, Volume 31 Issue 4
    

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    石油地质研究
  • Discussion on the classification of petroleum basins
    ZHENG Junzhang
    , 2004, 31(4): 864-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    All commercial reservoirs were found in sediment basins up to now. Different types of sediment basins have different hydrocarbon properties, so the classification of petroleum basins has guidance meanings for the resources assessment and is an important part of the fundamental researches of geological theory. The classification of petroleum basins is very complicated but the existing classification has been limited. By the architectonic system, the basins are divided into three types: inter-craton basins, craton margin basins and inter and margin craton active belt, then which could be sub-divided by genetic mechanisms and dynamics features.
  • Forming process and systematology of oil and gas pool
    ZHOU Xingxi
    , 2004, 31(4): 865-0.
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    Oil and gas pool forming process is happened within the petroleum system and its sub-system, including hydrocarbon generation, migration and accumulation system. In the whole process of hydrocarbon release from sources to accumulation into traps, physical and chemical reactions, as well as space motion happened. The systematology is one of theories on oil and gas pool forming process. The key research of oil and gas pool forming process is the formation mechanism, including the kinetics, dynamics and statics research. The compartment is very important and commom fluid migration and accumulation configuration for forming huge oil and gas fields. Taking the Kuche Oilfield, Tarim Basin, as an example, the vertical structure and horizontal pressure distribution and variation is analyzed, and the oil and gas pool forming process of the north and south belt is discussed. There are three types of oil and gas pool forming mechanism in the Kuche petroleum system: ①Yaha Mode, with a normal-pressure compartment charged early and recharged late; ②Kelasu Mode, with surpressure compartment of late convection; ③Dawanqi Mode, with the outpooring flow outside the compartment.
  • Hydrocarbon accumulation in the Yilahu structure and implication for exploration in the Toksun Sag, Turpan-Hami Basin
    HE Zhiping; KANG Yongshang; YANG Zhenxiang; JIAO Lixin; YANG Songling and XIAN Benzhong
    , 2004, 31(4): 866-0.
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    The researches on oil and gas source, reservoir, cap rocks and oil and gas migration show that the Yilahu structure could be defined as a reservoir combination. The play was controlled by the Wusu fault in the Middle Jurassic and by the Yilahu fault in the Late Jurassic. The controlling factors of oil and gas accumulation in the Yilahu structure show that the play have good oil and gas accumulating conditions, with the Permian mudstone as the major source rock, sandstone of the Kelamayi Formation and the upper part of the Triassic as the reservoir, mudstone of the Upper Triassic and overlying strata as the cap rock. However, the Yilahu structure was transformed and the pools in it were damaged heavily by tectonic movements since the Cretaceous. Some anticlines between the Yilahu fault and the Wusu structure were developed successively on the early structures since the Cretaceous, because the faults were less developed in this area, the oil and gas migrated to these structures during Jurassic were preserved very well after Cretaceous, which should be the prospective exploration area in the Toksun Sag.
  • Photo-elastic experiments of paleo-tectonic stresses field and fracture development characters on Anfutun buried hill, Damintun Sag
    SHAN Jiazeng; ZHANG Zhanwen; CHEN Shaosheng and XU Kun
    , 2004, 31(4): 867-0.
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    Formation and evolution of fractures were controlled by paleo-tectonic stresses field. By analysis of structural evolution of the basement top plane of Pre-Cenozoic era, it could be concluded that formation and evolution of fractures were influenced and controlled by compression stress field in the Yanshan Cycle, extension stress field in the sedimentary phase of Fangshenpao to Shahejie Formation, Himalaya Cycle, and dextral shear stress in the sedimentary phase of the Dongying Formation. Three phase distributive maps of paleo-tectonic stresses field of the basement top plane of Pre-Cenozoic era on Anfutun buried hill zone could be gotten by photo-elastic experiments, including the directional map of max principal stress, trajectory map of max principal stress and min principal stress. Experiments indicate that compression stress field in the Yanshan Cycle induced formation and evolution of NEE and NWW direction fractures, extension stress field in the Himalaya Cycle produced NNE and NNW direction fractures, and dextral shear stress in the Himalaya Cycle controlled distribution of EW direction fracture.
  • Experimental simulation on equilibrium temperature and pressure of methane hydrate in sediment systems
    WU Baoxiang; LEI Huaiyan; DUAN Yi and ZHANG Hui
    , 2004, 31(4): 868-0.
