, Volume 30 Issue 4
    

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    石油地质研究
  • Analysis of dynamical characters of fracture formation and evolution on Anfutun buried hill zone, Damintun Sag, Liaohe Depression
    GHEN Shaosheng; SHAN Jiazeng and XU Kun
    , 2003, 30(4): 316-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The fractures formation and evolution on Anfutun burial hill zone, Damintun Sag were controlled by three stages, two phases of structural stresses field, including compressive stress field was caused by plate movement (about 67-200 Ma before) during Yanshan period and extensional stresses field produced from upwelling of the mantle (about 36-66 Ma before) and dextral strike-slip stresses field induced by dextral strike-slip movement (about 24-35 Ma before)during Xishan Period. Extensional and dextral strike-slip stresses field during Xishan Period lead to reactivate of the older fractures and produce new fractures. Fractured oil and gas field should be explored on the Anfutun burial hill zone, Damintun Sag.
  • An improved pseudo 3-D oil/gas migration- accumulation model and its application in the Kuqa Depression, Tarim Basin
    SHI Guangren and ZHANG Qingchun
    , 2003, 30(4): 317-0.
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    A pseudo 3-D oil/gas migration-accumulation method for estimation of expelled hydrocarbon distribution was developed. This new methodology was apply to the Kuqa Depression in Tarim Basin and is able to: ①make hydrocarbon accumulation strength contour maps; ②calculate the hydrocarbon accumulation coefficient and the total hydrocarbon for each formation or a specified geological time; and ③generate histograms of cumulative hydrocarbon for each formation. The simulation results and predictions from this pseudo 3-D model have been proved in recent explorations.
  • Formation of the gas reservoirs of the Leshan-Longnvsi Sinian palaeo-uplift in central Sichuan
    YAO Jianjun; CHEN Mengjin; HUA Aigang and GAO Zherong
    , 2003, 30(4): 318-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The palaeo-uplift of Leshan-Longnvsi in central Sichuan Basin, in age of Sinian, is a complex petroleum system formed with many sources and periods，in which the hydrocarbon source is generated from sapropelic material dark shale in Qiongzhusi Formation basis, Lower Cambrian, then the dark seaweed dolomite and shale in the third member of Dengying Formation (Sinian). The Dengying Formation member Ⅲ hydrocarbon source reached peak generation period between Ordovician and Silurian, generated liquid hydrocarbons formed palaeo-reservoir in top of the palaeo-uplift. The first hydrocarbon generation was stopped around the end of Silurian. The second generation began in the Later Permian. From Triassic to Middle Jurassic, hydrocarbon source in Qiongzhusi Formation reached the main generation period, and the palaeo-reservoir formed on Dengying Formation weathering crust on the top of palaeo-uplift. From Later Jurassic to Early Cretaceous，the Qiongzhusi Formation reached a high generation，liquid hydrocarbons after thermal cracking became gaseous hydrocarbon in palaeo-reservoir，which gaseous hydrocarbon formed present reservoir after accumulation. Leshang-Longnvsi palaeo-uplift Sinian reservoir-cap rock is perfectly conservative, the Gaoshiti-Moxi structural belt and Huayinshang structural belt should be the potential target.
  • Pooling model of steep slop structure and lithological zone in north Dongying Sag
    WANG Zhigang
    , 2003, 30(4): 319-0.
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    The steep slop structure and lithological zone in the Dongying Sag is a complex fault zone developed under the multi-periods and multi-stress styles, which controlled the developments of six deposit system such as braided river delta, fan delta, diluvia fan, neritic underwater fan, steep deepwater turbidity fan and slump turbidity fan of neritic front-sand and three structure facies bands such as shovel-like steep fault alluvial fan, fan delta and small braided river delta and three structure rock facies such as diluvia fan on steep slope fault band of burial hill and bench terrace, fan delta, small ladder-like diluvia fan on steep slope fault band, slump turbidity fan and steep deepwater turbidity fan. The pooling model could be summarized as 5 patterns of forming reservoir such as sand updip and nip, anticline, fault-sealing barrier, thinner mud coat and turbidity lens. The results would be of important to forecast complex lithological pool.
  • Cabin-type oil and gas migration characteristics of the Western Sag, Liaohe Depression
    CHEN Zhenyan and SU Xiaojie
    , 2003, 30(4): 320-0.
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    Based on a systematic study of the fluid pressure system of the Western Sag in the Liaohe Depression, Eastern China, the concept of Cabin-type oil and gas migration system is herin proposed and modeled. Within the cabin, three systems are identified: a basal system ranging from 2900 to 3300 m in depth, a middle system from 1200 to 2900m, and an upper system above 1200 m. The middle cabin is the best oil trap because of its excellent super-high pressure seal and high porosity reservoir. For the Western Sag, attention should be paid to the upper cabin for exploiting shallow gas and heavy oil pools. In the lower cabin, lower buried hills in some sags should be the exploration targets.
