1, WANG Yonghua1
    null    2013, 34 (5): 1-1.  
    Abstract75)      PDF(pc) (1916KB)(769)       Save
    Based on plate tectonics theory and various useful information or data, this paper presents the formation and evolution procedures of the coastal prototype basins in West African, the stage correlation of paleo?sedimentary environment changes and their controlling effects on the giant oil?gas fields’formation conditions, and develops the hydrocarbon accumulation modes for the giant oil?gas fields in such three stages and four types of basins. It suggests that the three? segment basins in this area underwent three prototype stages such as the Late Jurassic?Early Cretaceous intra?continental rift stage, the Early Cretaceous intercontinental rift as a transition stage and the Early Cretaceous passive continental margin as a drift stage in West Africa. In the south segment formed the rift sequence structural?lithologic mode, due to little passive continental margin sequence; in the middle segment, the salt?bearing basins were characterized by transitional intercontinental rift halite, with the upper and the lower drift marine and rift lagoonal sediments which are all as premium source rocks,whereas the halite and marine shale as premium cap rocks, forming“dual?source and dual?seal”mode; in the north segment, the transitional basins were of great thickness of drift marine sediments, where narrow shelf and steep slope gave rise to drift turbidite sand bodies mode. Also, Niger delta basin with the unique high construction base formed“delta turbidite sand body”mode, in which the inner?ring rolling anticline belt is of the richest oil and gas, and giant oil?gas fields have been found in the turbidite sand bodies in the central anticline belt with muddy anticline belt and the outside?ring thrust and compressional anticline belt
    Related Articles | Metrics
    Segmentation of Sub-Andean Retro-Arc Foreland Basins in Western South America
    JU Liang, ZHANG Guang-ya, WEN Zhi-xin, WANG Wei-guang
    Xinjiang Petroleum Geology    2011, 32 (4): 431-434.  
    Abstract166)      PDF(pc) (580KB)(755)       Save
    Sub-Andean retro-arc foreland basins in the western margin of South America are important petroleum accumulation and production zones, and develop in three different tectonic settings: evolvement of Caribbean plate superimposed Andean-type foreland compressive deformation in the north; Sub-Andean foreland basins were in long-term the Gondwana continental marginal setting, subsequently subducted by oceanic plate and thrusted by Andean orogenesis in the middle; the shapes and evolvement of basins in Patagonia were more influenced by Gondwana breakup and opening of Atlantic in the south. Based on the evolvements and petroleum characteristics, the sub-Andean retro-arc foreland basins in the western margin of South America could be divided into 6 segments.
    Reference | Related Articles | Metrics
    Petroleum Exploration Achievements and Future Targets of Tarim Basin
    TIAN Jun
    null    2019, 40 (1): 1-1.   DOI: 10.7657/XJPG20190101
    Abstract330)      PDF(pc) (300KB)(750)       Save
    Ever since the foundation of Tarim Oilfield Company on April 10, 1989, great achievements have been obtained in 3 major fields: Kuqa foreland depression, carbonate rocks and clastics in the platform region with the cumulative proved oil and gas reserves amounting to 2.88 billion tons (equivalent). Tarim oilfield has become the major source area for the West-to-East natural gas transmission project and the third large oil and gas field in the mainland China. During the past 30 years of exploration practice, geological understandings about the foreland Kuqa depression, Southwest depression, carbonate rocks in the platform region and clastics in the platform region were continuously deepened, and the source rock, reservoir-cap rock assemblage, structure style, trap and reservoir model were identified for the 3 petroleum systems such as Kuqa depression, platform region and Southwest depression. The remaining exploration potentials of Tarim basin are enormous. The fine exploration should be carried out in the Kelasu tectonic belt of Kuqa depression, clastics in the western Tabei uplift, Ordovician Yijianfang formation in Tabei—Manxi area. The researches and exploration of Qiulitage tectonic belt in Kuqa depression, Jurassic series in the northern tectonic belt, Ordovician deep series in the platform region, Cambrian subsalt strata and piedmont area in the Southwest depression should be strengthened and the strategic breakthrough can be made
    Related Articles | Metrics
    FORTY YEAR'S REVIEW AND PROSPECT FOR PETROLEUM EXPLORATION IN TARIM BASIN
    Wang Qiuming, Zhang Jiyi
    Xinjiang Petroleum Geology    1992, 13 (4): 285-293.  
    Abstract73)      PDF(pc) (836KB)(749)       Save
    Related Articles | Metrics
    Discussion on Shale Oil in Jimsar Sag, Junggar Basin
    CAO Yuanting, PAN Xiaohui, LI Jing, ZOU Yang
    Xinjiang Petroleum Geology    2020, 41 (5): 622-630.   DOI: 10.7657/XJPG20200518
    Abstract498)   HTML27)    PDF(pc) (683KB)(729)       Save

    Two conclusions have been existent about the crude oil of the Lucaogou formation in the Jimsar sag, Junggar basin. One conclusion classifies the crude oil as tight oil, and the other as shale oil. According to two national standards - Geological Evaluation Method for Tight Oil and Geological Evaluation Method for Shale Oil, the classification of the crude oil in the Lucaogou formation is determined. The studies show that, based on the source-reservoir relationship and layer thickness statistics, the crude oil in the Lucaogou formation of the Jimsar sag is shale oil; based on the occurrence, source-reservoir relationship and oil accumulation model, the oil is determined as shale oil which accumulates between layers. In terms of the geochemical parameters of the source rock, the lithology and physical properties of the reservoir, the parameters of the oil reservoir, fracture development and brittleness, this study investigates how the characteristics of the shale oil in the Lucaogou formation are different from the typical shale oil at home and abroad. The results show that the shale oil in the Lucaogou formation is of low to middle maturity, but a large amount of hydrocarbons have been generated and expelled in the early stage; the reservoir has high porosity, but its permeability is obviously low; the oil saturation of the reservoir is high and the oil is characterized by high density, high viscosity, low gas-oil ratio and poor fluidity. Natural fractures in the reservoir are not developed, and the brittleness calculated with the rock mechanical method is poor.

    Table and Figures | Reference | Related Articles | Metrics
    Diagenesis of Tongbomiao Volcanoclastic Rocks in Tanan Sag in Hailaer-Tamuchag Basin, Inner Mongolia
    MA Limin1, LIN Chengyan1, WEN Gangfeng2,3, NI Xiaohua1
    null    2013, 34 (2): 1-1.  
    Abstract58)      PDF(pc) (300KB)(685)       Save
    The cores, thin?section and SEM data were used to research the diagenesis of volcaniclastic rocks and its effects on reservoir quality of Tongbomiao formation in Tanan sag in Inner Mongolia. The results show that the volcaniclastic rocks of Tongbomiao formation mainly consist of ignimbrite, tuff, tuffites, tuffaceous sandstone and tuffaceous conglomerate. In addition to the compaction, cementation and dissolution, the diagenetic characteristics of the volcanoclastic rocks are of peculiar properties, compared with normally sedimentary clastic rocks, such as clinkering process, devitrification and recrystallization. The clinkering and devitrification processes result in abundant secondary pores which improve the physical property of the reservoir. The existence of microcrystalline quartz cladding is beneficial to the conservation of primary intergranular porosity. The compaction and the carbonate cementation are mainly factors to allow the reservoir quality to be poor
    Related Articles | Metrics
    Influences of Reservoir Heterogeneity on Gas Channeling During CO2 Flooding in Low Permeability Reservoirs
    JIA Kaifeng1, WANG Yuxia1, WANG Shilu1, JI Dongchao2a, LIU Bin2b, ZHANG Ruiyao1, GAO Jindong1
    null    2019, 40 (2): 1-1.   DOI: 10.7657/XJPG20190214
    Abstract140)      PDF(pc) (300KB)(684)       Save
    In order to improve the oil recovery of CO2 flooding in low-permeability reservoirs and inhibit the CO2 channeling, the paper studies the influences of reservoir heterogeneity on gas channeling during CO2 flooding through laboratory experiments. On the basis of the experimental results, the characteristics of the oil production, ultimate oil displacement efficiency, gas breakthrough time, gas channeling time and pressure drop of different models are analyzed. The results show that vertically, the smaller the permeability contrast is, the later the gas channeling time will be; horizontally, the results of the model with high injection rate and low recovery factor are better than that with low injection rate and high recovery factor, that is, the higher the permeability at the inlet end,the later the CO2 channeling time, the better the oil displacement effect. The study result provides a beneficial support for the low permeability reservoir development in the Ordos basin
    Related Articles | Metrics
    Petroleum Exploration History and Enlightenment in Tarim Basin
    TIAN Jun
    Xinjiang Petroleum Geology    2021, 42 (3): 272-282.   DOI: 10.7657/XJPG20210303
    Abstract893)   HTML40)    PDF(pc) (2661KB)(678)       Save

    After summarizing the petroleum exploration history in the Tarim basin since 1950 from the points of major exploration areas and targets, exploration ideas, geological understandings and exploration technology and achievements, the exploration process for over 70 years in the basin can be divided into 4 stages: (1) Uphill exploration in the piedmont of the margin of the basin from 1950 to 1983; (2) Breakthrough to the cratonic area through conducting 6 times of exploration in the basin, and making many discoveries in cratonic clastic reservoirs from 1984 to 1996; (3) Great breakthrough in Kuqa piedmont area through persisting on “4 equal stresses” and strengthening technical research from 1997 to 2005; (4) Breakthroughs to subsalt thrust belts in the Kuqa foreland basin and to the fractured-vuggy carbonate rocks in ultra-deep exploration areas through focusing on three “battlefields” since 2006. As the first basin targeting ultra-deep exploration in China, it is necessary to summarize the hydrocarbon accumulation laws and exploration experiences. Due to low geothermal gradient and early-deposited effective source rocks, large-scale effective reservoirs may exist and accumulate in ultra-deep layers and large-scale hydrocarbon enrichment zones form. They are potential targets for future exploration, especially in the basin with low geothermal gradient in the central and western parts. The ultra-deep exploration practice in the Tarim basin has proved that persisting on technical research and innovation, conducting 3D seismic survey before drilling wildcat wells, and running integrated exploration and development are successful ways to make fast and large-scale exploration discoveries.