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    The research of equilibrium temperature and pressure of methane hydrate in porous sediments is important for learning the stability of methane hydrate and its evaluating and utilizing. Under the conditions of the temperature of 270.9-278.2K and the pressure of 2.47-4.31MPa, equilibrium temperature and pressure of methane hydrate dissociation in three sediment systems with average pore radii 53.2nm, 27.2nm, and 15.5nm are measured, respectively. The results demonstrate that the average pore size of nature-like sediments has effects on phase equilibrium conditions of methane hydrate. Under the same temperatures, equilibrium pressures of methane hydrate in pure water are lower than that of in sediments. The stability zones of methane hydrate in the sediments increase gradually with the increase of the pore radii. However, the effect of the sediment capillary on the stability of the methane hydrate is little when the temperature is dropped under zero point or the pore diameter be enlarged upon 60nm. An empirical exponential equation is presented to calculate the equilibrium temperature and pressure of methane hydrate dissociation. The results also show that there was a rule between the phase equilibrium conditions of methane hydrate and the pore sizes of the sediment media.
  • Simulation and potential evaluation of hydro-carbon regeneration of coal in the Shanxi Formation Huainan Coalmine
    ZHANG Runhe; ZHAO Zongju; HE Xiaosu and FENG Jialiang
    , 2004, 31(4): 869-0.
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    A thermal simulation experiment has been done on the coal sampled from Shanxi Formation in the Huainan Coalmine, south North China Basin, suggesting that a great deal of hydrocarbon is generated when simulation temperature reaches or exceeds the evolutionary temperature in the early stage of hydrocarbon generation. The gross hydrocarbon quantity of secondary generation is nearly equal to that of successive generation, and the more hydrocarbon generation in early stage, the less potential of hydrocarbon regeneration remains. Mechanism of secondary hydrocarbon generation was discussed and considered to be continuous with the primary generation. Based on the successive hydrocarbon production curve, the quantity evaluation measure for secondary hydrocarbon generation of Permian-Carboniferous coal in south North China Basin was established for the source evaluation.
  • Molecular geochemical evidences of marine deposit in Late Triassic Yunlong Sag, Chuxiong Basin
    LIN Qing; ZHOU Minghui; WEI Zhihong; BAO Jianping; ZHONG Duan and LIN Ren-zi
    , 2004, 31(4): 870-0.
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    24-n-properylcholestanes and 4-methyl-24-ethylcholestanes have been identified with relative high abundance in the hydrocarbon source rocks sampled from Shanpincun and Beiyinshan, Upper Triassic sections in the Yunlong Sag, Chuxiong Basin. The distribution of "three furan" is characterized with absolute dominance of dibenzothiophene. Besides the dibenzothiophene, naphthobenzothiophenes have been detected with high content, suggesting that the marine environment does exist during the end of Late Triassic.
  • Characteristics and evaluation of Mesozoic and Cenozoic clastic reservoirs in the Tabei Uplift
    PANG Wen and ZHAO Jingzhou
    , 2004, 31(4): 871-0.
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    The distribution of the oil/gas field is controlled by the high quality reservoirs in the Tabei Uplift. According to large amount of data of physical properties of the cores, the Tertiary-Triassic reservoirs in the Tabei Uplift are evaluated. Reservoir lithology is mainly feldspar sandstone and lithic sandstone, and the physical properties of the reservoir are favorable, mainly high porosity with middle to high permeability and middle porosity with middle permeability. As a whole, only the physical properties of the Jurassic reservoir are low. The evaluation shows that reservoir belongs to good or middle grade, high quality reservoir distributes wide in the Tabei Uplift，Tarim Basin. High quality reservoir of Neogene is located in the east of Tabei Uplift, and Paleogene in the east and north of Tabei Uplift. High quality reservoir of Cretaceous is situated in the Yangtake area, Yingmai 7 area and Hongqi area in the west of Tabei Uplift. The high quality Triassic reservoir developed in the middle of Tabei Uplift and south area in the west of Tabei Uplift.
  • Diabase facies identification in the west Chunhua Oilfield, Dongying Sag
    SONG Jianyong; WU Shiguo; PU Yuguo and LIU Yuan
    , 2004, 31(4): 872-0.
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    According to the lithology, electricity and seismic facies of lava distributed in the southwest Chunhua Oilfield, the rock-body is well-regulated and divided into center facies, marginal facies and outside facies. The electricity characters of rock-body are divided into four types as gradual change, step gradual change, top leaping gradual change and center depression type, respectively. The seismic facies are also divided into four types as cracked seismic facies, conglutinant seismic facies, multi-stratum seismic and eye-like seismic facies. The main lava body and metamorphic rock should be the new play domain in the intrusive lava.