  • Analysis on fault effect in Zhujiadun Gas Pool in Yancheng Sag
    LIU Dongying and WU Dongru
    , 2003, 30(4): 321-0.
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    The analyses on the formed conditions of Zhujiadun gas pool in Yancheng sag, show that its formation is closely related with faulting,not only with its structural traping actions,more with connecting and sealing functions of faults. After detailed research on gas migration indexes,characteristics of faulting evolution and analysis on hydrocarbon packages etc., these conditions have been acquired, i. e. ,the gas migrating direction is from the lower part to heading up, from the south to northern part totally,the Yan 2 fault provide main passages for gas moving heading up, and the reservoir strata offer passages for natural gas lateral migrating, and hydrocarbon preservation is concerned with weakening functions of fault activity. The formation of the gas pool is relative lately, mainly in deposition period of Yancheng Formation (Miocene).
  • The origin and hydrocarbon accumulation of Daxing conglomerate body in Langgu Sag
    ZHU Qingzhong; LI Chunhua and YANG Heyi
    , 2003, 30(4): 346-0.
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    Daxing fault controlled the limitation fault of the development of Langgu sag in Jizhong depression .It consisted of three isolated same direction faults in the early deposition of under 3rd member of Shahejie Formation.The same direction transmission slope is the entrance of sediment into the lake. The sediment is the sub-lacustrine fan system along side the transmission slope,with a characteristics of the positive circle of progressive sequence.The Daxing fault became a chain unified between the lately under the 3rd and up the 3rd member of Shahejie Formation.The main deposition center distributed within the transmission slope before the fault linked.Daxing conglomerate body have ample oil and gas because it has the 3000m thickness lake facies mudstone.The reservoir is the braided channel deposit.Porosity is mainly consisted of secondary pores including intra and inter-granular pore and fracture.The petrophysics of dolomite is better than that of limestone.The best hydrocarbon accumulation is the faulted anticlinal trap distributed the middle fan facies, the better is the faulted nose structure distributed on the fanhead.
  • Oil-source identification for the mixed oils derived from multiple source rocks in the Cainan Oilfield, Junggar Basin, Northwest China. Part I: Fundamental geochemical features of source rocks
    CHEN Jianping; LIANG Digang; WANG Xulong; DENG Chunping; XUE Xinke; JIN Tao; SONG Fuqing and ZHONG Ningning
    , 2003, 30(4): 347-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    Four hydrocarbon source rocks, in age of Carboniferous, Permian, Triassic, and Jurassic developed in the east of the Junggar Basin, Northwest China. The geochemical study shows that Permian source rocks, which contain high abundances of organic matter with good genetic potential, are the best hydrocarbon source rocks, and then, the Triassic source rocks in this area. The organic matter in Jurassic and Carboniferous source rocks mainly compose of type Ⅲ kerogen and their abundance varies greatly, for which the genetic potential is lower than that of Permian and Triassic rocks. These four source rock units in the Fukang Sag all reach a mature-high mature stage and have generated large amounts of oil. Permian extracts are isotopically lighter, and have low Pr/Ph ratios, are rich in β-carotane, tricyclic terpenes, gammacerane and C28 and C29 steranes, contain almost no diasteranes and have a low content of C27 steranes. Triassic extracts are characteristically rich in Ts, C29Ts and diahopanes, but have low gammacerane contents. The carbon isotopic composition of Jurassic extracts is noticeably heavier than that of Permian and Triassic extracts. Jurassic source rocks have Pr/Ph ratios generally > 3.0, and are rich in pentacyclic hopanes and C29 steranes, but poor in tricyclic terpenes, gammacerane, and C27 and C28 steranes.
  • Formation of heavy oil and correlation of oil-source in the western slope of the northern Songliao Basin
    FENG Zihui; LIAO Guangzhi; FANG Wei; ZHANG Juhe and SONG Lanbin
    , 2003, 30(4): 639-0.
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    A general geochemical analysis for the liquids of heavy oil reservoir show that the formation of heavy oil in this area is mainly associated with biodegradation of anti-oxygen bacteriea. The heavy oils can be divided into two types and five sub-types. The first type is biodegraded heavy oil that include three sub-types, serious, middle and light biodegraded oils. The second type is mixed heavy oils that contain two sub-types, mixture of oil and biodegraded oil, mixture of light hydrocarbon from oil evaporation and biodegraded oil. Comparing the biomarkers of oils and source rock, the heavy oils in the slope derive separately from matured source rock in Qijia-Gulong depression and low-matured source rock in the slope. The condition of abundant oil resource presents a good exploration prospect of heavy oils in the slope.