    Table and Figures | Reference | Related Articles | Metrics
    Experimental Study on the Phase Behavior and Fluid Physical Parameters of High CO2Content Natural Gas
    BIAN Xiaoqiang, DU Zhimin
    null    2013, 34 (1): 1-1.  
    Abstract73)      PDF(pc) (300KB)(672)       Save
    The JEFRI?PVT apparatus from DBR Company of Canada was used to test the phase transition from well bottom to well head and the physical parameters of high CO2 ? bearing natural gas, such as compressibility factor (Z?factor), formation volume factor (FVF), compressibility, and density. The experimental results show that no phase transition can be defined at experimental ranges, and with pressure rising, the Z?factor decreases and then increase(the minimal value appears at about 15 MPa), the density rises and both FVF and compressibility decrease (the decreasing amplitude at low pressure is larger than that at high pressure);with CO2 content increasing, the Z?factor decreases and the density increases (the increasing amplitude at high pressure is more obvious than that at low pressure), and both FVF and compressibility have little change; with temperature rising, the Z?factor increases (the biggest change arrives at about 15 MPa), the FVF rises(the increasing amplitude at low pressure is more obvious than that at high pressure), the density decreases (the decreasing amplitude at high pressure is more obvious than that at low pressure), and compressibility has little change
    Related Articles | Metrics
    Research Progress on Shale Oil Mobility Characterization
    ZHU Xiaomeng1, ZHU Wenbing1, CAO Jian2, SONG Yu1, ZHANG Dongmei1, HU Shouzhi1, LI Shuifu1
    null    2019, 40 (6): 1-1.   DOI: 10.7657/XJPG20190617
    Abstract318)      PDF(pc) (300KB)(670)       Save
    The mobility of shale oil and its characterization are key issues of shale oil study. The paper reviews the research progress on shale oil mobility characterization and proposes the study directions for shale oil mobility characterization. Shale oil mainly has 2 kinds of occurrence, namely adsorbed state and free state. The former is the main contributor for petroleum productivity so that the free oil mobility and its characterization are very important. The research methods of free oil can be divided into 2 categories such as direct characterization and indirect calculation. Direct characterization is subdivided into pyrolysis method and extraction method, but the experiment and analysis processes of the both methods are very complicated. Indirect calculation method is subdivided into the calculation method based on oil saturation of shale and the difference subtraction method based on the difference between the total shale oil content and the adsorbed shale oil content, the former leads to large errors and higher calculation results and the latter can obtain the theoretical max. mobile oil content. The accuracy of the latter method depends on the determination of the adsorbed shale oil content. The adsorption to oil mainly occurs in the organic matter of shale, but the mechanism of adsorption of organic matter to shale oil still remains unclear. Therefore, the investigation and determination of the adsorption capacity of kerogen to liquid hydrocarbons and its product composition variations and further revealing the adsorption mechanism of kerogen to shale oil are the new directions of the study on shale oil mobility characterization
    Related Articles | Metrics
    On Oil and Gas Resources in Marine Carbonate Basin of Central-Western China
    XU Xiao-song, WANG Zheng-jiang
    Xinjiang Petroleum Geology    2002, 23 (5): 366-371.  
    Abstract84)      PDF(pc) (2607KB)(664)       Save
    The onshore marine hydrocarbon-bearing basins of China are mainly distributed in Tethyan tectonic domain. From Ptoterozoic to Mesozoic, marine basins like Tarim, Ordos and Sichuan with cratonic basement are of enormous potentials in resources. They are major areas for petroleum exploration and development in China. Two structural strata of the marine basins are developed in Caledonian movement and Hercynian-early Indo-China movement for China's old land sedimentary and tectonic evolutions. The evolution of marine basins in early Paleozoic occurred as hydrocarbon source rocks with transgressive sequence and regressive sequence; during late Paleozoic-early Indo-China movement, the transgressive sequence was dominated by reservoir rocks, deposited secondarily by hydrocarbon source rocks; while the deposits of the regressive sequence developed both hydrocarbon source rocks and reservoir rocks. It is shown from exploration and development of these basins that they have three generalities in hydrocarbon generation,accumulation and forming reservoirs, i. e, the prototype basinal evolution is similar to the depositional sequences with five sets of hydrocarbon source rocks (Z2、€1、O1、O2-3、S1); in Caledonian movement formed failed foreland basins, deep basins and multistage exposed and corrosive surfaces occurred with palaeo-uplifts and structural tilting; the carbonate rocks with paleo-karst and overlapping Upper Paleozoic shaped reservoir system. The paleogeographic migration and the time deference of structural evolution resulted in the diversity between northern and southern basins.
    Reference | Related Articles | Metrics
    The Composite Regional Stratigraphic Classification in Tarim Basin and Its Circumferences
    HUANG Zhi-bin, WU Shao-Zu, ZHAO Zhi-xin, LI Meng, TAN Ze-jin, DU Pin-de
    Xinjiang Petroleum Geology    2002, 23 (1): 13-17.  
    Abstract197)      PDF(pc) (924KB)(658)       Save
    This paper summarized an achievement in recent 20-year researches of stratigraphic deposition and structures in Tarim basin. Based on the studies in the past,the necessary regulations have been made to Tarim basin (particularly to the basin's covered area), and one stratigraphic region has been divided into, which includes eleven subregions and twenty-nine minor regions. The circumferences of each formation unit and related depositional characteristics are summarized.
    Reference | Related Articles | Metrics
    Review of Natural Gas Industry in Kazakhstan and Proposals for SinoKazakhstan Cooperation
    MING Haihui
    null    2013, 34 (4): 1-1.  
    Abstract92)      PDF(pc) (300KB)(645)       Save
    Located in the hinterland of Central Asia, Kazakhstan is the largest country in oil and gas resources in Central Asia area, and the oil and gas industry is its pillar industry of the national economy. In recent years, Kazakhstan has taken measures to enhance the level of its oil and gas industry development by attracting foreign investment, technological innovation, merger and acquisition, etc. Over the past decade, the total oil?gas production of Kazakhstan increased by 6 times. In 2011, the production of crude oil, condensate and natural gas reached 8 006×104 t and 395×108 m3, respectively. With the tension of oil resources supply, rising of oil prices and increase of domestic gas demand, Kazakhstan modified resources law and promulgated natural gas law. These more pragmatic policies aim to continually strengthen the regulation and utilization of oil and gas resources, safeguard the interests of the country. Based on the development status and prospect analysis of the natural gas industry of Kazakhstan, the proposals for Sino?Kazakhstan cooperation in oil and natural gas are given in this paper
    Related Articles | Metrics
    Study on Petroleum Geology versus Fundamental Subjects
    LI De-sheng
    Xinjiang Petroleum Geology    2005, 26 (2): 217-220.  
    Abstract124)      PDF(pc) (955KB)(641)       Save
    The development of petroleum geology depends upon the innovation of relevant theories and technologies. In te1ms of hydrocar-hon generation, geodynamics and reservoir characterization that are the most fundamental subjects contained in petroleum geology, this paper discusses the conditions for generating thought of innovation, and points out that connecting link between the preceding and the fol-lowing and getting rid of the stale and bring forth the fresh are the ruotivity of tbe innovation; being practical and realistic and being es-tablished in plentiful firsthand information are the bases of it; diligence and independent thinking are the key of it, and the innovations of theory and technology b1ing by all means into growing production capacity. These views are more constructive to all petroleum geologists. especially to young generation of them today.
    Reference | Related Articles | Metrics
    On Volcanic Activity and Generation of Hydrocarbons
    GUO Zhan-qian
    Xinjiang Petroleum Geology    2002, 23 (1): 5-10.  
    Abstract196)      PDF(pc) (626KB)(636)       Save
    The volcanic body and intrusive rock body shaped by volcanic activity can form thermal source kitchen bodies into depositional rocks. In terms of sequence relations between volcanic body or intrusive body and source rocks. it can be divided into upper,middle and lower kitchens,which become a kitchen-like hydrocarbons generating model. So it is the volcanic activities that offer the earth's deep inorganic origin non-hydrocarbons gases(CO,CO2,H.etc.) into sedimentary basins. The gases may compound-generated mechanism occurring in the cap rocks of the basin. In addition,the inorganic gases from the deep of the earth contain methane carbon isotope of ≥-25‰,methane homolog carbon isotope composition could generate re-successional arrangement of inorganic methane gas followed by shaping inorganic methane gas reservoir. The volcanic activity conveys magmatic rock for a sedimentary basin,in which the hydrocarbon material such as methane, alkene, alkyne, etc. occurs in mantle rock, while crystalline rock in magmatic rock contains methane material,and exist the trend that the hydrocarbon content increases with the gravity increasing, so is volcanic rocks in magnetic rock, including carbon atomicity increasing. By volcanic activities a sedimentary basin may also get hydrothermal fluid, some metal elements (Fe, Mn, Zn, Cu, Pd) carried by water may accelerate the amounts of hydrocarbons generation. Therefore, it is indicated that the sedimentary basin with two-component cap structure appearsa catalytic hydrocarbon generation model.The conclusion shows that the effect of a volcanic activity on a basin with two-component cap structure could increase or accelerate its hydrocarbon generation. The multiple models give rise to mechanisms of organic, synthetic and inorganic hydrocarbon generation in basins with two-component cap structures.
    Reference | Related Articles | Metrics
    Geochemical Characteristics and Significance of Aromatic Hydrocarbon in Oil and Gas
    WANG Chuan-yuan, DU Jian-guo, DUAN Yi, ZHOU Xiao-cheng, ZHENG Chao-yang, WU Bao-xiang
    Xinjiang Petroleum Geology    2007, 28 (1): 29-32.  
    Abstract189)      PDF(pc) (132KB)(628)       Save
    This paper reviews the application and advances of aromatic hydrocarbon biomarker in petroleum exploration and development, such as depositional environment, input of organic matter, migration, oil source correlation and thermal maturity. The result indicates that alkylnaphthalene and aromatic sulfur compounds are indicative of depositional environment and type of organic matter. Fluoranthene, perylene, pyrene benzo-pyrene and benzopyrene have been proposed as the input of terrigenous higher plant. Methylnaphthalene ratio and Methylphenanthrene index increase with the thermal maturity. The relative distribution of dibenzothiophene is well used for maturity assessment. The ratios of perylene to benzofluoranthene and perylene to benzo (e) pyrene are an effective index of thermal maturity. It is determined that the contents and distribution of pyrrolic compounds and dibenzothiophene are controlled by oil fraction during migration, which has potential significance in evaluating the oil migration and reservoir filling direction. The component of aromatic hydrocarbon in sediment is very complicated, so that great efforts should be made to identify them with more advanced apparatus and improve some biomarker index by experiments and practices.
    Reference | Related Articles | Metrics
    Natural Gas Geology Accelerated the Growth of Natural Gas Reserve in Large Scale in China
    DAI Jin-xing, XIA Xin-yu, HONG Feng
    Xinjiang Petroleum Geology    2002, 23 (5): 357-365.  
    Abstract122)      PDF(pc) (5445KB)(624)       Save
    By the end of 2001, China has demonstrated 191 gas fields with a total proved reserve of 30 023×108m3 and remained recoverable reserve of 16 767.72×108m3. This will help China to be a big gas-producing country. Coal measures mainly generate gases, and oil secondarily. Till the beginning of 2001, the proved reserve of coal-formed gas accounts for 64% of total reserve in China. The present greatest 7 gas fields in China are all coal-formed types, which dominate domestic proved natural gas reserves. Presently, China has found 21 great gas fields, accounting for 59.8% of total gas reserve. There are 7 controlling factors in formation of a great gas field. The article has studied 31 indexes of identifying different natural gases.
    Reference | Related Articles | Metrics
    Sedimentation Model and Exploration Significance of Large?Scaled Shallow Retrogradation Fan Delta in Mahu Sag
    TANG Yong1, XU Yang2, LI Yazhe2, WANG Libao2
    null    2018, 39 (1): 1-1.   DOI: 10.7657/XJPG20180103
    Abstract119)      PDF(pc) (300KB)(621)       Save
    The upper Wuerhe formation of Permian and Triassic Baikouquan formation in Mahu sag and its adjacent areas are a set of near?source coarse deposits under the background of depression basin that are large?scaled shallow retrogradation fan?delta deposits under the background of gentle slope, and 13 lithofacies and 7 sedimentary microfacies are identified based on core observation. Multiple fan deltas are developed on the slope of the sag, and the fan bodies connect with each other. The formation of this kind of large?scaled shallow retrogradation fan delta is closely related to 3 geological conditions. The first is that continuously uplifting periphery ancient mountains and stable river systems provided sufficient provenance for each fan during deposition; the second is that there was a good paleogeographic background such as large basin, shallow water and gentle slope; the third is that continuous lake transgression and multi?stage slope?break are significant conditions for large?sized superposition and merging of sand bodies. A sedimentary model of large?scaled shallow retrogradation fan delta is established, which provides guidance for petroleum prospecting and reserves estimation in Mahu sag
    Related Articles | Metrics
    A New Breakthrough in Exploration of Large Conglomerate Oil Province in Mahu Sag and Its Implications
    TANG Yong, GUO Wenjian, WANG Xiatian, BAO Haijuan, WU Haisheng
    null    2019, 40 (2): 1-1.   DOI: 10.7657/XJPG20190201
    Abstract250)      PDF(pc) (300KB)(620)       Save
    There had been no significant breakthrough in petroleum exploration in Mahu sag of Junggar basin for about 20 years after the discoveries of Mabei oilfield in 1993 and Ma-6 area in 1994. An overall evaluation was conducted regarding the resources, reservoirs and stimulation potential in Mahu sag in the year of 2010. The results showed that the slope area in Mahu sag was the key strategic area for petroleum exploration. Then the exploration idea was changed from the exploration for structures in the fault zones around source to the exploration for lithological reservoirs in the major area within source. Since 2012 more and more discoveries have been achieved successively. Up to now, 6 large reservoir groups have been discovered and 2 large oil provinces have been proved in the south and north, respectively. The incremental OOIP is 12.4×108 t, among which the proved reserves is 5.2×108 t. The discovery of the large conglomerate oil province proves that hydrocarbon could accumulate in the above-source conglomerate reservoirs under the conditions of fracture connecting, and efficient development could be realized in low-permeability conglomerate reservoirs by using fine volume fracturing technology
    Related Articles | Metrics
    On the Usefulness of Usher, Logistic and Gompertz Growth Curves
    YU Qi-tai
    Xinjiang Petroleum Geology    2001, 22 (2): 136-141.  
    Abstract248)      PDF(pc) (801KB)(620)       Save
    The logistic growth curve and the Gompertz growth curve are the special case of the Usher growth curve. Their functional expressions are introduced respectively, which were used for prediction of oilfield development indexes. A repeated dual-variate regression equation aimed to obtain parameters of Usher growth curve is suggested. Based on actual data of oilfield, using Usher, Logistic and Gompertz growth curves as well as a most functional broad sense growth and decline curve, the matching calculation results of mentioned four curves have shown that the generalized growth and decline curve as、 well as the Usher curve are both very well matched with actual value,representing powerful capability of prediction. The Logistic curve, shows relatively good matching result, have relatively good usefulness. However, with respects to Gompertz curve,owing to the narrow range of ratio between the peak output corresponding cumulative pro- duction and maximum recoverable reserve, so the matching result is less good, and this curve is less useful. This paper points out that the future study on growth curve should be oriented to generalized growth curve,which can be applied to the entire procedure of oilfield development.
    Reference | Related Articles | Metrics
    Classification of Carboniferous in Northern Xinjiang
    ZHAO Zhi-xin
    Xinjiang Petroleum Geology    2009, 30 (4): 478-482.  
    Abstract161)      PDF(pc) (288KB)(618)       Save
    Based on the previous studies, the boundary between the Devonian and the Carboniferous and the middle boundary of Carboniferous are discussed. It is suggested that such formations as Yeliemodun, Baiyushan and Hala'alate are all the stratigraphic units for stradding the Upper and Lower Carboniferous. In this paper, the relationships among the Hongguleleng, Hebukehe, Gennaren and Heishantou formations are mainly discussed, and it is proposed that using the Heishantou formation substitutes for the Hebukehe and Gennaren formations.
    Reference | Related Articles | Metrics
    THE RELATIONSHIP BETWEEN P-AND S-WAVE VELOCITY RATIO, MODULUS OF ELASTICITY AND FLUIDS CONTAINED IN ROCKS
    Huang Kai, Xu Qunzhou, Yang Xiaohai, Lai Zhongkang, Zhang Lufei
    Xinjiang Petroleum Geology    1998, 19 (5): 369-371.  
    Abstract158)      PDF(pc) (178KB)(618)       Save
    Based on experimental simulation test of core in western Junggar basin, it is considered that P- and S-wave velocity ratio, Poissons ratio, Youngs modulus and Lames constant of core samples saturated with water are bigger than those of core samples saturated with oil ;while the volume and shear moduluses of core samples saturated with water are smaller than those of core samples saturated with oil.Modulus of elasticity of rock is also related to porosity, the larger the porosity, the smaller the modulus of elasticity, and vice versa.The modulus of elasticity of rock increases or decreases with experimental pressure increasing or decreasing.Above-mentioned characteristics of rock can be basically and possibly used for detection of distribution of oil, gas and water in rock by applying geophysical prospecting data.
    Reference | Related Articles | Metrics
    Compound Attribute as New Method for Pickup and Interpretation of Seismic Attributes
    ZHANG Jun-hua, ZHU Huan, GAO Rong-tao, ZHOU Zhen-xiao
    Xinjiang Petroleum Geology    2007, 28 (4): 494-496.  
    Abstract101)      PDF(pc) (410KB)(613)       Save
    The technologies for pickup of seismic attributes include generally Fourier spectral analysis, autocorrelation, main component, autoregression and coherent body, etc. However, how to get new seismic attributes from the extracted attributes is still insufficiently concerned about. This paper proposes a new seismic attribute-compound attribute and develops the corresponding software package by means of information engineering principle, which is characterized by simple physical significances such as overlay, difference, product and cascade, etc. and sensitive data match and display. The compound attribute is used for the detailed interpretation of fluvial facies reservoir in LHK area, showing that the resolution and the S/N ratio are improved obviously.
    Reference | Related Articles | Metrics
    Petroleum Exploration History and Enlightenment in the Northern Songliao Basin
    MENG Qi’an, LI Chunbai, BAI Xuefeng, ZHANG Wenjing, XUE Tao, PENG Jianliang, TANG Zhenguo
    Xinjiang Petroleum Geology    2021, 42 (3): 264-271.   DOI: 10.7657/XJPG20210302
    Abstract520)   HTML23)    PDF(pc) (1691KB)(604)       Save

    According to the exploration history in the northern Songliao basin, this paper summarizes the research results in different exploration stages and analyzes how the exploration idea in each stage changed and its role to exploring new targets. The Songliao basin went through three stages of oil and gas exploration: exploration of structural oil reservoirs (1955–1985), exploration of lithological oil reservoirs (1986–2010), and exploration of both conventional and unconventional oil and gas reservoirs (since 2011). The enlightment lies in objective geological conditions and the understanding of reservoir forming laws are the foundation for exploration deployment, sustainable theoretical innovation is the guarantee to make breakthroughs to oil and gas exploration, and technological innovation of engineering is the key to keeping steady increase of oil and gas reserves. The mature exploration areas in the basin are still primary exploration targets to discover large and medium-sized oil and gas fields in the future.