  • Permian volcanic reservoirs in the Tahe region
    YANG Jinlong; LUO Jinglan; HE Faqi; YU Renlian and ZHAI Xiaoxian
    , 2004, 31(4): 873-0.
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    The petrologic property, reservoir physical property and porosity diagenetic evolution of the Permian volcanic reservoir in the Tahe region, Tarim basin, are studied by core observation, scanning electron microscope (SEM), X-ray diffraction (XRD) and well log interpretation. The results suggest that the volcanic reservoir rocks are mainly dacite and volcanic breccias, then basalt and tuff. The volcanic reservoir spaces can be divided into two types: primary pores and secondary pores, including 11 sub-types. Fracture-pore assemblage is the main pore type. The volcanic reservoir experienced two phases of cooling diagenesis and secondary diagenesis. The secondary diagenesis is important for developing reservoir spaces, which contributed an effective reservoir for the volcanic rocks.
  • Characters of fluid inclusions in the Fuyang reservoir, Qijia-Gulong area, Songliao Basin
    HOU Qijun; MENG Qian and ZHANG Ge
    , 2004, 31(4): 874-0.
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    Abundant fluid conclusions, existed in the authigenic minerals, are developed in the sandstone of the Fuyang reservoir, Qijia-Gulong area, Songliao Basin. The homogeneous temperature of saltwater inclusion, which is co-developed with organic conclusion, is conspicuous for three peaks revealing the three stages of hydrocarbon injection of Fuyang reservoir. During the first hydrocarbon injection stage, the homogeneous temperature of inclusion is 90-120℃, with the organic inclusions distributing in the late quartz secondary increase edge, concrescence fracture of quartz grains and calcite cement. And, the organic inclusion in the concrescence fracture of quartz grains is injected in the homogeneous temperature of 100-110℃, and may be account for a tectonic movement under the homogeneous temperature between 90-100℃ and 110-120℃ which results in the fracturing of quartz grains. Evidence of the hydrocarbon injection is further represented by the oil trace or bitumen, representing possibly the main stage of hydrocarbon injection, existed between the secondary concrescence edge and calcite cement. The second hydrocarbon injection happened in the process of infilling of calcite vein and concrescence of quartz fracture with the homogeneous temperature of 120-150℃, and the bitumen in the calcite vein demonstrate the relatively large amount of hydrocarbon injection in this stage, and therefore prohibiting the growth of authentic minerals. The third stage of hydrocarbon injection is recorded and represented by the secondary concrescence of quartz edge, and revealing the homogeneous temperature of 160-170℃. The laser Laman spectrum indicates that the evolution degree of organic matter in the early oil and gas injection period is lower compared with that in the late injection period.
  • Evaporative fractionation of crude oils in the Ying-Qiong Basin
    HE Wenxiang; WANG Peirong; PAN Xianzhuang and WANG Feng
    , 2004, 31(4): 875-0.
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    The tectonic and geochemical characteristics in the Ying-Qiong Basin were analysed. Based on the relationships between fractionation and compositional alteration of oil and gas, the evaporative fractionation in the Ying-Qiong Basin was studied. The genetic mechanism of the reservoir was investigated, according to the geological settings and geochemical features of hydrocarbon and source rocks. The research result shows the abundant diapiric structures and episodic migration of natural gas offered basic geological condition for evaporative fractionation of oils in the Ying-Qiong Basin. The benzene, methylbenzene and dimethylbenzene aromatic compounds was extraordinarily rich in crude oil and the light hydrocarbon was depleted in n-alkanes. The distribution curve of log molar fraction for n-alkanes had a distinct slope break point, suggesting that the strong evaporative fractionation happened in reservoirs and caused the differences of the oils. The crude oil in the Ying-Qiong Basin was mainly aromatic-riched remnant oil that suffered evaporative fractionation, and remind geologists to look for moiety which contained plentiful light hydrocarbon.
    • 综合勘探开发技术
  • Application of 2D pre-stack migration in sub-aerial reverse fracture zone in Junggar Basin, Northwest China
    CAI Chunjiang; CHEN Zhigang and LI Xueyi
    , 2004, 31(4): 876-0.
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    The pre-stack time migration and depth migration have been successfully used in the south margin of the Junggar Basin for the data processing. Velocity analysis in the pre-stack time migration could be used for buiding an accurate RMS velocity section after having updated velocity correction to CRP gathers for several times. Higher signal-to-noise ratio, move dipping reflectors into their true subsurface position, and collapse diffractions could be achieved. Pre-stack depth migration is model-based, which is migrated by theory of ray tracing, discarding the assumption of horizon, stratified medium and isotropy. In the data processing, the pre-stack depth migration updates depth-velocity model until it reaches high quality by using tomography image principle.