  • he hydrothermal process and origin of illitation deeply in the Jiyang Depression
    YUE Fusheng; ZHANG Jinglian and DU Letian
    , 2003, 30(4): 640-0.
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    It is known that after the buried, thermal evolution, hydrocarbon generation of organic matter, kaolinite's transfer to montmorillonite, montmorillonite's transfer to illite, which coupled with hydrocarbon generation and migration. Investigation of the Paleogene sediments in Jiyang Depression of Sheng1i Oilfield showed that the transfer from montmorillonite, kaolinite into illite, montmorillonite into potash feldspar, sericite, illite is the result of K+ metasomatism of deeper hydrothemol fluids, which associate with the generation of secondary quartz, and is the silicon release of K+ metasomatism. In the Jiyang Depression there are some evidences of deeper hydrothermal fluids: gypsum-salt generation, Paleogene reef and dolomization, anomalous high gold in crude oils, mantle-derived CO2 gas pool and 3He isotopic anomaly, high temperature of quartz fluid inclusions, basalt magma effusive eruption, and so on. Recognition of illitation, dolomization, gypsum-salt formation will bring about revolutionary effect on petroleum exploration in future.
  • Framework of sequence stratigraphy and filling style of Baiyinchagan Sag
    ZHANG Fushun; WANG Shenglang; SUN Yipu and ZHANG Fangdong
    , 2003, 30(4): 641-0.
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    Located in Er’lian Basin, Baiyinchagan is a depression with faults in north and overlap in south. An overall study has been carried out. Based on drill core, logging profiles, logs, and seismic data, as well as the classic pattern of sequence stratigraphic framework by the EXXON Oil Company and the base level cycle pattern of high-resolution sequence stratigraphy by T. Cross, two super-sequences and six three-order sequences have been identified in Bayanhua group, Lower Cretaceous,which are the fundamental target beds of this region. Six types of sedimentary facies have been recognized. Among these sedimentary facies, alluvial fans and fan delta are found on the steep slope in north of the depression, while braid river delta and turbidity fans are found on the ramp of south. Three times of lake transgression can be distinguished. The sequence evolution is that they formed in early time, developed continuously ,reached to the biggest scale in late time.
  • Lithological types and distribution features of Tertiary algal-limestone in Chaixi area, Qaidam Basin
    SHOU Jianfeng; SHAO Wenbin; CHEN Ziliao and SHEN Anjiang
    , 2003, 30(4): 642-0.
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    Tertiary of Chaixi area in Qaidam Basin developed algal-laminated, algal-stromatalite, algal-masses and algal-micrite limestones. The former three algal-limestones are good hydrocarbon-bearing reservoirs,and the dissolution porosity of a little algal-micrites developed, which also formed hydrocarbon-bearing reservoirs. The distribution features of algal-limestones,which mainly distributed in E32, N12 and N2 strata, are different. E32 algal-limestones,distributied in thick carbonate rock, are lower continential clastic and higher dolomite contents. The N12 algal- limestones are thinner interbeded with light gray to brown sandstone and mudstone with higher continential clastic contents and the N2 algal-limestones are even thinner interlaminate with other rocks, and its continential clastic contents are very high. The distribution features of the algal-limestone are controlled by regional structure activities, lake horizotal face changes and paleogeology environments.
  • Reservoir characters and evaluation of the Tertiary clastic sediments in the Northern Qaidam Basin, Northwest China
    GAO Yunfeng; PENG Suping; HE Hong and KONG Wei
    , 2003, 30(4): 643-0.
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    Drilling, well logging and core data from 35 wells are utilized for reservoir character study of the Tertiary clastic sediments in the north Qaidam Basin, Northwest China. The reservoirs are strongly heterogeneous, mostly fine sands and silts. Their microfacies include alluvial fan, river channel, deltaic distributary channel, and floodplain. Based on lithology, microfacies, and reservoir property, the reservoirs can be classified into three categories. Type Ⅰ- medium to fine sands deposited in floodplain meandering channels or deltaic distributary channels. This is the best reservoirs and found mostly in Nanbaxian, Maihai and Beiqiuling area. Type Ⅱ- medium to coarse sands, conglomeratic sandstones and pebbly sandstones deposited in braided channels, or occasionally in littoral or marginal lacustrine environments. Reservoir quality of this type is moderate. Type Ⅲ- conglomerate, silts or clayey silts deposited at beach, bar, alluvial fan, or floodplain setting. Type Ⅲ is the least desired reservoir type. Type Ⅱ and Ⅲ are the most widely distributed reservoirs in the region.
  • Haline lacustrine biohermal reservoir characters in Block Da 81-4 of the Yidong Oil Field, East China
    WU Huaguo; LI Chun and QIAN Zheng
    , 2003, 30(4): 644-0.