    Table and Figures | Reference | Related Articles | Metrics
    Advances in Research on Foreland Basin
    WU Yang-yang, FENG Jun
    Xinjiang Petroleum Geology    2003, 24 (1): 87-91+0.  
    Abstract116)      PDF(pc) (489KB)(601)       Save
    A foreland basin is defined as a sedimentary basin deposited between frontal margin of orogenic belt and its adjacent craton. It can be divided into four structural elements such as wedge-top, foredeep, forebulge and back-bulge depo-zones. There are three kinds of foreland basins classified in terms of origin and location: peripheral foreland basin, retroarc foreland basin and regenerated foreland basin. The evolution of it is a dynamic process with the feature of progressive development. A foreland basin mainly undergoes common processes of topographic load, subduction load, dynamic plate load, thus resulting in lithosphere flexure. A foreland basin always occurs with compressional orogenic belt in pairs, showing distinct coupling and complementary nature. In a foreland basin, the most favorable hydrocarbon accumulation is the following structural locations: faulted-extensional anticline and decollement anticline on thrust faults in floor of double thrust structural zone, fault expanding fold of buried thrust fault front and “triangular domain" included by passive top double thrust structural zones.
    Reference | Related Articles | Metrics
    Discovery and Hydrocarbon Accumulation Mechanism of QuasiContinuous HighEfficiency Reservoirs of Baikouquan Formation in Mahu Sag, Junggar Basin
    ZHI Dongming
    null    2016, 37 (4): 1-1.   DOI: 10.7657/XJPG20160401
    Abstract134)      PDF(pc) (300KB)(600)       Save
    In recent five years, great breakthroughs have been made successively in the Lower Triassic Baikouquan formation in hydrocarbon?rich Mahu sag in the northwestern margin of Junggar basin, and the above?source quasi?continuous oil reservoirs with the reserves over hundreds of millions of tons are firstly discovered, which should be attributed to the changes of thoughtway from structural reservoir exploration to lithological?stratigraphical reservoir and continuous reservoir exploration. Composite analysis on hydrocarbon accumulation mechanism shows that high?quality Carboniferous?Permian source rocks are developed in hydrocarbon?rich Mahu sag, which is favorable for oil generation; high?quality reservoirs and structural?lighological traps of fan?delta front facies are developed in Baikouquan formation, in which faults connect the source rock and the reservoir, which helps hydrocarbon accumulation; gentle structures with good top and bottom conditions in Baikouquan formation are in favor of hydrocarbon enrichment; abnormally high pressure and fractures occur in Baikouquan formation, and the oil here is of good quality and reservoir sweet spots are developed, which is good for high oil production. Therefore, quasicontinuous reservoirs with the reserves of hundreds of millions of tons in Baikouquan formation in Mahu sag are characterized by extensive oil distribution, local oil enrichment, jointly controlled by nose?like structural belts and favorable belts in delta front as well as faults, high?efficiency accumulation and great prospecting potential, which can be an important supplement to continuous?reservoir exploration and research in the world. It is suggested that Huangyangquan fan, Madong fan and Xiayan fan with relatively low exploration degree should be focused on for further petroleum exploration at present
    Related Articles | Metrics
    Geological Characteristics and Exploration Practice of Tight Oil of Lucaogou Formation in Jimsar Sag
    KUANG Lichun1, WANG Xiatian2, GUO Xuguang2, CHANG Qiusheng2, JIA Xiyu2
    null    2015, 36 (6): 1-1.   DOI: 10.7657/XJPG20150601
    Abstract205)      PDF(pc) (300KB)(595)       Save
    The Jimsar sag is formed in the late Hercynian period, transformed strongly in Yanshanian period, and shaped in Himalayan period. Today it’s a half graben?like sag with fault in the west and overlap in the east. The Middle Permian Lucaogou formation distributs in the whole sag with the major sedimentary assemblage of saline shallow lake and deep lake facies. High?quality hydrocarbon source rocks are in the Lucaogou formation, and the organic matter type is mainly the mixed organic matter of Type Ⅰ and Type Ⅱ1 during mature stage.Compared with the tight oil in other regions, sweet spots of tight oil in Lucaogou formation have characteristics of thin monolayers and large vertical span with two concentrated sections of them. For sweet spots reservoir, the predominant lithology is dolomitic fine?silty sandstone,the porosity of core in net confining stress averages 10.8%, the permeability of it ranges from 0.001 mD to 0.6 mD, being dominated by dissolved micropores.
    Related Articles | Metrics
    New Sight about Affect of Authigenic Chlorite on Sandstone Reservoir
    GONG Fan-hao, BAO Zhi-dong, FAN Zheng-ping, WU Xing, LIU Li
    Xinjiang Petroleum Geology    2011, 32 (4): 338-341.  
    Abstract109)      PDF(pc) (456KB)(593)       Save
    Early authigenic chlorite cementation is of significant effect on the conversion, preservation and reconstruction of primary pores, based on the casting thin section and SEM analyses of Triassic Yanchang formation of Jiyuan area in western Ordos basin. It mainly occupies primary pores, converting them into intercrystal pores of clay minerals which can impede the damages of siliceous and carbonate cements to the pores, providing pathways for late fluid reconstruction of reservoirs. Its oil-wet clay mineral attributes provide condition for late hydrocarbon accumulation in low porosity and low permeability reservoirs. Also, the sensitivity of clay minerals should be taken into consideration when developing chlorite cemented reservoirs due to chlorite’s active and easy hydrolysis chemical properties. Though previous studies show an increase in compressive resistance in chlorite cemented reservoirs, this article demonstrates high compactions after the growth of grain-coating chlorite, which means such a compressive resistance may be overstated.
    Reference | Related Articles | Metrics
    The Impact of Clay Minerals on Oil-Gas Reservoir
    ZHAO Xing-yuan
    Xinjiang Petroleum Geology    2009, 30 (4): 533-536.  
    Abstract198)      PDF(pc) (414KB)(586)       Save
    Clay minerals are closed to petroleum geology and drilling-producing engineering owing to their distribution universality, unique crystal structure and physicochemical property. There are different correlations between different clay minerals and sand porosity and permeability; and there exist differentiations in correlativity or correlation coefficient between the same clay mineral and sand porosity and permeability due to its difference in shape and occurrence. Such a most important and potential factor for causing oil-gas reservoir damages appears the fact that different clay minerals could cause different damages of oil-gas reservoir. It is concluded that taking corresponding and advantageous measures for preventing oil-gas reservoir damages based on available studied results of clay minerals can gain stable and high yields of oil-gas reservoirs or fields.
    Reference | Related Articles | Metrics
    Research on Fine 3-D Geology Modeling
    LI Jun-jun, WANG Zhi-zhang, ZHANG Zhi-huan, JIANG Dan, WANG Li-chang, ZHANG Xiao-feng
    Xinjiang Petroleum Geology    2011, 32 (5): 484-486.  
    Abstract120)      PDF(pc) (923KB)(585)       Save
    In the present conditions of computer resources, the digitization of every link of fine reservoir description has been realized. Application of high-precision 3-D geology modeling greatly improves the speed and accuracy of oil-gas reservoir research. 3-D reservoir model provides supports for reservoir numerical simulation and for reservoir evaluation and design of development plan. In Karamay Fengcheng oilfield, the reservoir modeling in some new prospecting districts often appear in such a situation as large area and less well like bull's eye due to a few wells. In order to improve the simulation precision in this oilfield, the adjacent dense well patterns in the old districts are applied to determine variogram which is then used for modeling of sparse well-pattern area, and good effect of modeling has been achieved.
    Reference | Related Articles | Metrics
    Sedimentary Fades of Upper and Lower Youshashan Formation in Altun Slope Area, Qaidam Basin
    DAI Lln, JI You-liang, LIU Cheng-xin
    Xinjiang Petroleum Geology    2005, 26 (2): 172-174.  
    Abstract116)      PDF(pc) (883KB)(581)       Save
    This paper presents the in-depth sedimentary facies characteristics of upper and lower Youshashan formation in Altun slope area, Qaidam basin based on the sequence stratigraphic study, and includes the alluvial fan facies, the fluvial-floodplain facies, the delta facies, the fan-delta facies and the lacustrine facies, etc. Using four second-order sequences identified, plane distribution of each sedimentary facies is discussed, and the Neogene lake basin evolution and eastward movement caused by tectonic uplift are speculated. In terms of pale ostructure, paleoclimate and sedimentary source recharge, the dominant factors for Youshashau sedimentary facies evolution are analyzed.
    Reference | Related Articles | Metrics
    Origin of Low Structures in Central Sichuan Area
    QIN Qi-rong, SU Pei-dong, LI Le, LIU Li-ping
    Xinjiang Petroleum Geology    2005, 26 (1): 108-111.  
    Abstract114)      PDF(pc) (2745KB)(578)       Save
    The origin of structures in central Sichuan area is discussed according to its structural characteristics and the regional tectonic setting of Sichuan basin. It is considered that the structure in central Sichuan area are formed under the regional tectonic stress of Sichuan basin and the local stress derived from the basement structure and different properties during Himalayan tectonic movement. It could be divided into such two stages as the early S-N compression stage and the middle-late NE- -SW compresso-shear stage.
    Reference | Related Articles | Metrics
    Geological Characteristics and Hydrocarbon Accumulation Model for Cenozoic Play in Persian Gulf Basin
    JIA Xiaole1, HE Dengfa1TONG Xiaoguang2
    null    2014, 35 (1): 1-1.  
    Abstract74)      PDF(pc) (300KB)(578)       Save
    There are five hydrocarbon accumulation plays in Cenozoic in Persian Gulf basin, of which the Asmari?Gachsaran play is the most important one. The paleogeography evolution, hydrocarbon source rocks, reservoir rocks, cap rocks and hydrocarbon accumulation process are studied, showing that the Middle Cretaceous hydrocarbon source rock of Kazhdumi formation was deposited in low energy and euxinit environment, and reached hydrocarbon generating/expulsion peak in Early Pliocene. Oil and gas migrated vertically along fractures and finally accumulated in Oligocene?Lower Miocene Asmari fractured limestone reservoir. The Miocene Gachsaran formation provided an effective regional seal for the Oligocene?Lower Miocene Asmari reservoir. The oil and gas accumulation occurred in structural trap formed by lateral compression. The high quality source rocks, favorable reservoir rocks, fractures connecting the source rocks with reservoirs, effective regional/local seals, and the good matching between hydrocarbon generating peak and tectonic activity, fracture, trap forming time are the key of hydrocarbon enrichment in Asmari?Gachsaran play
    Related Articles | Metrics
    Subsalt Structural Styles of Keshen Section in Kelasu Tectonic Belt
    HOU Guiting1, SUN Shuai1, ZHENG Chunfang1, TANG Yangang2, ZHOU Lu2, MO Tao2
    null    2019, 40 (1): 1-1.   DOI: 10.7657/XJPG20190103
    Abstract122)      PDF(pc) (300KB)(570)       Save
    The exploration and development practices in the Cretaceous Bashijiqike formation of the Kelasu tectonic belt in Kuqa depression reveal that the fractures are featured with vertical zonation, which are possibly constrained by neutral surfaces of anticlines. It is necessary to rebuild the structural style of the Kelasu tectonic belt because the present model for structural style classification cann’t explain the vertical zonation of fractures. Selecting the Keshen section of the Kelasu tectonic belt as the study area, taking the interlimb angle of fold as the main element and combining with the fault combination configuration, the paper rebuilds the subsalt structure styles of the Keshen section in the Kelasu tectonic belt on the basis of 3D seismic interpretation. The results show that the structural styles of the Keshen section can be divided into 2 types such as gentle fold and open fold according to the interlimb angle of fold; according to the fault combination configuration, the gentle fold is further divided into double-thrust gentle fold, back-thrust gentle fold and recoil gentle fold, and the open fold is divided into double-thrust and back-thrust open folds. The structures to the north of the Keshen fault are imbricate fault anticlines made up of open and gentle folds, and the structures to the south of the Keshen fault are imbricate structures of gentle-fold faulted anticline. The distribution of fractures is closely related to the interlimb angle, the thickness and the distribution range of tension fissure zones in the open folds are much larger than those in the gentle folds, and faults has an influence on the distribution of the fractures around them. The classification of the structural style provides a foundation for the further study on the fracture development and genetic mechanism of different structural styles
    Related Articles | Metrics
    New Understanding of Delta Depositional Model
    JIN Zhen-kui, HE Miao
    Xinjiang Petroleum Geology    2011, 32 (5): 443-446.  
    Abstract164)      PDF(pc) (412KB)(562)       Save
    Through flume experiment and investigation of modern deltas, it is found that in front delta, underwater distributary channels are not formed, the distributary channels of delta plain disappear immediately once extending to the lake (sea) level; front delta sand bodies are usually sheet-shaped and fan-shaped, instead of ribbon shaped. These are different with the traditional understandings of them. The study suggests that depositional model of fan deltas differs widely from that of river deltas. On alluvial fans and fan delta plain develop two types of topography units: channel and inter-channel, both of which are sandy-conglomeratic deposits. There is not environment for shale or mudstone deposition. The mudstone deposit interbeded with sand-conglomerate is actually formed at pre-fan and inter-fan during regression of alluvial fan or when the alluvial fan is abandoned. The deposits of front fan deltas are dominated by sandyconglomeratic deposit from channel flow and sheet flow. Sand- conglomerates from channel flow form mouth bars, and those from sheet flow form underwater sheet flow shoal, both of which are connected together to shape sheet-like sandy-conglomeratic deposits, and further connected with those of fan delta plain.
    Reference | Related Articles | Metrics
    Divergent Role of "Emei Tafrogeny" on Yangtse Palaeoslab and Tarim Palaeoslab and Its Significance in Geoscience
    LUO Zhi-li, YONG Zi-quan, LIU Shu-gen, ZHAO Xi-kui, SUN Wei
    Xinjiang Petroleum Geology    2004, 25 (1): 1-7.  
    Abstract119)      PDF(pc) (2670KB)(556)       Save
    Many Chinese scholars in geosciences believe that in Early Paleozoic,Yangtse palaeoslab was linked with or not far from Tarim Palaeoslab,based on similarity between palaeobiocoenosis and sedimentary facies. This paper discusses the divergence and convergence of these two slabs and their kinematic features from the "Xinkai tafrogeny" and "Emei tafrogeny" emerged in tectonic evolution history of Paleozoic slabs in China, and sets forth the dynamic mechanism of Y angtse palaeoslab drifting to east from the theory of "Emei mantle plume" . The study suggests that if the judgment of these divergence and drifting to east is acceptable, that Tetys within border of China should be opened first is fimly supported, which is also of big significance in theory of geology to studying global Permian basalt erupting in large scale and simultaneously in some places. In addition, they have much more implications for studying the events of broad biogenic extinction during Late Permian and Early Triassic; for finding out metal deposits of vanadium and titanium magnetite in Altun block and adjacent areas; particularly,for searching for giant oil-gas fields of Lower Paleozoic in Tarim basin.
    Reference | Related Articles | Metrics
    Spatial and Temporal Characteristics of Permian Large Igneous Province in Tarim Basin
    CHEN Han-lin, YANG Shu-feng, LI Zi-long, YU Xing, LUO Jun-cheng, HE Guang-yu, LIN Xiu-bin, WANG Qing-hua
    Xinjiang Petroleum Geology    2009, 30 (2): 179-182.  
    Abstract186)      PDF(pc) (349KB)(554)       Save
    The magmatism of Permian large igneous province (LIP) is a very significant thermotectonic event in process of evolution of Tarim basin. The lithological units of this province consist of brecciated mica-olivine pyroxenite pipe, olivine pyroxenite, pyroxenite, gabbro, basalt, diabase, alkali syenite and syenite dike, being dominated by basalt and diabase. They are not only distributed in the west part of Manjiaer depression and west part of Tabei (northern Tarim) uplift, but also in Tazhong (central Tarim) uplift, Buchu uplift and Taxinan (southwestern Tarim) depression, covering an area of 20×104 km 2 , and there are also 7 thickness centers for residual distribution. The time sequence of the Permian LIP development is as follows: Wajilitag layered rock mass→brecciated mica-olivine pyroxenite pipe→ basalt of Kupukuciman formation (278-292 Ma) →basalt of Kaipaicileike formation (272-288 Ma) →diabase and ultrabasic dikes→ syenite (quartz syenite porphyry) (277 Ma).
    Reference | Related Articles | Metrics
    Achievements and Potential of Petroleum Exploration in Tuha Oil and Gas Province
    LIANG Shijun
    Xinjiang Petroleum Geology    2020, 41 (6): 631-641.   DOI: 10.7657/XJPG20200601
    Abstract888)   HTML1958)    PDF(pc) (932KB)(553)       Save