  • Structural genesis mechanism guided detailed interpretation of complicated anticline
    ZHANG Ruifeng; LI Jinsong; MIN Bin and ZHAO Weisen
    , 2004, 31(4): 877-0.
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    Locating trap is a key issue in improving drilling success ratio in progressive exploration and development. It needs to integrate structural background and detailed analysis of genesis mechanism of local structure in order to guide detailed interpretation based on 3D seismic data. Liuquan South faulted anticline, Langgu Sag, north Jizhong Depression, was formed by a composite stress of 3 different kinds of structural stresses and was severely faulted. Zhongchakou fault to the east detached along the strata plane. Two groups of rotated listric normal faults, which are roughly parallel to the Zhongchakou fault but with opposite dipping direction, were severely compressed laterally and wrenched vertically. It also induced local plastic crumple of the shale in middle to lower part of Shasan group. Structural genesis mechanism study guided structure interpretation, strata occurrence study, faults grouping and structure mapping of Liuquan South faulted anticline, which helped to find and evaluate progressive exploration and development targets.
  • The parameter sensitivity and risk analysis for basin modeling
    SHI Guangren and ZHANG Qingchun
    , 2004, 31(4): 878-0.
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    A program of the parameter sensitivity and risk analysis of basin modeling is presented, in which the crucial parameters are selected according to the petroleum exploration and their sensitivity. The probability distribution of simulation results is figured out by the Monte Carlo method so as to conduct the risk analysis of basin modeling. The method is applied to the Tarim Basin as a case study，and the selected sensible parameters are the erosion thickness，the paleo-geothermal gradient and the curve of Ro versus depth. The simulation suggests that the erosion thickness could strongly affect burial，paleo-temperature，Ro and oil generation-expulsion histories, and paleo-geothermal gradient affects the geothermal，Ro and oil generation-expulsion histories，and the curve of Ro versus depth greatly affects the Ro and hydrocarbon generation-expulsion histories. The risk analysis results based on the three parameters are obviously superior to previous results. The technique makes basin modeling from the traditional determination model to the advanced risk analysis model.
  • Evaluation of source rocks at no exploratory well area of Nanpu Sag, Bohai Bay Basin
    ZHANG Zhenying; SHAO Longyi; LIU Guangdi; JIA Linping and YANG Guangming
    , 2004, 31(4): 879-0.
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    There are few exploratory wells in offshore of the Nanpu Sag, which brings difficulty to the source rock evaluation and reserves calculation. The organic abundance and kerogan type in the Dongying Formation of Hatuo area of Nanpu Depression could be evaluated by using the seismic stratigraphy. The source rock in the Ed13 is a good one because its higher organic abundance (TOC 1.14%, S1+S2 4.92mg/g )，and type Ⅱ1 kerogan at a mature stage. The source rock in the Ed23 has similar parameters (TOC 0.99%；S1+S2 4.36mg/g；type Ⅱ1 kerogan) , has been in peak stage for generating hydrocarbon，and is also evaluated to be good source rock, and the source rocks in the Ed2 are evaluated to be bad source rocks．According to different colors of dark mudstone，the TOC qualification rates are counted at different intervals (TOC qualification rate:No 12,72.5%; No13,47.6%; No 14,55.6%)．
  • Application of the micro-facies analysis in the progressive exploration of Pucheng oil and gas field
    ZHOU Jinbao
    , 2004, 31(4): 880-0.
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    The middle interval of S3 in the Pucheng oil and gas field, Dongpu Depression, is of sub-fan deposits. The distributary channel, sheet-like sand, intra-channel sand and lacustrine mud could be determined according to the core and well-log analyses. Based on the sand-body distribution, the micro-facies model is established and the sand distribution outside the area controlled by the well could be predicted. Based on the distribution, some progressive exploration targets could be provided. All the drilled well got good oil production in this area, suggesting both blocks have potential for playing.
  • Variable-dimension fractal method for oil-water layer identification
    WANG Renyi; LI Zhengke; GUO Kecheng and LIU Ying
    , 2004, 31(4): 881-0.
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    The complexity of the differential waveform between the porosity and resistivity curve of the oil-water layers implicates if the reservoir contains oil and gas or not. The information of oil and gas from the waveform grid fractal dimension can be used to identify the oil and water layer. The grid fractal dimension of the differential waveform signal between oil-water layers is only related to the waveform complexity and independent of the waveform absolute value, of which the grid variable-dimension fractal spectrum has better capability than conventional log explanation method to identify low resistivity oil layer and high resistivity water layer.