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    In Block Da 81-4 of the Yidong area, Jiyang Depression, bioherms in the Sha-4 Member of the Shahejie Formation were formed in haline lacustrine environment on ramp margin. Five small scale bioherms (2 algal reefs and 3 algal knolls) are in vertical succession. Three major lithofacies associated with bioherms are: ①dolomites dominate the lower algal reefs; ②limestones comprise the majority of the algal knolls; and ③limited presence of clastics and evaporates. Seven types of porosities are observed. They are inter-particle, inter-granular, mold-granular, growth-skeletal granular, breccias granary, inter-crystal granular, and structure fissure. The bioherms have undergone deep burial, dolomization, dissolution, deformation, and cementation, all being domiant diageneses affecting reservoir porosity. The dolomized branching algal reefs in Block Da 81-4 and nearby blocks are probably most promising exploration targets.
  • High-resolution sequence structural and stacking pattern study of the Es2 reservoirs in the Sheng-1 area, Shengli Oil Field
    LI Zhenquan and ZHENG Rongcai
    , 2003, 30(4): 645-0.
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    Sheng-1 area is located in the western part of the Shengtuo Oilfield of the Jiyang Depression in the Bohai Bay Basin. The oil-bearing upper part of the Member 2 (Es2) of the Shahejie Formation was deposited in delta plain low tortuous braided channels. The sand beds 1 to 3 of the Es2 can be divided into 1 intermediate, 5 high, and 14-16 super high order depositional cycles, each with different internal structures and stacking patterns. The high and super high order cycles demonstrate two types of sequence structures: symmetry and asymmetry stacking patterns and deepening upwards cycles. The two intermediate cycles asymmetric ascending half-cycles.
    • 综合勘探开发技术
  • Quantitative study on sedimentary microfacies
    CHEN Yefei
    , 2003, 30(4): 646-0.
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    The I-IV sandstone units of Member 2, Quantou Formation (Cretaceous), Siwujiazi Oilfield in the Songliao Basin, is characterized by poorly defined spontaneous potential and gamma ray logs. By analysing the regional sedimentary environments, sedimentary structures, single well facies, as well as microfacies markers and logging curves, four microfacies are recognized, including meandering stream point bars, crevasse splays, natural levees and flood plains. Four important parameters have been selected as indicators of microfacies, including porosity, shaliness, and sand percentage; these are used to build a discriminance function for each microfacies by using Bayes Successive Discriminate Analysis. The quantitatively identified microfacies for 136 uncored wells of the Siwujiazi Oilfield are modeled and tested, attaining an accuracy exceeding 90%.
  • Effects of diagenesis on reservoir property and auality，a case study of the Cainan Oilfield in east of Zhun Ga’er Basin
    PENG Shi-mi; DAI Jinyou; ZHANG Yiwei; XIONG Qihua and WANG Zhizhang
    , 2003, 30(4): 647-0.
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    A case study of the Cainan Oilfield in the east Zhun Ga'er Basin, Northwest China, establishes a relationship between diagenesis and reservoir property. Four parameters (apparent compaction, caulking ratio, matrix ratio, and degree of cementation) are quantified to measure diagenesis. Being a direct measure of reservoir quality and a composite indicator of diagenesis, porosity is linearly related to apparent compaction and caulking ratio. In the case of the Cainan Oilfield, it is estimated that porosity loss due to compaction is 1.8 times of all other diagenetic porosity losses combined.
  • Decrease uncertainty of geo-statistical model by using seismic data
    YU Guoyi; WANG Genjiu; MU Longxinhong and WANG Guihong
    , 2003, 30(4): 648-0.
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    The use of 3-D for a geo-statistical modeling of reservoir will be able to reduce the uncertainty of estimated sand bodies. The method of geo-statistical modeling via using the right seismic parameters is briefed as follows: quantity control to the input data by using the Variance Function; correlation analysis between the well data (hard data) and seismic parameters (soft data); finally, to decide the sand extent in 3-dimension by using the geo-statistical methods (e.g. Co-Krige), and achieve the optimized reservoir modeling. The example taken from the Xinchang Structure in the Xiaoquan-Qinggangzui tectonic zone, Sichuan Province shows it is an effective way by using the seismic data to decrease the geological risk in field development.
  • The application of seismic micro-facies analysis in Dagang seashore area
    ZHANG Yanzhang; LIAO Qianjin; FAN Junxia and ZHAO Haikuan
    , 2003, 30(4): 649-0.
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    Based on the difference in seismic-geology condition of complicated structure and reservoir, optimizes and picks multiples of geophysical technologies such as seismic micro-facies cluster, waveform classification, seismic attribute optimization, horizon correlation analysis to set forth analysis of seismic micro-facies and classification of sedimentary micro-facies. It points out potential area of lithology trap and gain remarkable geology and drilling efficiency, depending on structural information.