    Petroleum exploration in the Tuha oil and gas province started in the 1950s, but large-scale oil and gas exploration began in 1980s. Abundant exploration results have been successively achieved in Tuha basin, Santanghu basin, Yin’e basin, etc., and major breakthroughs have been made in the exploration for Jurassic coal-measure oil and gas, Permian-Triassic ultra-deep heavy oil, Paleozoic volcanic oil and gas, and tight oil and gas in Santanghu basin. Some oil-rich sags such as the Taibei sag of Tuha basin and the Malang sag of Santanghu basin have been identified with proved oil and gas reserves (equivalent) of 8.20×108 tons, indicating good economic and social benefits. Over more than 30 years of exploration, the geological understandings of coal-derived hydrocarbons, ultra-deep heavy oil reservoirs, volcanic oil reservoirs, low-pressure oil reservoirs, and tight oil and gas reservoirs have been continuously deepened, the geological theory of oil and gas accumulation and the controlling factors of oil and gas reservoirs have been clarified, and key technologies have been formed for different types of oil and gas reservoirs. The study shows that all the basins in the Tuha oil and gas province are in the stage of medium-low exploration degree, and the remaining exploration potential is large. To keep stable production, next measures should focus on: 1)fine oil and gas exploration in coal-measures, expanding exploration to the Permian and Triassic series, and deepening the exploration in the northern piedmont areas; 2)evaluating the sweet spot intervals and zones in unconventional oil reservoirs, and exploring the Paleozoic oil and gas reservoirs while finely exploring clastic oil reservoirs around Santanghu basin; and 3)taking the Tiancao sag, Chagan sag and other sags in Yin’e basin as the key exploration targets, and confirming favorable exploration blocks.

    Table and Figures | Reference | Related Articles | Metrics
    TYPE CURVES FOR PRODUCTION DECLINE ANALYSIS
    Hu Jianguo, Wu Jianxia, Chen Yuanqian
    Xinjiang Petroleum Geology    1993, 14 (2): 147-151.  
    Abstract179)      PDF(pc) (365KB)(553)       Save
    New type cuIves of dimensionless cumulative prođuction versus dimensionlexs time for production declinc analysis are developed based on Arps’ decline equation. Decline index(n), initial decline rate (Di) and initial production (Qi) can be obtained by macthing field data with the type curves. The reliability of the type curves has been confirmed by well production data.
    Reference | Related Articles | Metrics
    FanDelta Group Characteristics and Its Distribution of the Triassic Baikouquan Reservoirs inMahu Sag of Junggar Basin
    TANG Yong1, XU Yang2, QU Jianhua1, MENG Xiangchao2, ZOU Zhiwen2
    null    2014, 35 (6): 1-1.  
    Abstract96)      PDF(pc) (300KB)(551)       Save
    The Triassic Baikouquan formation in Mahu depression belongs to shallow?water delta deposits under the background of gentle slope, in which gravity?flow lithofacies and fluid?flow lithofacies are developed. There exist six fan dalta systems in peripheral Mahu sag,they are Xiazijie, Huangyangquan, Zhongguai, Karamay, Madong and Xiayan fan dalta systems. According to the ancient slope, provenance supply way, such five types of fan deltas are classified as mountain?pass steep slope, mountain?pass gentle slope, near?mountain gentle slope, near?mountain steep slope and near?alluvial fan steep slope types. The fan?delta front has advantageous hydrocarbon accumulation conditions for the following reasons. It is adjacent to the Mahu sag; its sand bodies are widely distributed and extended to a large distance, and superposed in covering the mid?lower slope areas of the sag; there exist faults connecting underlying oil source rocks; the fan?delta plain facies tight belts on the sides and updip directions can shape effective shielding layers and the lateral and top?bottom lacustrine mudstone is developed as barriers, etc. All these can control the distribution and enrichment of oil and gas in vertical and areal directions.Hence the Mahu slope area possesses a macroscopic geological background for large?scale hydrocarbon accumulation, and the above research results can provide guidance for the lithologic reservoir exploration in Mahu sag
    Related Articles | Metrics
    A Study on Mechanism of Oil Displacement by Imbibition
    LI Chuanliang1, MAO Wanyi2, WU Tingxin3, ZHU Suyang1
    null    2019, 40 (6): 1-1.   DOI: 10.7657/XJPG20190608
    Abstract388)      PDF(pc) (300KB)(549)       Save
    Oil displacement by imbibition is an effective way of oil recovery in fractured reservoirs. However, there is not a unified recognition on its mechanism. In order to clarify the mechanism of imbibition, a study is carried out and some conclusions are obtained in this paper. Imbibition can be divided into cocurrent imbibition and countercurrent imbibition and the imbibition in reservoirs belongs to cocurrent imbibition. Imbibition can also be classified as horizontal imbibition and vertical imbibition, and vertical imbibition is more complicated than horizontal imbibition. All the imbibitions in reservoirs belong to vertical imbibition. Imbibition also includes one-side-contact imbibition, two-side-contact imbibition and all-side-contact imbibition, and the imbibition in reservoirs belongs to all-side-contact imbibition. Imbibition can also be divided into capillary pressure imbibition and buoyance imbibition. Capillary pressure imbibition can only suck water into rocks and expulse oil, while buoyance imbibition can either suck water into rocks to expulse oil or suck oil into rocks to expulse water. The imbibition in reservoirs belongs to buoyance imbibition. Imbibition in larger pores is faster than that in smaller pores. End-effect may retain some oil in rocks, which will decrease imbibition efficiency. Adding surfactant into water can decrease the influence of end-effect. The larger the matrix block is, the higher the imbibition recovery efficiency will be, but the longer time will be taken for imbibition. The matrix block size and reservoir rock fragmentation degree during volumetric fracturing can be optimized through experiments
    Related Articles | Metrics
    The Enlightenment from Comparative Studies of the Coalbed Methane (CBM) Development at Home and Abroad
    CAO Yan, LONG Shengxiang, LI Xinzi, HU Xiaohu, WANG Chuangang, WANG Feng
    null    2014, 35 (1): 1-1.  
    Abstract90)      PDF(pc) (300KB)(547)       Save
    The United States, Canada, Australia and other countries have entered the stage of commercial development and utilization of CBM resources. China’s CBM resource amounts with burial depth of less than 2 000 m are basically equal to natural gas resource amount. So fully development and utilization of CBM resources is of great significance to improve the energy structures of China. However, China’s CBM commercial development is still in the initial stage, there exists big gap with the United States, etc. To realize the rapid and sound de? velopment of China’s CBM development, this paper compares the block geological conditions, the development technologies of CBM, preferential support policy and economy at home and abroad, uses the successful experiences of the United States in CBM development and utilization for reference, proposes relevant knowledges and suggestions in geologic understanding, development process and technology, low cost strategy and policy support and so forth, based on the current development status of CBM in China
    Related Articles | Metrics
    Petroleum Exploration History and Enlightenment in Sichuan Basin: A Case Study on Sinopec Exploration Areas
    HU Dongfeng, WANG Liangjun, HUANG Renchun, PAN Changlin, ZHANG Qingfeng
    Xinjiang Petroleum Geology    2021, 42 (3): 283-290.   DOI: 10.7657/XJPG20210304
    Abstract495)   HTML15)    PDF(pc) (1888KB)(544)       Save

    After systematically analyzing the petroleum geological theory and exploration results of the Sinopec exploration areas in the Sichuan basin, we divide the exploration history of the Sichuan basin into three stages: exploration for structural oil and gas reservoirs (1953-2000), exploration for lithologic gas reservoirs (2000-2010), and exploration for both conventional and unconventional oil and gas reservoirs ( from 2010 to present). Taking Puguang, Yuanba and Fuling gas fields as cases, which are three most representative large gas fields discovered by Sinopec in the Sichuan basin in recent two decades, we analyze the problems arising in the early exploration stage, summarize the theoretical innovations, changes of idea, exploration discoveries and follow-up plans. Our findings can be a reference for exploration in other areas or basins.

    Table and Figures | Reference | Related Articles | Metrics
    Application of NMR Technology in Evaluation of Low Permeability Conglomerate Reservoirs :A Case Study from the Lower Triassic Baikouquan Formation in Mahu Sag
    MAO Rui1, XU Lin1, FANG Tao2, WANG Zhenlin1
    null    2018, 39 (1): 1-1.   DOI: 10.7657/XJPG20180116
    Abstract87)      PDF(pc) (300KB)(542)       Save
    The low permeability conglomerate reservoir in the Lower Triassic Baikouquan formation of Mahu sag, Junggar basin is characterized by complex reservoir lithology, complicated clay minerals and serious heterogeneity, so it is difficult to accurately characterize the effective porosity of the conglomerate reservoir with current logging methods. Considering that the clay mineral content is the controlling factor of reservoir physical properties, the paper uses the difference between neutron logging porosity and NMR logging porosity and clay mineral content obtained from core analysis to establish a clay mineral content characterization model; then uses clay bound water porosity and clay mineral content obtained from core analysis to establish a clay bound water porosity characterization model, based on which the effective porosity can be obtained by NMR porosity minus clay bound water porosity. The actual application of the method in 19 exploration wells in the study area shows that the relative error of effective porosity is only 6.8%, indicating that good effect has been gained by using the method, which could provide a new technological means for effective porosity evaluation with NMR logging data
    Related Articles | Metrics
    Geological Characteristics, Resource Potential and Exploration Direction of Shale Oil in Middle-Lower Permian, Junggar Basin
    ZHI Dongminga, SONG Yongb, HE Wenjunb, JIA Xiyub, ZOU Yangb, HUANG Liliangb
    null    2019, 40 (4): 1-1.   DOI: 10.7657/XJPG20190402
    Abstract215)      PDF(pc) (300KB)(540)       Save
    The Middle-Lower Permian series, the most important source rocks in Junggar basin, are dominated by multi-source, fine-grained mixed sediments deposited in a terrestrial salty lake environment and have good conditions for shale oil generation. A shale oil province with the OOIP of one billion tons has been discovered in the Lucaogou formation of Jimsar sag. Based on the previous study results and combined with the available geological data, the paper systematically summarizes the geological characteristics of the favorable shale oil areas in the Middle-Lower Permian of the basin. Meanwhile, on the basis of benchmarking with the geological characteristics of the shale oil in the Lucaogou formation of Jimsar sag, the shale oil exploration potential in the Fengcheng formation of Mahu sag and the Pingdiquan formation of Wucaiwan-Shishugou sag is analyzed and the next exploration direction for the shale oil in the basin is discussed. The study results show that the multi-source fine-grained mixed sediments of shore-shallow lacustrine-semi-deep lacustrine facies in the Middle-Lower Permian strata of the basin are the high-quality source rocks where tight sweet-spot reservoirs are developed, and the reservoir combination is characterized by source rock-reservoir superposition and frequent interbed with each other vertically, which lays a foundation for shale oil accumulation in the Middle-Lower Permian strata. Typical terrestrial shale oil characteristics such as hydrocarbon mainly coming from neighboring source rocks, self generation as the complementary and in-situ accumulation can be obviously seen. The maximum proven resources of the shale oil in the basin is 27.25×108 t. The geological conditions of the Fengcheng shale oil in the Mahu sag are better than those of the Lucaogou shale oil in Jimsar sag, therefore, the Fengcheng formation in Mahu sag is considered as the next key area for shale oil exploration. The geological conditions of the Pingdiquan shale oil in Wucaiwan-Shishugou sag are relatively poor, and the shale oil here can only be considered as a prospect area for exploration. Additionally, the Luocaogou formation in the piedmont of Bogda Mountain and the Pingdiquan formation in the slope area of Fukang-Dongdaohaizi sag are the potential areas for shale oil exploration and at present comprehensive geological research should be performed to gain more geological understandings and to complete technical preparation work
    Related Articles | Metrics
    Thrust Fault Activity and Hydrocarbon Migration and Accumulation in Thrust Fold Belt in Southern Margin of Junggar Basin
    YANG Geng, LI Wei, LI Benliang
    null    2012, 33 (5): 1-1.  
    Abstract79)      PDF(pc) (300KB)(538)       Save
    The thrust fold belt in southern margin of Junggar basin has been still active since the Cenozoic era, and the hydrocarbon exploration in this area must focus in present thrust structural belt rather than ancient one. Based on available surface surveys and 2D/3D seismic data interpretations, the dip angles of thrust faults in this belt most range from 30°±5° to 50°±5°. The stress analysis shows that intersection angle between the principal stress and the fault is about 30°±5°, which means the maximum/the minimum principal stress ratio is the minimum, there exists the maximum fluid pressure, at which the fluids around the fault may flow along the maximum principal stress orientation,the faults become the main pathway of fluid migration. When the intersection angle is about 50°±5°, the reactivated faults need higher fluid pressure, resulting in that the sealing of the fault is relatively better. Under the tectonic compression, the thrust fault extends toward the north,in which the detachment layer of fault is mudstone or shale of the Paleocene Anjihaihe formation, which forms much higher tectonic overpressures in this layer. The sandstone horizontal permeability of the Ziniquanzi formation underlying Anjihaihe formation is much higher than its vertical permeability, which is helpful to becoming favorable reservoirs, being major target zones for petroleum exploration in this area
    Related Articles | Metrics
    A Method to Predict Reasonable Reserve-Production Ratio Limit for Oilfields
    WANG Luchun, ZHAO Xin, LI Jindong, SUN Zhijie, XUE Rui
    Xinjiang Petroleum Geology    2020, 41 (3): 355-358.   DOI: 10.7657/XJPG20200316
    Abstract306)   HTML5)    PDF(pc) (415KB)(538)       Save