  • Universal Kriging method for quantitative sandstone prediction between wells
    MU Lihua; PENG Shimi; YIN Zhijun; ZHANG Linhe and LIU Qiong
    , 2004, 31(4): 882-0.
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    Universal Kriging is an unsteady geostatistical method which is used for predicting sandstone between wells. Conditioned by sandstone thickness interpreted from logging data at well location, Universal Kriging could be used to build drift polynomial expressions reflecting sandstone variety by analysis of sandstone thickness variation in different directions. The estimate value of sandstone thickness between wells from Universal Kriging could be much precise and is more coincident with geological rules. Excellent effect is got in the prediction of sandstone between wells by Universal Kriging in Member 3 of Shahejie Formation, Liuzan Oilfield.
  • Improved condition algorithm of fluvial facies for reservoir stochastic modeling
    ZHANG Chunlei; DUAN Lindi and WANG Zhizhang
    , 2004, 31(4): 883-0.
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    A new fluvial model, including the description and modeling of branching and intercrossing, is put forward. A new fast condition algorithm is adopted according to geological and geographic characteristics. Field application shows that new fluvial model is restricted by more geological information and can be adopted widely. The conditioning algorithm which consists of upstream, down stream and branch simulation is more precise and fast.
  • Modeling of dual-porosity and dual-permeability for low-permeability sandstone reservoir
    SUN Yeheng; SHI Fugeng; WANG Chengfeng; YANG Yaozhong; XU Qinglian and WEI Xiaorong
    , 2004, 31(4): 884-0.
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    The modeling of fracture system is the key of modeling a low-permeability sandstone reservoir. Considering the characters of the dual-porosity and dual-permeability for low-permeability sandstone reservoir, based on previous research results, a method for calculating the shape factor, fracture permeability, fracture porosity and the properties of matrix system is presented according to the current fracture descriptive technology. The method is used in the reservoir numerical simulation research on Fan 12 Block, Daluhu Oilfield, Dongying Sag. The calculated water cut trend fits with the actual development data and the workload of history matching is reduced.
  • Sequential Gaussian collocated co-simulation in drilling risk prediction
    LIU Wenling; XIA Haiying; GONG Xinglin and HE Wei
    , 2004, 31(4): 885-0.
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    In reservoir evaluation, well location design and progressive development stage, evaluating the uncertainty of reservoir prediction and predicting drilling risk probability can play an important role for selecting development block and reducing drilling risk. Sequential Gaussian collocated co-simulation is applied in reservoir prediction of Block F2, Daqing Oilfield. The simulation takes thickness of sand as a primary variable and seismic dominant frequency as a secondary variable and to generate 50 different realizations. The minimal sand thickness "threshold" for development is 5m; a drilling risk prediction map of the study block is generated based on a 5m sand thickness. Four wells are discovered in the district where drilling success probability value is lower than 1, which has been suggested to stop drilling. The reservoir development practice of the study block proves that the 4 wells just are in the district where sand is thin. The Sequential Gaussian collocated co-simulation cooperated with seismic attribute data is of higher precision and can efficiently reduce the drilling risk.
  • A method to quantitatively calculate the volume of carbonate reservoirs
    ZHANG Jinduo
    , 2004, 31(4): 886-0.
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    In the extreme inhomogeneous carbonate reservoir in the Tarim Basin, large solution cavity corresponds to the strong reflect in the seismic profile. The extracted reflection amplitude is analyzed, and the amplitude range of the reservoir is required with the well and seismic calibration. With the seismic information visualization technique, the seismic data is specially disposed to obviously reveal the location of the reservoir in the profile. The volume of the carbonate reservoir could be calculated with the sample number, its volume and porosity.
  • Numerical analysis of borehole stability in the bedded formation
    HU Xiuzhang; WANG Xiaojun and LI Yongchi
    , 2004, 31(4): 887-0.
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    It is an important project to keep the wellbore stable for exploration and development. Based on transversely isotropic constitutive relations and the generalized plane strain deformation assumption, a two-dimensional finite element computational model considering the influence of directional tensile strength and shear strength on weak planes is proposed to analyze the stability of inclined borehole in arbitrary dip direction of bedded formation. The computation results imply that it is possible to analyze the wellbore stability in complex geologic conditions and to predict the safe well pressure rapidly in drilling problem by using the model. The numerical result suggests that the main cause of the wellbore instability is the shear failure induced by weak plane.