  • Gas reservoir recognize and prediction of Tabamiao Region in north Ordos Basin
    LUO Yu; MOU Zehui; ZHU Hongquan; ZHANG Keyin and FENG Fang
    , 2003, 30(4): 650-0.
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    Tabamiao is located at Yishan Slope Stripe in north Ordos Basin. The gas reservoir rocks is mostly consisted of Late Palaeozoic P1x and P1s riverway sandstone. The study summarize the lithology, electricity and geophysical character of Tabamiao gas reservoir, which set up the criterion of log parameters to recognize the gas, water and dry layers. Then it predicted the gas distribution of domain produce layers by using seismic special disposal technique. The result indicates that in most Tabamiao Region where has abundance sandstone is relatively favorable, especialy in area around Well DT-1 and Changjitu where sandstone grow and has a high gas saturation. The gas distribution feature prove that north Ordos Basin gas reservoir belongs to a deep basin gas.
  • Sandstone reservoir prediction of Duzhai Sub-sag in Dongpu Sag，Zhongyuan Oilfield
    PU Renhai; CAI Qixin; CHEN Jun and LI Wei
    , 2003, 30(4): 651-0.
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    The discovery of the Well PS12 in Duzhai Sub-sag in 1991 disclosed 28m (in the interval ranging from 4793m to 4821m) of sandstone in the stratigraphic unit Es33+4 with initial 35,000 m3/d of gas production. According to integrated research of the new 3-D data, well core and logs, the sandstone is reinterpreted as a trough-fill channel that flowed from north to south. The evidences are as: ①The west-dip angles of the sandstone on dip log decrease upward suggest a sandstone fill in a incised valley oriented in N-S direction; ②3-D seismic horizon amplitude maps show narrow linear or sinuous belts of sand stone along the sub-depression axis in north-south direction. In addition, the narrow belts of amplitude anomalies tend to branch out southward. These characteristics also define a north to south channel and deltaic tributary channels; ③ the thick sandstone shifts sharply from lacustrine shale at its bottom and top and shows no vertical grain-size variation interiorly.
  • The application of seismic coherent analysis technology in Chengdao Oilfield
    SUN Suehua and LIU Zhanjun
    , 2003, 30(4): 652-0.
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    Three dimensional seismic data imply the response of formation and lithology information underground. so it is very effective for solving geologic problem. Three dimensional seismic exploration is wide used in oil field. However，the traditional way is difficult to obtain clear and exact view of fault and special geobody. Coherency data can solve this problem effectively. By calculating the similarity of waveform convert the original amplitude seismic data to coherency data. Descript the algorithm of coherency data and the response of fault and special geobady in detail, it shows a good prospect of application of the coherence. In the process of exploration and production of Chengdao Oilfield，by applying coherent analysis technology，the distribution of fluvial sandbody precisely were forecasted. This guided the determination of well site. Very good economic and social benefit have been obtaine
  • Discussions on the traditional pore pressure evaluation methods by using well logging
    FAN Honghai
    , 2003, 30(4): 653-0.
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    Evaluation of pore pressure by using well logging is a common method that is hardly to be used in the none-mudstone formation and overpressure horizons. The establishment of relationships between the well logging parameters and pore pressure of strata is not totally reasonable and less the believable theory basements. The pore pressure proposed based on the experience formula from the nearby formation with higher permeability would be lower than that of practical pressure. These limitations should be paid attention on in case of that traditional pore the pore pressure is evaluated by using well logging information.
  • Water saturation explanatory model of argilla-ceous sandstone under the macroscopically electric conduction mechanism
    ZHU Jiajun; GENG Bin; GENG Shengchen; WANG Xuejun and SHI Dishi
    , 2003, 30(4): 654-0.
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    A kind of water saturation explanatory model of argillaceous sandstone is presented, including the formation water alteration during the lithification, and the argillaceous sandstone conductive volume as micro pore conductive volume occupied by the bound water and conductive volume in the effective pore. The conductors in those two conductive volumes have different conductive characteristics and their own conductive factors, so, the total conduction of the argillaceous sandstone is the summation of those two parts. The application of this model in the oil-base mud well has a good agreement between the explanation and the analysis data.
    • 油田开发与油藏工程
  • A perspective of development in reservoir description
    SHEN Benke; HU Yongle and TIAN Changbing
    , 2003, 30(4): 655-0.
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    In view of the development phases of reservoir description as well as the development stage of other branches in sciences, reservoir description technology in the 20 century could be categorized into following stage: technology preparation stage before the formal establishment of reservoir description in 1960s-1970s, whereas strictly speaking, this stage could not be taken into the chronicle of reservoir description development; Establishment of reservoir description and determination of description workflow in 1980s could be regarded as the second stage, in which sedimentation tectonics geology, reservoir geology and petroleum geology are taken as guidance along with combining geology, seismic, well testing as well as computer technology altogether to transform logging analysis from a specific well bore to the whole block for description and analysis; rapid development stage in 1990s, with residual oil distribution being the study focus, reservoir description technology has been developed to accurately describe and predict underground reservoirs, hence to build 3-D quantitative geological model. Development trends of reservoir description in the future will be as further development and application of high-resolution sequence stratigraphy; inter-well seismic technology in the oilfield development as well as 4-D seismic technology for performance surveillance.