    In order to evaluate whether the reserve-production ratio of an oilfield is reasonable or not, according to the definition of reserve-production ratio,the relationship among production decline rate and liquid production, the relationship between production decline rate and watercut, the paper establishes the relationships between the reserve-production ratio and produced fluid, watercut rise and reserve-production equilibrium coefficient, respectively, and predicts the trends of reserve-production ratio in different development modes. Additionally, the paper establishes an annual reserve-production ratio formula under the ideal conditions and charts of rapid prediction of reasonable reserve-production ratio, divides the reserve-production ratio at the limit watercut into 4 categories including reasonable, relative reasonable, unreasonable and extremely unreasonable reserve-production ratio and then determines the reasonable reserve-production ratio. Applying this method into a block and assuming that other conditions remain unchanged, the reserve-production ratio is already negative when the watercut reaches 96.2%, indicating a relatively low reserve-production ratio. Finally, the reasonable reserve-production ratio is determined as 8.2, which provides new references for reasonable reserve-production ratio limit determination in oilfields and countermeasures for development plan adjustment based on the rationality evaluation of the current reserve-production status of oilfields.

    Table and Figures | Reference | Related Articles | Metrics
    Division of Methane Weathering Zones in the Middle and Lower Jurassic Coal Seams of Santanghu Basin
    WANG Qiong, YANG Shuguang, WANG Gang, XU Hao, REN Pengfei, DONG Wenyang
    Xinjiang Petroleum Geology    2020, 41 (3): 261-268.   DOI: 10.7657/XJPG20200302
    Abstract411)   HTML9)    PDF(pc) (1788KB)(537)       Save

    Based on the gas contents and main gas components of the middle and low rank coal seams in the Santanghu basin, and combined with the structure, sedimentation and hydrogeological characteristics of the basin, the methane weathering zones in the coal seams in Hanshuiquan sag and Tiaohu sag are divided, and the methane weathering zones in the coal seams of the Kumusu sag, Malang sag, Naomaohu sag and Suluke sag are predicted. The results show that the methane weathering zones in Santanghu basin are 400-1 000 m deep. The methane weathering zone in the northern part of the basin is shallower than that in the southern part due to the influence of the thrust uplift zone in the northeastern in Santanghu basin. The sedimentary environments of the coal seams of the deep-lake-semi-deep lake facies and the braided river delta facies in Naomaohu sag, Malang sag and Tiaohu sag in the eastern Santanghu basin are better than those of the fan delta facies in Hanshuiquan sag and Kumusu sag in the western Santanghu basin, causing the methane weathering zone in the eastern basin generally shallower than that in the western basin. The methane weathering zones representing open, locally retained hydrogeological units in Tiaohu sag and Malang sag are shallower than those representing close, weak runoff hydrogeological units in other sags. It is preliminarily predicted that the northern Malang sag is the target area for further coalbed methane exploration and development, and the northern Tiaohu sag is the target area for exploration and development of the coal measure gas.

    Table and Figures | Reference | Related Articles | Metrics
    Tight Oil Accumulation Characteristics and Selection Criteria for Potential Basins
    MA Feng1, WANG Hongjun1, ZHANG Guangya1, HE Zhengjun1, YANG Liuyan1, LI Fei2
    null    2014, 35 (2): 1-1.  
    Abstract85)      PDF(pc) (300KB)(532)       Save
    Based on statistic and compared all available definitions of tight oil given by oil exploration scholars across the world, it can be defined that tight oil, which can be economically recovered only by large fracturing, is continuously accumulated within the source rock as well as its top and bottom, with tight clastic rock and carbonate rock as the reservoir rock, permeability less than 1 mD and porosity less than 12%. According to 8 parameters summarized after successful exploration and development of mature shale blocks in North America,the tight oil is of 10 accumulation characteristics: (a) special shale type is required; (b) organic matter abundance reaches a given level; (c) organic matter thermal maturity lies in the oil window; (d) organic matter type is mainly Type I and Type II; (e) organic?rich shale thickness reaches a given scale; (f) interbeds with good porosity and permeability exist between shale rocks; (g) overpressure conditions exist; (h) shale has high Young’s modulus and low Poisson’s ratio; (i) brittle minerals content is high; (j) crude oil is light. On these bases, this paper points out the differences between tight oil and shale gas in source rock quality and reservoir characteristics for economic development, and presents the assessment criteria for potential shale in tight oil basins from analyzing the geological conditions of tight oil accumulation in North America: TOC>2%, Ro: 0.5%~1.3%, ρr<0.87 g/cm3, μo<10 mPa·s. According to this criteria, 98 basins with tight oil exploration potential have been screened out across the world, their tight oils are mainly distributed in Mesozoic and Paleozoic
    Related Articles | Metrics
    Stress Simulation of Vetical Hydraulic Fracture Propatation Mechanism in Tight Conglomorate Reseriors of Mahu Area
    WANG Shuo, QIN Jianhua, YANG Xinping, LI Xiaoshan, ZHANG Yi, WANG Yingwei
    Xinjiang Petroleum Geology    2020, 41 (2): 193-198.   DOI: 10.7657/XJPG20200209
    Abstract420)   HTML11)    PDF(pc) (4103KB)(530)       Save

    In the light of the features of ultra-low porosity and permeability of the conglomerate reservoir in Mahu oilfield, the volume fracturing tests in horizontal wells are carried out to stimulate the reservoir. However, how to connect reservoirs at the extreme through hydraulic fracturing is a major difficulty in both theory and practice. Based on the theories of fluid-structure interaction and rock elastoplastic fracture and by means of finite element method, the paper discusses the stress evolution rules and fracture mechanism of mudstone layer, and analyzes the influencing factors such as mudstone interlayer thickness, rock mechanical parameter, dip angle and effective stress during volume fracturing in horizontal wells. The study results show that if the injection rate of fracturing fluid is constant, the effective thickness of the mudstone interlayer penetrated by hydraulic fractures is less than 5 m; the larger the differences of the mechanical parameters between conglomerate and mudstone, the larger the dip angle of mudstone layer and the worse the penetrating capability of the hydraulic fractures; the minimum horizontal principle stress plays a leading role in fracture propagation vertically. Additionally, the distance from a horizontal well to mudstone layer and well injection pressure have great influences on fracture propagation. Perforation at close range to mudstone interlayers should be avoided to improve fracturing effect.

    Table and Figures | Reference | Related Articles | Metrics
    Development Tendency of Geological Theory of Total Petroleum System: Insights From the Discovery of Mahu Large Oil Province
    TANG Yong, CAO Jian, HE Wenjun, SHAN Xiang, LIU Yin, ZHAO Kebin
    Xinjiang Petroleum Geology    2021, 42 (1): 1-9.   DOI: 10.7657/XJPG20210101
    Abstract724)   HTML32)    PDF(pc) (826KB)(525)       Save

    Petroleum system is a basic tool for strategic oil and gas exploration and the geological theory of petroleum system needs to be extended with the development of unconventional petroleum geology theory. Based on the review of the evolution of petroleum system theory and the analysis of its development tendency, the paper studies the discovery history of the large oil province of Mahu. The research results show that the discovery of the Mahu large oil province represents a microcosm of the development of petroleum system theory. The large oil province of Mahu where all kinds of reservoirs can be found has the basic conditions of source-reservoir coupling, providing empirical evidences for the establishment of the total petroleum system theory. Taking Mahu sag as a case, there are possibly four directions for the exploration of total petroleum system–from outer-source to inner-source, from conventional resources to unconventional resources, from shallow strata to deep ones, and from single traps to continuous geological bodies.

    Table and Figures | Reference | Related Articles | Metrics
    Application of Remote Detection Acoustic Reflection Logging to Fractured-Vuggy Carbonate Reservoir Evaluation
    ZHANG Cheng-sen, XIAO Cheng-wen, LIU Xing-li, GUO Hong-bo, ZHU Deng-chao, WANG Gui-qing
    Xinjiang Petroleum Geology    2011, 32 (3): 325-328.  
    Abstract103)      PDF(pc) (453KB)(523)       Save
    Remote detection acoustic reflection logging (RDARL) is capable to reflect acoustic impedance anomaly ranging from 3 to 10 meters beside a wellbore in carbonate formation or fractured-vuggy carbonate reservoir. This paper presents the detection principle and its typical response features applied to different types of reservoirs. Through the scale application of RDARL to Tarim carbonate reservoirs, integrated with conventional logging data, the fractured-vuggy developed situations of them beside the wellbores are evaluated. And the acid fracturing test shows that it can reach above 85% in effectiveness, increasing comprehensive capability of evaluating such a reservoir in this basin.
    Reference | Related Articles | Metrics
    Prediction of Reef Reservoir in Changxing Formation of Damaoping Area, Eastern Sichuan Basin
    DING Chuanqi, ZHOU Lu, ZHONG Kexiu, WU Yong, ZHONG Feiyan, LIU Yi
    Xinjiang Petroleum Geology    2020, 41 (2): 164-171.   DOI: 10.7657/XJPG20200205
    Abstract308)   HTML5)    PDF(pc) (5209KB)(522)       Save

    The reefs of the Upper Permian Changxing formation in the Damaoping area of the eastern Sichuan basin are distributed in the shape of ring and strip. Individual reefs are characterized by small scale, deep burial depth, multiple periods of vertical superimposition and strong heterogeneity, leading to difficulties in reef prediction. Regarding the characteristics of weak amplitude of in-phase axis, blank and disordered reflections within the reef reservoir, and based on the logging-seismic calibration and forward models to establish seismic response characteristics of the reef, clustering analysis is performed to fuse multiple seismic attributes which are sensitive to reef, and the reef distribution is predicted. Constrained by isochronal seismic amplitude slice through reefs, S-transformation-based spectrum decomposition amplitude slices are used to identify reef boundary. The combined method of fractional frequency and waveform clustering can get more accurate reef boundary and more detailed characteristics of the reef, which are highly consistent with the actual drilling results in the study area.