  • Origin and identification of the deep reservoirs with low resistivity in the Pucheng Area
    ZHANG Yanhong; ZHAO Qilei; XI Tiande; TAN Zhongping; TU Xingwan; YAN Yuying and HU Lijun
    , 2004, 31(4): 888-0.
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    Low resistivity (<2Ω·m) reservoirs in deep middle and upper Es3 in the Pucheng Area of the north Dongpu Sag mainly occurred in lower part of the structure or stratigraphic structure with obtuse formation dipping angle, which are usually connected with small grain size (median grain diameter smaller than 0.1mm), high illite content (70%-90% in clay minerals), high pelitic, high degree of mineralization in formation water (average 28.5g/L), well developed micro-porosity (pore radius smaller than 0.1μm) and gentle structure, etc. Based on the information, including drilling, system coring, production test and the analysis on the origin of low resistivity reservoir and the properties of the irreducible water saturation in the reservoir, the Movable Water Analysis Method could be used for identifying the content of movable water in oil bearing formation and the low resistivity reservoirs.
    • 油田开发与油藏工程
  • The water displacement recovery in different kinds of fault block sandstone reservoirs, Sinopec
    WANG Guangfu; XU Jian; WANG Duanping and YUAN Xiangchun
    , 2004, 31(4): 889-0.
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    The 452 development units of fault block sandstone reservoirs in Sinopec, which are characterized by medium-high permeability and ordinary viscosity, are subdivided into edge/bottom-water fault block reservoirs driven by natural energy, simple fault block reservoirs, complicated fault block reservoirs and extra-complicated fault block reservoirs, all of latter three are water-driven. The relations between the water displacement recovery and well-pattern of fault block reservoirs are analyzed, by which the formulae of oil recovery efficiency of different kinds of fault block reservoirs are regressed. The potential of EOR is analyzed. The study offers some reference for decision-making of tagging remaining-oil.
  • Modeling of low permeability sandstone reservoirs
    LI Yang
    , 2004, 31(4): 890-0.
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    The low permeability sandstone reservoirs are characterized with strong heterogeneity, strong diagenesis and widespread fractures, and the reservoir modeling, different from the middle-high permeability sandstone reservoirs, should include structural model, property model and fracture distribution model and the last should be the most important one. For a structural model, diagenesis, as well as sedimentary facies and micro-facies, should be accounted into the differentiation of facies. For a property model, stochastic modeling method as sequential indicator simulation (SIS) and sequential Gaussian simulation (SGS) could be used. For a fracture distribution model, structural stress field simulation could be used for fracture prediction on foundation of core observation and logging identification. The reservoir model will be able to reveal spatial heterogeneity of the low permeability sandstone reservoirs much effectively.
  • Recovery mechanism simulation for the fractured igneous heavy oil reservoir of the Block Zao 35, Dagang Oilfield
    WANG Yizhong; YUAN Shiyi; SONG Xinmin; RAN Qiquan and SU Yan
    , 2004, 31(4): 891-0.
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    The recovery mechanism of depletion development, water drive, and steam stimulation in the fractured igneous heavy oil reservoir of the Block Zao 35, Dagang Oilfield, is studied through numerical simulations. During depletion development, oil is produced from both the matrix and fracture. During water drive process, there is rare capillary imbibition because of high viscosity and poor mobility, only part of oil in the fracture can be produced and the oil can't be produced from the matrix. During steam stimulation process, the oil-bearing layer is heated, oil viscosity decreased and the mobility increased. So capillary imbibition is strengthened and oil can be produced from the matrix. The conclusion can be reached through the research that steam stimulation, not water drive, should be adopt after depletion recovery in the fractured heavy oil reservoir.
  • Determination of the critical liquid carrying flow rate at low gas liquid ratio
    WU Zhijun and HE Shun-li
    , 2004, 31(4): 892-0.
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    Based on Hagedorn and Brown's method of wellbore pressure calculation, theoretical and actual liquid holdups at low gas liquid ratio are defined, and the principle and formulas to calculate the critical liquid carrying flow rate are established. The analysis of the influencing factors of the critical liquid carrying flow rate and the bottomhole pressure reveals that high gas reservoir pressure, as well as high gas production rate, is required for normal liquid carrying. The field application indicates that the computation results of the method accord with actual production data.
  • Optimization of the flooding pattern in reservoirs with obvious directions of fracture and sand body
    CHEN Guoli; LIANG Chunxiu; LIU Ziliang; LIU Yuncheng and WANG Guoqing
    , 2004, 31(4): 893-0.