  • Automatic historical matching method and its application in reservoir simulation
    CHEN Zhaofang; ZHANG Jianrong; CHEN Yueming and LI Huipeng
    , 2003, 30(4): 656-0.
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    A non-linear optimum problem defined in a n-dimensional space is solved with the creation of an objective function by introducing optimum theory, restraining initial and boundary reservoir conditions, and applying historical matching methodology. The principles for adjusting parameters during historical matching process include:①priority is not predetermined; ②sensitivity is given priority; and ③local adjustment follows overall consideration. To reduce the adjusted parameters, an analytical function is used to express the relationship between relative permeability and saturation. The studied area was divided into several sections based on reservoir geology and well distribution, and each section was simulated separately. An automatic historical matching was then conducted on individual wells in fault-confined blocks to collect composite water cut and formation pressure data. The major adjustable parameters are relative and absolute permeability. With 126 experiments, the matching results are consistent with historical production data.
  • Optimal flooding patterns in fractured low-permeability sandstone reservoir
    LIU Ziliang; WEI Zhaosheng; CHEN Wenlong and MA Liwen
    , 2003, 30(4): 657-0.
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    An optimized flooding pattern in fractured low-permeability reservoir should delay directional water break-through, prolong water flooded time, and deal with the problem of water injection failure. Because of the generally slow pressure transfer rate, the producer-injector spacing should be relatively close so that the well pattern is flexible for adjustment during the late development phase. Four types of flooding patterns are used in the fractured low permeability reservoir of the Jilin Oilfield: ①skew inverted nine-spot flooding arranged in an equilateral triangle pattern (Fuyu Oilfield); ②flooding pattern with the well array direction at 22.5° with the fracture strike (Xinli Oilfield); ③flooding pattern with the well array direction at 45° with the fracture strike (Xinmin Oilfield); ④skew inverted nine-spot flooding arranged in a rhombic pattern (Min 43-8 block and Daqingzijing Oilfield). The skewed inverted nine-spot pattern flooding with a close well spacing should be used during the initial development phase, and the pattern should be adjusted to linear flooding during the late development phase. The well array direction should be parallel to the fracture strike.
  • Simulation experiment on high-rate production in carbonate gas reservoir without marginal and bottom water
    XIANG Yang; XIANG Dan and HUANG Dazhi
    , 2003, 30(4): 658-0.
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    The overburden pressure, formation pressure, formation temperature, and initial water saturation of fractured carbonate gas reservoir without marginal and bottom water have been simulated. The elastic gas drive experiment has been done in the condition of 0.55-11MPa by using whole diameter dolomite cores. The relationship between core permeability and recovery rate (draw-down pressure) has been studied depending on the simulation experiments. The permeability decline magnitude of the cores with the permeability more than 18×10－3μm2 is the greatest when pressure difference is from 0.55 to 4MPa, therefore the draw-down pressure of this group of reservoir should be less than 1.5MPa. With the pressure difference of 3MPa, the average permeability decline magnitude of the cores with the permeability between 2×10－3μm2 and 18×10－3μm2 is 17%, hence the draw-down pressure should be less than 5MPa.
  • Non-linear optimal modeling of production manipulation and its application
    SHANG Mingzhong; Ge Yingjie; ZHONG Taixian and LI Shurong
    , 2003, 30(4): 659-0.
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    The purpose of non-linear optimal modeling of production manipulation is to get the maximum combined profit from all 9 production components under various conditions. Besides a maximum profit, certain conditions must be met: ①average cost must be under a given limit; and ②the gross investment for all production components is less than a preset budget. Given an oil field, a non-linear optimal model can be established to satisfy these conditions as well as the annual productivity and profit goals per administrative requirements for a multi-year planning period. With such a model, annual production and cost distribution for all 9 components can be programmed and manipulated to realize the maximum profit.
  • Mineral and lithological feature of Dalinghe heavy oil reservoir and the effects on development in the Block Du212, Shuguang Oilfield
    MA Mingfu; XU Huaimin; DU Lidong and QI Kai
    , 2003, 30(4): 660-0.