    Table and Figures | Reference | Related Articles | Metrics
    Application of Relative Permeability Curves to Establishment of Empirical Formulas for Fluid Productivity Index and Injectivity Index of Horizontal Well
    WANG Tao, ZHU Wei-hong, YANG Sheng-lai, BAI Qiu-yan, LI Ji-ping, WU Min
    Xinjiang Petroleum Geology    2009, 30 (2): 235-237.  
    Abstract154)      PDF(pc) (210KB)(520)       Save
    The thin-sandstone reservoir of HD oilfield in Tarim basin is characterized by dual payzones, ultra-deep and ultrathin laminar reservoir with medium-low permeability and edge water. It is developed by water injection technology of double-step horizontal wells. This paper gives the empirical formulas for horizontal well's fluid productivity index and injectivity index changing with water cut applying the relative permeability curves. The case study indicates that these formulas are practicable for prediction of injection-production capacity, rational regulation of injection-production strategy and EOR by horizontal well water flooding in this reservoir.
    Reference | Related Articles | Metrics
    A Review of Fan Delta Studies at Home and Abroad
    GU Yong-hong, WANG Zhen-yu, TAN Xiu-cheng
    Xinjiang Petroleum Geology    2003, 24 (6): 590-593.  
    Abstract110)      PDF(pc) (236KB)(519)       Save
    Fan delta has been becoming a focus studied by sedimentologists at home and abroad. Through more than 30-year in- depfh studies, fan deltas’ sedimentary characteristics are more and more understood. This paper outlines the definition, classification, formation setting and process, sedimentary characteristics and models of fan delta as well as related study methods and tendency. These studies are of significance for searching for mineral deposits and hydrocarbon reservoirs. Also, there exist a lot of issues to be dealt with urgently for the study of fan deltas, needing in-depth researches to be made further.
    Reference | Related Articles | Metrics
    Himalayan Movement and Petroleum A ccumulation in Jiuxi Basin
    ZHOU Xiao-feng,ZHAO Ying-cheng ,ZHANG Ya-jun
    Xinjiang Petroleum Geology    2005, 26 (4): 393-396.  
    Abstract122)      PDF(pc) (459KB)(519)       Save
    Jiuxi basin is located in the northeastern margin of Qinghai-Tibet plateau with active natural earthquake. Himalayan movement in this basin can be divided into eleven stages in terms of weak-strong intensity of structural compression. The Middle Pliocene is its main deformation/formation stage and petroleum accumulation stage in this area. The structural deformation originates in Oligocene. With cont inuous north-shifting of sedimentary center, the development periods of each structural belts tend to postponing from the south to the north, thus controlling the fault- related fold, structural trap and zonal distribution pattern of oil-gas reservoirs in this area. It is indicated that the natural earthquake is an important role in petroleum migration and accumulation.
    Reference | Related Articles | Metrics
    Reservoir Characteristics and Main Controlling Factors of Cretaceous Qingshuihe Formation in the Southern Margin of Junggar Basin
    SI Xueqiang, YUAN Bo, GUO Huajun, XU Yang, CHEN Nenggui, PENG Bo
    Xinjiang Petroleum Geology    2020, 41 (1): 38-45.   DOI: 10.7657/XJPG20200106
    Abstract331)   HTML11)    PDF(pc) (6429KB)(513)       Save

    Profitable oil and gas flows of over 1,000 m 3/d have been obtained from the sandstone reservoir of the Cretaceous Qingshuihe formation in the Sikeshu sag of the southern margin, Junggar basin, which proves that the formation belongs to a set of high-quality reservoir. Based on the analysis of outcrop sections and drilling data and using polarizing microscope, pore and permeability analyzer and confocal laser scanning microscope, the paper analyzes the rock mineral, physical property and pore structure of the sandstone samples from the Qingshuihe formation and carries out researches on diagenetic evolution by combining with its burial history. The results show that the sandstone of Qingshuihe formation mainly containing feldspar lithic sandstone and lithic sandstone is characterized by a little matrix, medium content of cements and developed residual intergranular pores, which is at the Phase A of the middle diagenetic stage with the compaction dominated by pore reduction. The comprehensive analysis shows that the formation of the high-quality reservoir in Qingshuihe formation is controlled by 3 key factors such as early long-term shallow burial and late rapid deep burial, developed fractures and abnormal high formation pressure. The early long-term shallow burial and the late rapid deep burial are favorable for preservation of primary pores in the reservoir; both intragranular microfracture and bedding fracture are developed, which is helpful for the formation of efficient flowing paths in the sandstone reservoir; and the abnormal high formation pressure contributes to the preservation of intergranular pores and the opening of fractures.

    Table and Figures | Reference | Related Articles | Metrics
    Formation Mechanism of Weima No.2 Gas Pool in Kongquehe Slope, Tarim Basin
    ZHAO Zeng-lu, LIU Wen-hui, YANG Bin-yi, WANG Pu-gui, FU Dai-guo, YAN Yong-xin, ZHANG Yan-qiu
    Xinjiang Petroleum Geology    2003, 24 (6): 549-551.  
    Abstract84)      PDF(pc) (1649KB)(506)       Save
    There exist vertically structural sequences of Paleozoic, Mesozoic and Cenozoic in Kongquehe slope area, Tarim basin, horizontally nose-like uplifts of Baliying-Puzhong-Qunke and Longkou-Weima-Kaiping, and effective source rocks of continental Jurassic and marine Cambrian-Ordovician. Paleozoic and Mesozoic reservoir-cap rock assemblages are well developed, with good space-time configuration between trap shaped period and generation or expulsion period of hydrocarbons in source rocks and good preservation nature, which are favorable for forming large scale oil-gas reservoir conditions. Kongque-1 Well, located on Weima No.2 anticline structure in Kongquehe slope, has produce gas flow by drillstem test of Silurian. It is considered from analyses of the gas property and geochemical feature that formation of the gas in this area is of characteristics of multi-source composite and multi-stage continuity, belonging to petroliferous gas formed by sapropelic parent material, and marine sedimentary source rocks of Lower Paleozoic.
    Reference | Related Articles | Metrics
    Variation Laws of Compressibility, Porosity and Permeability of Rocks during Injection-Production Process of Reservoir
    WANG Zhou-hua, GUO Ping, ZHOU Dao-yong, GAO Hui-jun
    Xinjiang Petroleum Geology    2006, 27 (2): 191-193.  
    Abstract194)      PDF(pc) (471KB)(502)       Save
    The keep-up pressure recovery of most oil-gas reservoirs and the gas storage measurement on some depletion reservoirs have been made in China, which have endlessly caused variation of pressure difference between inside-pore and outside-pore, followed by always changes of compressibility, porosity and permeability of rocks due to injection and production time and again of reservoir fluids. The variation of petrophysical parameters with pressure drawdown is better known, but the changing law of them with cycling, rising and declining of formation pressure is seldom researched. This paper presents the experiment of compressibility, porosity and permeability by using artificial cores on which different confining pressures are put. Study shows that these petrophysical parameters will change with pressures, of which rock porosity will affect other parameters' variations, and permeability has lag-effect during cycling, rising and declining of the pressure.
    Reference | Related Articles | Metrics
    Palaeokarst of Cambro-Ordovician and Oil-Gas Distribution in Tarim Basin
    KANG Yu-zhu
    Xinjiang Petroleum Geology    2005, 26 (5): 472-480.  
    Abstract100)      PDF(pc) (1279KB)(498)       Save
    The Cambro-Ordovician is very thick and widely distributed in Tarim basin. The well developed palaeokarst feature in it is due to multistage tectonic movement and its intrinsic sedimentary characteristics. It is the palaeokarst distributed vertically and laterally that controls the hydrocarbon distribution. More than ten large-and middle-scale such oil-gas fields have already been found up to now. This paper highlights the stage of palaeokarst development, the distribution, type and origin of palaeokarst and the characteristic and the oil-controlling effect of such a reservoir. It is concluded that the Cambro-0rdovician system(@) in Tarim basin is significant horizon(s) or zone (a) for finding out giant oil-gas field in future.
    Reference | Related Articles | Metrics
    Numerical Simulation Research of Fracture Propagation in Tight Sand Reservoir by Volume Fracturing Process
    ZHAO Zhenfeng1, WANG Wenxiong1, ZOU Yushi2, LEI Xin2, XIAO Bo2
    null    2014, 35 (4): 1-1.  
    Abstract70)      PDF(pc) (300KB)(498)       Save
    Volume fracturing is the key technology for improving production of tight sand oil reservoir. By the approach of integrating finite element method with discrete element method, a model for fracture propagation by volume fracturing process is developed in this paper, by which the fracture propagation modeling of multiple clusters fracturing of horizontal well in Chang?7 tight sand oil reservoir of Changqing oilfield is researched. The result shows that volume fracture could easily form when stress difference is lower than 4 MPa, and planar fracture mainly formed when it is higher than 5 MPa. The density of natural fracture could only affect the stimulation effect when the stress difference is very low. When the stress difference is 3 MPa, the interference of fracture between clusters is serious and partial merge of fractures will appear. In this situation, no matter increasing number of perforation cluster or reducing cluster space, the stimulating reservoir area won’t increase obviously. When the stress difference is 5 MPa, the interference of fracture between clusters is weak. Increasing number of perforation cluster is beneficial for hydraulic fractures to connect with more natural fractures, improving the development degree of the volume fractures and expanding the stimulation area.
    Related Articles | Metrics
    REVIEW OF SOURCE ROCK MATURITY EVALUATION BY ORGANIC PETROLOGY METHOD
    Cheng Dingsheng
    Xinjiang Petroleum Geology    1998, 19 (5): 428-432.  
    Abstract134)      PDF(pc) (206KB)(496)       Save
    Organic maturity is an important problem in evaluation of source rocks.From the view of the historical retrospects and future prospects of organic petrology, the application effectiveness on evaluating source rock maturity by three optical methods of organic petrology, such as transmitted light, reflected light and fluorescence was elaborated, respectively, and their appropriate range, existed problem and the realm which should be strengthened and deepened to study were pointed out in this paper.
    Reference | Related Articles | Metrics
    Probe into Exploration Prospect of Cambrian Subsalt Carbonate Rocks in Tarim Basin from East Siberia Basin
    LV Xiu-xiang, BAI Zhong-kai, FU Hui
    Xinjiang Petroleum Geology    2009, 30 (2): 157-162.  
    Abstract160)      PDF(pc) (646KB)(495)       Save
    East Siberia basin and Tarim basin are all ancient craton basins where a series of oil-gas fields have been found, with different scales and reserves. The correlation of hydrocarbon accumulation and major control factors between these two basins indicates that there exist premium source rocks and reservoirs in subsalt carbonate rocks of Cambrian in these basins, and regionally distributing gypsum-salt rock of Middle Cambrian is good cap rock. The study shows that the subsalt carbonate rocks of Cambrian in Tarim basin possess favorable exploration prospect, the favorable areas or zones are located in the main host belts of Tazhong uplift and its two sides, Yingmaili and Lunnan areas in Tabei uplift and southern structural belt of Bachu swell, based on the source-reservoir-cap rock assemblage, structural development, sedimentary environment, oil-gas shows and the petroleum accumulation characteristics of the two basins.
    Reference | Related Articles | Metrics
    Genesis and Distribution of the Cambro-Ordovician Dolomite in Tarim Basin
    ZHENG Jian-feng, SHEN An-jiang, LIU Yong-fu, CHEN Yong-quan
    Xinjiang Petroleum Geology    2011, 32 (6): 600-604.  
    Abstract199)      PDF(pc) (578KB)(493)       Save
    The dolomites of Cambro-Ordovician in Tarim basin are of four geneses, corresponding with four kinds of dolomitization ones such as sabakha dolomite, seepage reflux dolomite, buried dolomite and hydrothermal dolomite, which can be properly identified from the lithologic characteristics and geochemical characteristics. This paper comprehensively analyzes the paleogeographic and paleoclimate data, concludes the vertical and lateral distributions of dolomites with different geneses in Tarim basin: the development of sabakha dolomite and seepage reflux dolomite are controlled by sedimentary facies and mainly developed in Lower-Middle Cambrian; the development of burial dolomite are controlled by diagenetic facies, but the reef and shoal with high porosity as well as open system connected with fracture passage are easy to dolomitize; hydrothermal dolomite mainly develops below unconformity and near the discordogenic fault.
    Reference | Related Articles | Metrics
    Technology for Gas Injection Miscible Phase Recovery in Pubei Oilfield of Turpan-Hami Basin
    LIU Bin, ZHANG Jun, LI Y an-ming, PU Yu-e, HE Shu-hua
    Xinjiang Petroleum Geology    2002, 23 (5): 424-426.  
    Abstract98)      PDF(pc) (1183KB)(493)       Save
    Taking Pubei oilfield as an example, this paper systematically presents the reservoir condition, detailed reservoir description,key index determination and overall project design in relation to gas injection miscible phase recovery. It is stressed that detailed reservoir description, comprehensive studies, including lab experiment and evaluation, numerical simulation and economic assessment of miscible phase recovery, have to be performed prior gas injection miscible phase recovery for a low permeability oilfield. And analysis and evaluation in detail are made in view of issues from field production and effectiveness of Pubei oilfield development. Thus more practical experiences would be gained for the miscible phase recovery with low permeability oilfield.
    Reference | Related Articles | Metrics
    Discovery, Distribution and Exploration Practice of Large Oil Provinces of Above?Source Conglomerate in Mahu Sag
    ZHI Dongming1a, TANG Yong1b, ZHENG Menglin1b, GUO Wenjian1b, WU Tao1b ZOU Zhiwen2
    null    2018, 39 (1): 1-1.   DOI: 10.7657/XJPG20180101
    Abstract215)      PDF(pc) (300KB)(491)       Save
    Combining the data of geophysics, geology and drilling, the paper systematically summarizes the discovery process of large oil provinces in Mahu Sag. Based on reservoir dissection and the study of reservoir?cap assemblages in the upper Wuerhe formation and Baikouquan formation, the reservoir forming model has been perfected, which could guide the overall breakthrough of Baikouquan formation and upper Wuerhe formation in sedimentary fans of Xiazijie, Karamay, Zhongguai and Xiayan, and 2 large oil provinces such as Baikouquan formation in the northern Mahu sag and the upper Wuerhe formation in the southern Mahu sag have been discovered. It is considered that the favorable conditions of large oil province forming in Mahu sag consist of the large?scaled slope tectonic setting during the deposition of the upper Wuerhe formation and Baikouquan formation, the high?quality alkalin?lacustrine source rocks in the Lower Permian Fengcheng formation, the continuous superimposed conglomerate bodies distributed on the 2 unconformity surfaces and the high?steep faults and so on. Based on which, a new hydrocarbon accumulation model of lithological reservoir groups which is made up of multistage retrogradational conglomerate bodies in large and continuous distribution is established. The discovery of the large oil provinces and the establishment of the hydrocarbon accumulation model in Mahu sag can provide guidance and references for the exploration in the strata of Middle Permian and deep Carboniferous?Lower Permian in this area
    Related Articles | Metrics
    Method for Determination of Hydrogen Sulfide in Crude Oil
    CHEN Qing1, CHEN Deen2
    null    2012, 33 (4): 1-1.  
    Abstract132)      PDF(pc) (300KB)(491)       Save
    The problems occurred in these methods for determination of hydrogen sulfide in crude oil such as water extraction, nitrogen stripping ? chromatography, nitrogen stripping ? XVI total sulfur analyzer and nitrogen stripping ? iodometric methods are analyzed. The iodometric method for determination of hydrogen sulfide in crude oil combined with nitrogen stripping method is finally recommended and is further improved from the detection device, steps, formulas, etc
    Related Articles | Metrics
    A Quantitative Evaluation of Carbonate Reservoir—An example of Tahe oilfield
    ZHANG Shi-qing, FAN Zheng-jun, LIU Jian-hua, GAO Qiu-tao, LIU Jie
    Xinjiang Petroleum Geology    2003, 24 (2): 146-148+188.  
    Abstract103)      PDF(pc) (825KB)(491)       Save
    The Ordovician carbonate rocks in Tahe oilield is a complex reservoir with low porosity, low permeability, fractures and vugs, serious heterogeneity as well as variety of fluid properties, along with multiple faults and complicated structural shapes. For fractured reservoir,electrical imaging information can be used to directly or visually reflect the dip or dip angle of fractures and development of vugs and dissolved pores, etc. It is now the most advanced and optimal well log technique applied to fractured reservoirs. In addition, dual laterolog of conventional well log can offer differential amplitudes which may depict characters of fractures to a certain extent. Hence, combination of conventional well logs, electric imaging data and XMAC information could be adopted to identify the reservoir with pores, vugs and fractures. This paper proposes a method of "Weight evaluation” for classification and quantitative evaluation of the Ordovician reservoir in Tahe oilfield on the basis of the actual production situation. By production testing verification, its coincidence rate is up to 92.3%。Furthermore, prediction of lateral distribution of developed thickness of the Ordovician Grade I reservoir is made,and the results accord with real geological conditions of Tahe oilfield. This method is good for extensive application.
    Reference | Related Articles | Metrics
    Source Kitchen and Natural Gas Accumulation in Kuqa Depression, Tarim Basin
    WANG Fei-yu, DU Zhi-li, ZHANG Shui-chang, ZHANG Bao-min, CHEN Jian-ping, Bernhard Cramer
    Xinjiang Petroleum Geology    2009, 30 (4): 431-439.  
    Abstract142)      PDF(pc) (950KB)(488)       Save
    Based on the simulated test data, the chemical kinetics parameters of natural gas generation rate and carbon isotope from the typical source rocks in Kuqa depression of Tarim basin are established. In view of the geologic data and the present- and paleo- geothermal data from exploration wells and artificial wells, the changes of maturity and gas generation rate with time for each well are analyzed with BasinMod software. And the hydrocarbon generating history and source kitchen evolution of Jurassic-Triassic source rocks are recognized. It is suggested that the late and fast burial and mature of source rocks in Kuqa depression since the Neogene, in particular, the rapid deposition of Kuqa formation since the Pliocene (5×106 a BP) lead to sudden increase of the maturity of source rocks, entering into dry gas stage with extremely high gas generation rate. This is a significant reason for formation of highly active natural gas pool in this depression. As shown by the chemical and stable carbon isotope compositions of the discovered gases, the formation of the giant gas pool in Kela-2, Yaha underwent very different geological processes due to the differences in their gas source kitchens. Gases in Yaha condensate gas field in the frontal uplift zone appear to represent gases generated within early to middle oil window with relatively isotopic light gas, whereas the isotopic heavy gases in Kela-2 gas field in Kelasu-Yigikelike Yi structural belt are most likely high maturity gases (Ro:1.0%~2.5%) generated since 5×106 a BP.
    Reference | Related Articles | Metrics
    Application of CT Scanning Image Technique to Study of Oil Saturation Distribution in Core Displacement Test
    GAO Jian, HAN Dong, WANG Jia-lu, WU Kang-yun, LIU Li
    Xinjiang Petroleum Geology    2009, 30 (2): 269-271.  
    Abstract143)      PDF(pc) (318KB)(486)       Save
    With CT technique, oil saturation distribution can be measured. Original oil saturation and residual oil saturation of different sections and orthogonal intersections as well as 3-D oil saturation can be determined by core scanning in three states which are dry, saturated with formation water and oil displaced by water, thus realizing the visualization and quantitative characterization of oil saturation distribution in core water flooding experiment. The heterogeneity of core oil saturation distribution can be evaluated with standard deviation and variation coefficient. The difference between the CT value and real oil saturation is less than 3%, indicating that the result of CT technique is more accurate than those of other methods for description of the distribution and variation of oil saturation in core displacement test.
    Reference | Related Articles | Metrics
    A Study on Stratigraphic Erosion Thickness in Xihu Sag, the East China Sea Basin
    WANG Zhen, ZHANG Ming-li, WU Fa-dong, WANG Zi-yu, WANG Lin-sheng
    Xinjiang Petroleum Geology    2005, 26 (2): 175-177.  
    Abstract101)      PDF(pc) (695KB)(485)       Save
    Since Late Cretaceous, Xihn sag in the East China Sea basin underwent chasmic stage, depression stage and regional subsid-ing stage, shaping several extensive regional unconformities (seismic reflection interfaces) such as T02(hottom of Pliocene), T42 (bottom Miocene), T03(bottom of Oligocene), causing intensively stratigraphic erosion. This paper presents the basic principle and approach for cal-culating the stratigraphic erosion thickness by means of geologic analogy method, analyzes the affect of the erosion on oil-gas accumnla-tion by taking 26 major seismic line profiles in xihu sag as examples, and probes into the applicability of this approach.
    Reference | Related Articles | Metrics
    Geochemical Characteristics of Carboniferous-Permian Volcanic Rocks in Zhongguai Area in Northwestern Margin of Junggar Basin
    SUN Guo-qiang, YAO Wei-jiang, ZHANG Shun-cun, XING Cheng-zhi, SHI Ji-an, LI Bing
    Xinjiang Petroleum Geology    2011, 32 (6): 580-582.  
    Abstract98)      PDF(pc) (319KB)(479)       Save
    The analyses of the whole-rock elements of 25 samples from Carboniferous-Permian volcanic rocks in Zhongguai area in northwestern margin of Junggar basin reveal that the volcanic rocks are mainly composed of intermediate-acid andesite, dacite, rhyolite, volcanic breccia and tuff, of which SiO2 content averages 66.840%, and they are dominated by calcic series and calc-alkalic series (calcic series accounts for 64% and calc-alkalic series for 36%). According to the geochemical characteristics of the volcanic rocks in this area, the volcanic eruption should occur in the continental inner side of island arc system and undergo melting process of continental crust.
    Reference | Related Articles | Metrics
    Offshore Petroleum Exploration History and Enlightenment in Beibu Gulf Basin
    LI Fanyi, ZHANG Houhe, LI Chunrong, ZHANG Wenzhao, HAO Jing, XU Qingmei, YAN Han
    Xinjiang Petroleum Geology    2021, 42 (3): 337-345.   DOI: 10.7657/XJPG20210310
    Abstract628)   HTML9)    PDF(pc) (1700KB)(478)       Save