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    In case of that both fracture and sand body of a reservoir possess clear directions, and their permeability obviously increase along the two directions, respectively, the flooding pattern must suit the two directions to avoid water-breakthrough or watered-out in any one of the two directions. The Saertu reservoir of Haituozi Oilfield was discovered in 1999 in the Songliao Basin, which belongs to typical low permeability lithological reservoir. On the foundation of sedimentary facies, reservoir fracture and numerical simulation, the pattern density, the directions of well array, the pattern shape, the well spacing, the injection-to-producing well ratio and the flooding pattern are optimized, and finally the 600m×150m inverted nine-spot rhombus pattern is selected for the reservoir. The effect of the project is better after the implementation. The rate of oil production reaches 1.48%. The forecast recovery factor is 20%. The reservoir pressure becomes stable and the daily liquid and oil production declined slowly. The water-cut rises steadily. The inverted nine-spot rhombus pattern has two adjustable directions of well array.It is the optimal pattern for the reservoir with obvious direetions of fracture and sand body.
  • The waterflood behaviors of Sanjianfang Formation reservoir in the west Ling 2 fault block, Qiuling Oilfield
    ZHU Yushuang; SUN Wei; LIANG Xiaowei; YAN Lin; CHENG Xinghai; JIA Zili; MA Guangming; WANG Xiaofang and WANG Feiyan
    , 2004, 31(4): 894-0.
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    There are many problems in the waterflood development of Sanjianfang Formation reservoir of Qiuling Oilfield, including low formation pressure and oil production, rapid increase of water cut and the pressure of water well is approaching fracture pressure. To solve these problems, waterflood behaviors are studied thoroughly by using performance analysis. The results suggest that the characters of the production wells are multi-layers per well, single direction response per layer, single direction per layer and two directions per two layers of water breakthrough. There is positive correlation between the response time and water breakthrough time, and the water breakthrough will come soon after responding if the response time is too short of too long. If the response time is 8-14 months, the water breakthrough comes late after response. Gas block phenomenon should not be ignored as it is probably the key factor causing the problems existing in waterflood development. Waterflood behaviors could also be affected by sedimentary, structure, perforation, the extending direction of sandstone body and reservoir physical property.
  • Application of the zonal pressure testing data from east part of the north Block 3 in North Saertu, Daqing Oilfield
    Lü Hongbin; YU Ying; BIE Aifang and FANG Hongchang
    , 2004, 31(4): 895-0.
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    The zonal pressure testing data of 19 wells from the east part of the north Block 3 in the north Saertu, Daqing Oilfield, were obtained to evaluate the development efficiency of the block. Under the development mode of separate zone production and adjustment of the heterogeneous multi strata, the block reveals obvious interlayer, inlayer and planar inconsistencies. The zonal pressure data can help to demonstrate the pressure level and distribution of different reservoirs, to efficiently guide well stimulations and other adjustment planning, and to scientifically sustain the implementing of further configuration adjustment and casing protection. The zonal pressure testing technology has a broad application prospect in high water-cut development period of produced oilfields.
    • 油田非注水开发
  • Polymer-injection response of tertiary infilling producers in the west-central area, Daqing Oilfield
    WU Shuyun; BAI Yanming; SONG Jie and YUAN Zhaohui
    , 2004, 31(4): 896-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The residual reserves of class 1 and 2 oil layers in the Daqing Oilfield, which are suitable for polymer drive, decreased annually along with the increase of polymer injection area of the main oil-layers. Polymer injection test is carried out in the west-central dense well pattern area, perforating all layers except for class 1 and 2 layers. According to the test results, 3 types of layers are produced and the water injectivity percentage reaches 57%.The injection of low molecular weight polymer with well space of 100m results in effective control of the layers with effective thickness of more than 0.5m, which are the main potential polymer drive layers. The recoverable reserves increase for the center wells were evaluated by using performance analysis, static method and numerical simulation, which reveals that the reservoir recovery could be increased by 4% by polymer driving the tertiary infilling wells.
  • Physical modeling of ASP flooding slug combination
    LI Jianlu; HE Xianhua; GAO Feng; LU Shouliang and CAO Tie
    , 2004, 31(4): 897-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    A series of core flooding experiments with two types of HPAM, with molecule weight of 1.2×107 and 2.0×107 respectively, were conducted to investigate the effect of the combination mode, concentration and the size of ASP slug on displacing efficiency. When the amount of chemical matter is the same, the recovery of the higher concentration, smaller slug is higher than that of the lower concentration, larger slug; and the difference is more obvious as the HPAM with higher molecule weight is used. The increase of the preflush polymer slug (0.1-0.3PV) is beneficial to displacing efficiency. The post-pad slug can be chosen to be 0.2PV because it has no remarkable effect on the displacing efficiency. The results suggest that the two-slug injection mode (the polymer is separated from the ASP system) would be better than the single slug (alkaline, surfactant and polymer are in the same slug).