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    The hydrocarbon in the Dalinghe reservoir, developed within the Sha-3 sub-member of Shahejie Formation in the Block Du 212, Shuguang Oilfield (Liaohe Oil area) is a heavy oil pool. Based on the information of cores and thin sections from 11 wells, the reservoir lithology is mainly gravel, greywacke, medium-fine sandstone and the cement is loose. The reservoir contains high caulking stuff content, which is mainly clay mineral among which the montmorillonite content is highest. The lower oil formation is superior to the upper formation as to composition maturity and texture maturity, and the clay mineral content in the upper formation is higher than that in the lower formation. When the oil field has been being developed, the progress should be selected as matching pH of the injected fluid, adding certain K+, taking moderate injection-production rate would not be higher than the critical value of the migrating micro-grain within the oil formation.
  • The mechanism of anomaly produced fluid of well and warning signs of earthquake
    XU Shouyu and SUN Wanhua
    , 2003, 30(4): 661-0.
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    It is the earthquake warning signs of that the produced fluid of well in Huimin Sag come forth anomaly. The gestate process of earthquake is the variational process of regional terrestrial stress. It causes the change of pore-fluid press. It augments diffrential pressure. It also changes the velocity and quantity of flow in wells. It varies the solubility of underground liquid, the physical and chemical property of underground fluid also changed.
    • 油层保护与改造
  • Carbon-dioxide hydraulic fracturing technology and its application to the Upper Paleozoic gas reservoirs of the Changqing Oilfield, Northwest China
    ZHENG Xinquan
    , 2003, 30(4): 662-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    CO2 foam hydraulic fracturing technology was applied to the low permeability and low-pressure Upper Paleozoic gas reservoirs (depth within 4000m) in the Changqing Oilfield for production increase experiment. With HPG as thickening agent, AC-8 acidic cross-linker was developed in the frac fluid research. YFP-1 foaming agent, CQ-A1 and DL-10 cleaning additives were selected because of their excellent foaming characteristics in water. Intensive hydraulic fractures were produced by applying increased amount of liquefied CO2. Comparing with water based frac fluid, application of CO2 foam frac fluid will typically increase flow back efficiency by 50%, shorten flow back time by 40 hours, and reduce formation damage by 30% (average formation damage is 48.51%).
    • 油田非注水开发
  • Determination and recognition of AMPS copolymer simulation parameters
    HOU Tianjiang; ZHAO Renbao; MO Bin; WU Yasheng; ZHANG Jingling; LIU Shuqin; XIE Lixin and ZHANG Huanen
    , 2003, 30(4): 663-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The method of determination HPAM simulation parameters under the mild conditions (T≤75℃,TDS≤20g/L) is practically used, but carried no such research under harsh conditions (high T and high TDS). In order to provide some basic recognition of probability of large scale application of AMPS co-polymer in Zhongyuan Oil Field, some methods and instruments, including Starch Potassium Iodide Method and Rheometer and Core Flow Instrument are studied and presented for determing some key simulation parameters. Five AMPS co-polymer concentration are designed for carrying on an experince of 20 points absorption and residual resistance factor under 86℃, by using core flow test and zero shear viscosity of 5 kinds TDS. The analysis result suggests that these parameters are commonly higher than HPAM’s and the rheological characteristics of AMPS co-polymer is different with that of HPAM due to it’s existed dispersed micro-gel in this solution.
    • 油藏物理
  • Experimental study on oil-water relative permeability under natural reservoir conditions
    LU Chengyuan
    , 2003, 30(4): 664-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The experimental results on oil-water relative permeability, by using core samples from the Well 7-44-J245 in the Gudong Oilfield of Shengli petroliferous area, reveal that an increase in net overburden pressure led to changes in pore structure (mainly the pore throat), and the water permeability increases more rapidly relative to oil permeability which decreases more rapidly than water permeability. This is the major factor affecting percolation. Temperature increase will also change the oil-water viscosity ratio, leading to a higher irreducible water saturation but a lower residual oil saturation. However, temperature has little impact on relative permeability when oil-water viscosity ratio is close to 1. At 30MPa and 80℃, the water-oil viscosity ratios of refined oil/brine and degassed-dehydrated oil/brine are close. Natural reservoir conditions should be simulated during the relative permeability experiment. The experiment can be designed to simulate only the net overburden because percolation is not sensitive to the absolute values of overburden and pore pressure.
  • Predicting rock compressibility by artificial neural network
    WANG Anhui; ZHANG Yingkui; GAO Jinglong; SHAO Wenyong; RUAN Baotao; ZHU Mingwen; WANG Haizhong and LIU Binghui
    , 2003, 30(4): 665-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    Due to the requirements of the mass balance calculation, elasticity energy calculation, well-testing interpretation, and overcoming the difficulty in measuring the rock compressibility in the oil-gas reservoir engineering in Jilin Oilfield，east China, earlier experience formula is tested and verified by using the present data of practice rock compressibility in Jilin Oilfield, east China, resulting in 504.20%-681.15% of the total relative error. The study has found that these experience formulas are hardly to be used and applied in the Jilin Oilfield. So, taking pressure and porosity as input layer parameters and rock compressibility as output layer parameter，the rock compressibility is calculated by using the error back-propagation of artificial neural network，which is named as a BP method. The study has predicted the rock compressibility in the Block Ⅰ and Ⅱ of Jilin Oilfield，respectively, and tested and verified the reliability of this method by using practice data, resulting in 12.8% of the relative error only.