    The paper analyzes the historical data of drilling, seismic survey, reserves and production, summarizes the offshore exploration achievements and targets and petroleum geology theory, then divides the offshore exploration process in the Beibu Gulf basin into three stages: (1) Early exploration stage (1960-1995). Drilling results proved that there are good source rocks and source-reservoir-cap assemblages in the Beibu Gulf basin, the basic structural characteristics was understood, and the secondary tectonic units were divided. Early exploration results laid a good foundation for further oil and gas exploration during 1980s when there was a high tide of foreign cooperation. (2) Breakthrough to the Weixinan sag and progressive exploration stage (1995-2010). The discovery and successful evaluation of a number of oilfields represented by Weizhou 12-1 firstly contributed to the cumulative proven geological reserves of oil in the Beibu Gulf basin exceeding 100 million tons. Facing the condition that the Weixinan sag is full of oil but the average size of the oilfields in the sag is relatively small, a progressive exploration strategy was put forward, which broke the bottleneck and realized the upgrading and increase of reserves. (3) Breakthrough to the Wushi sag and exploration into new areas (since 2010). The discovery and successful evaluation of a number of oilfields represented by Wushi 17-2 proved that the Wushi sag is another hydrocarbon-rich sag that has been confirmed by drilling data following the breakthrough of the Weixinan sag. This opened a new prospect in the Beibu Gulf basin. Meanwhile, the exploration to new targets such as buried-hill reservoirs led to the identification of a number of pre-Paleogene carbonate reservoirs which are potential contribution to sustainable development.

    Table and Figures | Reference | Related Articles | Metrics
    Deep Crustal Structure and Hydrocarbon Accumulation in Ordos Basin
    ZHANG Jing-lian, SHI Lan-ting, WEI Ping-sheng, ZHANG Hu-quan, CHEN Qi-lin, LI Yang-jian
    Xinjiang Petroleum Geology    2009, 30 (2): 272-278.  
    Abstract117)      PDF(pc) (537KB)(476)       Save
    Based on the basement feature, basement faults distribution, thick dolomite occurrence, existence of gypsum-salt (especially sylvite) and abundant metal hydrothermal minerals in Ordos basin, it is indicated that there once existed intensive action of mantle fluid in this basin. The study of the deep crustal structure of Ordos basin and the western basins (Yinchuan basin and Liupanshan basin) shows that no mid-crust low velocity layer occurs in deep Ordos basin, but low velocity and high conductive layers widely appears in mid-crust of Yinchuan basin and Liupanshan basin, in which natural gas is generated from the Mantle fluid by Fischer-Tropsch synthesis in Yinchuan basin, while crude oil from it in Liupanshan basin. It is the tectonic compression nappe actions of Late Mesozoic that, on one hand, allow the natural gas in Yinchuan basin to migrate from west to east along unconformity (dominated by weathering crust) between the Ordovician and the Carboniferous (Permian) and structural fractural system and shape poors; on the other hand, allow the crude oil in Liupanshan basin to migrate toward the same direction along pseudoconformity between the Triassic and the Jurassic and form reservoirs. Also, Rujigou coal mine with low sulfur, low ash and premium anthracite is originated partly from the carbon-enriched mantle fluid in Yinchuan basin. the distribution pattern of rare-earth elements of Mesozoic petroleum pitch and the carbon and hydrogen isotope features of Paleozoic natural gas indicate the participation of such a deep crust mantle fluid. According to these, the reefs (dolomite as reservoir, gypsum-salt as cap rock) of Lower Paleozoic in Ordos basin are the main targets for further petroleum exploration; in deep Dongsheng area of Yimeng uplift in northern Ordos basin there exist mid-crust low velocity and high conductive layers, so large oil-gas field could be found below Dongsheng sandstone uranium deposit. At present, in Mid-Proterozoic of Yimeng uplift encountered natural gas by drilling (Jin-13 Well) and ignited successfully, foreshowing that there are bright prospects for petroleum exploration in basement rocks in northern Ordos basin.
    Reference | Related Articles | Metrics
    Sedimentary Characteristic and Facies Evolution of Permian Lucaogou Formation in Jimsar Sag, Junggar Basin
    SHAO Yu1, YANG Yongqiang2, WAN Min1, QIU Longwei2, CAO Yingchang2, YANG Shengchao2
    null    2015, 36 (6): 1-1.   DOI: 10.7657/XJPG20150602
    Abstract117)      PDF(pc) (300KB)(476)       Save
    The systematic studies of the sedimentary characteristic and sedimentary facies of the Permian Lucaogou formation in Jimsar sag of Junggar basin are based on the available cores, thin sections and logging data. The results show that this formation was affected by the charging of terrigenous detrital, volcanic activity and endogenous carbonate rocks, and dominated by dolomitic rock with complex rock components and varied structures. The lacustrine basin gradually changed from early open lake basin to late closed lake basin. The dessert spots are mainly distributed in such sedimentary environments as delta, underwater bank, mixed flat and dolomitic flat, etc, and characterized by thin silty layer, high contents of quartz, feldspar, carbonate mineral, and low content of clay minerals. The lower sweet spot interval has high contents of quartz and feldspar, while the upper one has high content of dolomite, between which the deposits of semi-lacustrine lake mud and gravity flow occur. Because of the periodical change of climate, the deposits appear in ring strips along lake rim to the lake center with strong heterogeneity in the vertical. In the Lucaogou formation sedimentary period, a lot of volcanic materials were carried by wind into the lacustrine basin, resulting in a mix of normal sediment, volcanic and terrigenous detrital materials in the basin
    Related Articles | Metrics
    Laws and Models of Water Invasion in Kela 2 Gas Field
    WU Yongping, YANG Ming, LI Ming, SUN Yong, ZHANG Yongbin, WANG Hao
    Xinjiang Petroleum Geology    2020, 41 (3): 302-306.   DOI: 10.7657/XJPG20190607
    Abstract429)   HTML15)    PDF(pc) (1338KB)(473)       Save

    Kela 2 gas field in Tarim basin is a massive ultra-high-pressure dry gas reservoir with the largest proved reserves in China. Since 2010, water breakthrough due to geological conditions has been found in seven wells, which brings risks to the steady production of the gas field. Therefore, it is very important to understand the laws and to identify the models of water invasion in the gas field. This paper analyzes the general characteristics of water invasion in the gas field, and determines four regions with different water invasion models. Regarding the watered-out wells in the different regions, the fracture development degree, the relationship between high-permeable zone and interlayer and the distance from high-permeable zone to edge/bottom water are analyzed and the main factors controlling water invasion in watered-out wells are identified. The main direction of incoming water is determined through fault plugging capacity evaluation, dynamic tracking well test analysis and post-casing saturation time comparison. Combined with production performance and history matching of geological model, the water invasion models are determined and the model in single well can be divided into three types such as vertical channeling and lateral invasion of bottom water, lateral invasion of edge water and invasion upwards of bottom water. Based on the numerical simulation of the gas reservoir, the water invasion models in non-watered-out wells can be predicted and a detailed development strategy is proposed to ensure the continuous and efficient development of the Kela 2 gas field.