    • 油田开发与油藏工程
  • Production of attic oil in complex fault block reservoir by CO2 gas drive
    TAN Shihai; ZHOU Zhengping; WU Zhiliang; QIAN Weiming; LIU Wei and XIAO Wei
    , 2004, 31(4): 898-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    In the late high water cut stage of complex fault block reservoir, the attic oil at the high point of the structure is difficult to be developed economically and effectively. With the abundant natural source of CO2 gas and the techniques of tank boat transportation, wellhead supercharging and high-pressure temperature rise, CO2 gas drive has been conducted in the Chujialou Oilfield, Qintong depression, north Jiangsu Basin. The optimal project of CO2 gas drive is selected by numerical simulation, and the field test began in Oct., 2000. CO2 gas of 132.06×104m3, 1.59 percent of oil reservoir pore volume, has been injected into the reservoir. The oil increment is 2545t, and the water cut is decreased by an average of 6%. The oil draining factor of CO2 is 0.001 927t/m3. Recovery factor has increased by 1.07%. The field test reveals that CO2 injection from well at the lower point of the reservoir can drive the water drive remaining oil and accumulate hydrocarbon at the high point of the reservoir. Meanwhile, more test information about producing process and producing characteristics of CO2 gas drive has been gained. The test results show that production of attic oil in complex fault block reservoir by CO2 gas drive has clear mechanism, relatively simple technique and quick effectiveness. And provides a effective way for tertiary oil recovery of complex fault block reservoir.
    • 油藏物理
  • Viscosity prediction experiment of the oil-water emulsions at reverse phase point
    QIN Jishun; ZHANG Xing; GENG Hongzhang; GUO Wenmin and CHEN Xinglong
    , 2004, 31(4): 899-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The reservoir conditions are simulated by using the high-temperature and high-pressure viscosimeter, the viscosity of the oil-water emulsions of the Tahe Oilfield is measured. Test shows that reverse phase point of oil-water emulsion is between 50%-60% of watercut. The testing curve is generated and the viscosity of oil-water emulsions is analyzed by using Gaussian and Lorentzian curve. The test suggests that under reservoir conditions, the viscosity variation of the oil-water emulsion is similar to that under normal temperature and pressure. The viscosity prediction model is provided and the prediction result shows that the error of Gaussian and Lorentzian prediction is small when the water cut is higher than 50% and thus presents scientific foundation for the calculation of oil flow in the reservoir, wellbore and pipelines.
    • 油层保护与改造
  • Laboratory damage appraisal and cleaning technology of hydraulic fractures
    CHEN Hongjun; GUO Jianchun and ZHAO Jinzhou
    , 2004, 31(4): 900-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    A kind of fracture cleaning acid is designed for ES-10 well in the Songzi Oilfield to remove both the fracture damage caused by residue of fracturing pad and formation damage due to drilling mud. A special loop experimental procedure is presented for modeling the flowing process of fracturing liquid from ground to fracture and the fracture damage due to uncompleted decomposition of fracturing pad or residue of fracturing fluid. The loop experiment suggests that the fracture cleaning acid is not only quite effective in decomposing residue gel, but can eliminate the damage caused by drilling mud. In order to increase the acid penetration distance and decompose the gel residue, high concentration of the fracture cleaning acid and high injection rate are applied in the treatment. The fracture damage is removed and the permeability of the formation near the fracture is improved, and the production of the well could be greatly improved.
    • 国际交流与合作
  • Petroleum system in Qom Basin, Iran
    WANG Shihu; LI Zheng; ZHU Rifang; ZHOU Wen and LIU　Qing
    , 2004, 31(4): 901-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The abundance, types and maturity of organic matter in Shemshak Formation of Jurassic and Qom Formation of Oligocene-Miocene, and oil source correlation in Qom Basin, Iran, show that the Shemshak Formation is the most possible source rock for the playing and the Qom Formation has hydrocarbon generation potential. The organic matter of the Shemshak Formation entered into oil window in the Early Cretaceous, and evolved into wet gas and condensate window in about 17 Ma. At the early of Pliocene, the rapidly subsidence of Qom Basin brought on the oil window entrance of Qom Formation and the over maturation of Shemshak Formation. There are Neogene oil and gas accumulation derived from Shemashak Formation and Qom Formation, or primary oil-gas pool in Shemshak Formation in the Qom Basin.
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