    • 油层保护与改造
  • Visual simulation of porous structure in packed gravels
    BO Qiwei; DONG Changyin; ZHANG Qi; LI Zhifen and ZHAO Dongwei
    , 2003, 30(4): 666-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    A certain number of suspending gravels are randomly selected to visually simulate sediment precipitation process. While sediment compaction due to gravity is not taken into consideration, the simulation procedures include precipitation initiation, selection of colliding grains, stability analysis, and moving trend prediction. The porous structure and throat size distribution can be derived from statistical analysis of the simulation data. In the present experiment, the simulation was conducted twice on gravels of 0.4-0.8 mm in diameter. Both sets of data indicate that the throat size did not demonstrate normal distribution. For a specific grain size, multiple simulations must be conducted and the data should be statistically treated in order to arrive at a reliable result.
  • Sensitivity of low porosity and permeability reservoir of upper Es4 Member in Lijin area, Dongying Sag, Jiyang Depression
    XU Jianhua; HAO Xinwu; WANG Jinyou and WANG Yanhong
    , 2003, 30(4): 667-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The deep near-shore submarine fan reservoirs of the 4th member of Shahejie Fm. (Es4 member) in Lijin area, located in Dongying Sag of Jiyang Depression, have low porosity, low permeability with strong heterogeneity. According to sensitivity flow tests, the potential sensitivity of these reservoirs was evaluated based on systematical rock-mineral analysis of mineral components, physical properties, pore structures, etc. The studies showed that the water and salinity sensitivity obviously exist in these reservoirs. Following effective measures to protect reservoirs during drilling were recommended as follows: using low density drilling fluid with complex shield temporary blocking agent (whose salinity is lower than 40g/L) under low penetrating rate (<2m/d); negative pressure perforating; using high condensation acid (mostly concentrated phosphoric acid) to carry out acidization and block removing.
    • 国际交流与合作
  • Main reservoir modeling and horizontal drilling design for the lower Shanxi Formation in the Changbei Block of the Yulin Gas Field, Ordos Basin
    SHOU Xuancheng; HE Guanghuai and Nick Fest
    , 2003, 30(4): 668-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The main reservoir in the lower Shanxi Formation (Lower Permian) is composed of quartz sandstones in Changbei Block of the Yulin Gas Field in the east Ordos Basin. This reservoir will be developed through horizontal drilling. Reservoir modeling reveals that the quartz sandstones are continuously distributed sheet sands, formed in inner-incised valleys of laterally migrating braided channels. The average accumulated thickness of the sheet-like sandstones at the axial part is 15.77 m. It gradually changes into single layer on both sides of the main channel. The dimensions of the multi-layer sandstones are 5-30 km wide and 9-40m thick. A single-layer sandstone is 0.25-1 km wide and 5-8m thick. The coarse to very coarse nature and high component maturity of the quartz sandstones are favorable for keeping original porosity. However, there are internal fluid barriers due to heterogeneity of the sediments. The average spacing of such barriers is 600m. The two horizonal wells are designed to drill through these barriers and to connect the reservoirs. The horizontal drilling will be steered based on LWD data.
  • Source rock evaluation and crude oil geochemi-stry in the Fula Depression, M-Basin, East Africa
    XU Juzhen; LUO Xiaoping and WANG Haihong
    , 2003, 30(4): 669-0.
    Abstract ( ) Download PDF ( ) Knowledge map Save
    The Well Fu-1 is a regional exploration well in Fula Depression, M-Basin, in which the high production commercial oil was obtained. The geochemistry character of the Well Fu-1 and Bal-1 suggests that the horizon developed in the middle interval of the Abu Gabra Formation is the low-matured good to excellent source rock.It is supposed that the hydrocarbon source rock in the deeper could be higher mature. The source rock in the Fula Depression is the best strata in M-Basin with greater resource potential. The thermal evaluation of hydrocarbon source rock in this well is at a low mature stage.The crude oil had been affected by biodegradation, but it's saturated hydrocarbon has a high percentage of isoporaffin and an entire sequence of n-alkane. It is supposed that the reservoir was filled twice. The crude oil has tricyclic and sterane,high C29Ts,an entire sequence of diasterane and some γ-cerane. In the series of homohopane, the 22S configuration is bigger than 22R configuration. About the series of sterane, it has high diasterane; the C27, C28, and C29 sterane distributed in a dissymmetry “L” style. The depositional water is fresh water-little salt water.
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