    Table and Figures | Reference | Related Articles | Metrics
    FORMATION AND EVOLUTION OF THE TARIM BASIN
    Tian Zaiyi, Cai Guiling, Lin Liang
    Xinjiang Petroleum Geology    1990, 11 (4): 259-275.  
    Abstract775)      PDF(pc) (2136KB)(472)       Save
    The Tarim Basin Lies in the central part of the Asia continent and has a basement composed of highly-metamor-mphosed rocks of Archeozoic and Proterozoicages. It is bounded to the north by the Central Asia—Mongolia foldbelt and on the south by the Kunlun foldbelt. The evolutionary history of the Tarim Basin can be divided into pre—plate-form stage,plateform stage and basin stage. The basin consists tectonically of foothill depressions, intrabasin uplifts and depressions,and marginal thrust uplifts. With a compressional nature accompanied by intense convergent strikeslip faults,the Tarim Basin is a major petroliferous and multi-cyclic cratonic basin with faulting events superposed by depressionai oaes. The Mcso-Ccnozoic Erathcm belongs to terrestrial sedimentary sequence and fault-block structural style which differs from those of foredeeps related to A—subduction in North America.
    Reference | Related Articles | Metrics
    Sedimentary Characteristics and Model of Outcrop in Jingjingzigou Formation of Southern Margin, Junggar Basin
    ZHANG Chi, YU Xinghe, LI Shunli, CHEN Hongliang, YANG Zhihao, LI Yalong
    null    2017, 38 (5): 1-1.   DOI: 10.7657/XJPG20170507
    Abstract103)      PDF(pc) (300KB)(470)       Save
    To solve the problems that the depositional environment of the Middle Permian Jingjingzigou formation in southern margin of Junggar basin is unclear and its sedimentary model is controversial, starting from 2 outcrop profiles such as Sigonghe and Sigonghe Coal Mine Plant, the paper makes a detailed study on the sedimentary characteristics of the formation, divides the formation into 11 lithofacies and 6 vertical sequences, identifies cyclic base levels including scour surface, lithofacies transition surface and flooding surface, concludes the abrupt change of paleoclimate from humid reducing environment to dry oxidation environment, and establishes a sedimentary model of braided-river delta for Jingjingzigou formation based on combination with typical profile analysis. The study shows that several sets of sandstones and mudstones deposited in the Jingjingzigou formation in the southern margin of Junggar basin, which are dominated by grey color and interbedded with several sets of coal beds. Large amount of debris of plant fossils can be noted in the formation, indicating a humid and warm paleoclimate which was suitable for vegetation growth. The interbedded red-brown sandstone in the middle indicates an abrupt change of the paleoclimate. Braided-river delta is mainly developed in the formation including distributary channel, swamp, interdistributary bay, underwater distributary channel and mouth bar etc. Relatively high sandstone ratio shows a characteristic of “mud coated by sand”. The base level rises continuously due to the influence of regional structures and downward half-cycle is poorly developed under the impact of river channel down-cutting
    Related Articles | Metrics
    Orthogonal Test Design and Numerical Simulation Optimization of CO2 Flooding in Extra-Low Permeability Reservoirs
    LI Nan1, PAN Zhijian1, SU Ting1, FEI Yongtao2
    null    2017, 38 (1): 1-1.   DOI: 10.7657/XJPG20170110
    Abstract102)      PDF(pc) (921KB)(469)       Save
    Low permeability reservoirs are the main contributors to the discovered and proved reserves in China currently, among which extra-low permeability reservoirs are widely distributed and account for a large proportion of the reserves. However, extra-low permeability reservoirs are characterized by poor physical properties, so it is difficult to enhance single well production by conventional waterflooding method significantly. CO2 flooding can expand oil volume, reduce oil viscosity, lower interfacial tension and capillary resistance and finally improve oil displacement efficiency. In order to develop extra-low permeability reservoirs reasonably and efficiently, based on numerical simulation and orthogonal design methods, CO2 flooding models are established for extra-low permeability reservoirs, and technical and economic evaluations are carried out for the factors influencing CO2 flooding. The analysis indicates that the parameters influencing development effect from high to low are reservoir type, well spacing density and injected CO2 volume. Considering daily well production and internal rate of return and so on, the optimum way to develop extra-low permeability reservoirs is the combination of CO2 flooding in horizontal wells and the corresponding parameters
    Related Articles | Metrics
    Influencing Factors of CO2 Flooding in Low Permeability Reservoir with Reservoir Numerical Simulation
    LIAO Hai-ying, LV Cheng-yuan, ZHAO Shu-xia, CHEN Yan, HE Ying-fu, ZHOU Yin-bang, WANG Qiang
    Xinjiang Petroleum Geology    2011, 32 (5): 520-522.  
    Abstract106)      PDF(pc) (265KB)(466)       Save
    Low-permeability oil reservoirs have unique features of low abundance, low pressure, and low yield, their economic and effective exploitation are very difficult. Gas injection is the more efficient recovery method for such reservoirs at home and abroad. With numerical simulator, the main influencing factors affecting CO2 flooding are determined, including analysis of the components of split and fitting, selection of state equation and experimental regression, etc. The study results show that phase behavior simulation is the key of success or failure in numerical simulation of compositional model. The mode of water-gas alternating injection, with properly increasing the injection pressure and selecting appropriate bottom-hole flowing pressure, has obvious effect on incremental production and EOR. Numerical simulation indicates that different well patterns or spacings, heterogeneity, fracture direction, gas injection parameters are the sensitive controlling factors of CO2 flooding, directly affecting reservoir development index and development effect.
    Reference | Related Articles | Metrics
    Status and Issues of Technologies for Development of Condensate Gas Pools
    GUO Ping, LI Shi-lun, DU Zhi-min, SUN Lei, SUN Liang-tian, LI Min
    Xinjiang Petroleum Geology    2002, 23 (3): 262-264.  
    Abstract105)      PDF(pc) (154KB)(465)       Save
    Study the related technologies for development of condensate gas field is of significance with more and more condensate gas fields being discovered nowadays. In this paper, some matured technologies and their shortcomings used in condensate gas field development are outlined, the technical developing trends are presented on the whole, and issues to be studied are proposed. It is considered that the major topics or problems that should be paid attention to are about deep condensate gas phase state, percolation of abnormal high pressure condensate gas pool, and comprehensive technologies for development of deep condensate gas pool.
    Reference | Related Articles | Metrics
    Correlation of Jurassic in Northern Margin of Qaidam Basin and Its Petroleum System
    WANG Chang-gui, MA Li-xie, WANG Wen-di, QIAO Zi-zhen, HOU An-ping, GAO Xue-feng, REN Yu-fen
    Xinjiang Petroleum Geology    2009, 30 (4): 454-458.  
    Abstract132)      PDF(pc) (601KB)(464)       Save
    The north margin of Qaidam basin is an old oil region. The Middle and Lower Jurassic strata are its main source rocks. Through regional studies, the Jurassic is divided into 3 series and four formations, i.e. Xiaomeigou formation of Lower Jurassic, Dameigou formation of Middle-Lower Jurassic and Hongshuigou formation and Caishiling formation of Upper Jurassic, of which Dameigou formation can be subdivided into 7 members. This paper presents the classifications and correlations of 38 wells encountered into the Jurassic one by one, and reviews the sedimentary characteristics of Lower Jurassic and Middle Jurassic, based on which the petroleum systems of the Lower Jurassic and the Middle Jurassic. It is concluded that the Lenghu-Nanbaxian arc structural belt and the Eboliang structural belt are favorable areas for petroleum exploration.
    Reference | Related Articles | Metrics
    A Microphysical Interpretation of Genetic Mechanism of Immature Oil
    ZHOU Yan-ru
    Xinjiang Petroleum Geology    2006, 27 (5): 515-521.  
    Abstract128)      PDF(pc) (639KB)(463)       Save
    The genetic mechanism of immature-low mature oils is explained using theories of chaos and dissipative structure in microphysics. The theoretic basis for genetic mechanism of immature oil and the theoretic model for organic negentropy reaction in microscopic mechanism of hydrocarbon generation are presented. The organic matter and its property for forming the immature oil are applied to demonstrate the microscopic mechanism of the hydrocarbon-generating from acidic non-hydrocarbon and neutral nonhydrocarbon in immature-low mature source rocks. The typical examples, biomarker's maturity index and ZYR rearranged sterane isomeride are discussed. Finally, the accumulation characteristics of immature oil are described in this paper.
    Reference | Related Articles | Metrics
    Geochemical Characteristics of Pinghu Crude Oils in Pingbei Area of Xihu Sag
    YIN Shiyan1,2, YE Jiaren2, LEI Chuang3, SHAN Chao2, TIAN Yang2, LIU Fangyuan2
    null    2014, 35 (5): 1-1.  
    Abstract53)      PDF(pc) (300KB)(462)       Save
    Based on the analysis of the light hydrocarbons, saturated hydrocarbons and aromatic hydrocarbons from crude oil in Pingbei area of Xihu sag, the C7 light hydrocarbon compound of the Pinghu crude oil are characterized by (1) high methylcyclohexane content, low dimeth?ylcyclopentane and pentane content, and paraffin wax index and heptane value ranging from 3 to 13 and 10%~18%, respectively; (2) wide distribution of carbon number of the n?alkanes without odd?even predominance, the Pr/Ph ratios in most samples distributing between 3.6 and 8.2; (3) steranes mainly consisted of regular sterane, with highest C29 sterane, and relatively high degree of isomerization; (4) relatively high hopane content, the hopane/sterane ratio of 1.5~6.7, low gammacerane content and abundant diterpene; and (5) some Reteneis detected from the aromatic components, the methylphenanthrene index being between 0.71 and 1.42, the highest fluorenehas content among the three series of fluorenecompounds. A comprehensive analysis shows that the oil?forming matrix in Pinghu formation is dominated by terrestrial organic matter, most formed in the oxidation?strong oxidation limnetic facies sedimentary environment, with minority parent material formed in weak oxidizing semi?deep lake facies environment, and the kerogen is mainly in stage of mature to high?mature evolution
    Related Articles | Metrics
    Geological Characteristics and Hydrocarbon Accumulation Model of the Upper Paleozoic Khuff-Lower Mesozoic Sudair Play in the Central Arab Basin
    JIA Xiaole1, HE Dengfa1, TONG Xiaoguang2,WANG Yumei3a, JIA Aiting3b, TAO Qin’e3c
    null    2014, 35 (3): 1-1.  
    Abstract82)      PDF(pc) (300KB)(460)       Save
    The Khuff-Sudair play is an important play in Persian Gulf Basin. This paper studied the paleogeography evolution, hydrocarbon source rocks, reservoir rocks, cap rocks and hydrocarbon accumulation process and model of the Khuff-Sudair play. The Lower Silurian Qusaiba source rock was deposited in anoxic marine shelf in fast subsiding depo?center of Arabian platform. Its source rock went into oil window in the Callovian period of Late Middle Jurassic and into gas window in the Early Cretaceous-Turonian period. The oil and gas migrated vertically through faults and fractures and horizontally through overlying sandstone into the Khuff reservoir of the Upper Permian. The Sudair formation of Lower Triassic provided an effective regional seal. The time of oil generation and expulsion was earlier than the time of trap formation, so the oil was difficult to accumulate. The time of gas generation and expulsion was at the same time with the trap formation, so the gas accumulation occurred in the structural trap formed by the basal activity. The Upper Paleozoic Khuff-Lower Mesozoic Sudair play in the North-South Pars gas field could be a major target for petroleum exploration in the Mid-Arab ersian Gulf basin in the future
    Related Articles | Metrics
    The Science Research Frontier of Petroleum Geology
    ZHANG Zhiyi, XIA Bing, ZHU Ruijing, ZHANG Yanni
    null    2013, 34 (2): 1-1.  
    Abstract50)      PDF(pc) (300KB)(459)       Save
    Plate tectonics theory is not appropriate for continental geology. New understanding of the earth exhaust effect gives a bright way to the earth dynamics study and opens a broad space for the earth science research. Theory of deep origin of oil has well developed and several new research frontiers have appeared. Many new research results, such as experiment or researches to the inorganic synthesis of hydrocarbons, structure knot, ring?shaped structure, the basement of oil?bearing basin and inexhaustible nature of oil/gas resources, are presented in this paper. All these researches proved that tectonic movements of the earth crust tectonics controlled oil/gas formation and distribution. Oil and gas were the products of the earth evolution at a certain stage. The science research frontier of petroleum geology lets us get new ideas from practices to form new theory. Using such new theories to guide oil/gas exploration and development will play an unprecedented role and has great potentials in development
    Related Articles | Metrics
    Seismic Imaging Technology for Deep Strike-Slip Faults in Carbonate Reservoirs
    YANG Wei, ZHOU Gang, LI Haiying, MA Xuejun
    Xinjiang Petroleum Geology    2021, 42 (2): 246-252.   DOI: 10.7657/XJPG20210218
    Abstract456)   HTML16)    PDF(pc) (5409KB)(459)       Save

    Seismic wave reflected from the deeply buried Ordovician carbonate reservoirs in Shunbei area of Tarim basin is absorbed and attenuated seriously, and the energy of the seismic wave field diffracted from the deep strike-slip faults in the Ordovician-Cambrian formations is weak, making it difficult to get accurate seismic image. To improve the quality of seismic image, we analyzed the seismic responses characterized by low frequency and weak amplitude, then suppressed noises while protecting low-frequency signals and carried out wavelet consistency processing, and finally applied fault-controlled velocity modeling, tomographic velocity inversion and broadband inverse time migration imaging technologies to improve the seismic imaging quality of the deep strike-slip faults under the desert in the Shunbei area of Tarim basin. The result is helpful to reduce exploration risks and provides reliable data for trap implementation and well allocation.

    Table and Figures | Reference | Related Articles | Metrics
    A Study on CO2 Flooding Effectiveness and Its Geologic Storage
    YAO Yue-dong, LI Xiang-fang
    Xinjiang Petroleum Geology    2009, 30 (4): 493-495.  
    Abstract104)      PDF(pc) (250KB)(458)       Save
    The numerous researches and applied results at home and abroad indicate that injecting CO2 into reservoir may greatly enhance oil recovery (EOR) and realize the long-term and in-situ geologic storage of CO2 . This paper presents the investigation of the status of CO2 storage and related EOR abroad and the latest trend, and studies the impact of reservoir quality, fluid property and recovery process on CO2 flooding and storage using numerical simulation method. And these influenced factors are comprehensively analyzed, according to the calculated results of reservoir parameters in pilot area, followed by that the evaluating indices for influencing CO2 storage and related EOR are determined, and these factors are evaluated.
    Reference | Related Articles | Metrics
    Research on Cracking Principles of Brittle Low-Permeability Sands
    DAI Jun-sheng, WANG Bi-feng, MA Zhan-rong
    Xinjiang Petroleum Geology    2007, 28 (4): 393-395.  
    Abstract101)      PDF(pc) (168KB)(457)       Save
    In the quantitative research on fracture, some principles for rock fracture are usually adopted to confirm when and in which direction the rock fractures occur under stress. Usually, tectonic fracture appears in several forms such as tension fracture, conjugate shear fracture and tension-shear fracture. It is necessary to comprehensively apply the tension fracture principle and the shear fracture principle in case studies. On the basis of Coulumb-Mohr and Griffith fracture principles, this paper puts forward rock-cracking examination principle for low-permeability sand reservoir in combination with the results of rock mechanical test, in which Griffith principle is applied to tension fracture examination, while Coulumb-Mohr principle to shear fracture examination.
    Reference | Related Articles | Metrics