, Volume 33 Issue 5

    

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专家论坛
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  Identification and evaluation of Xushen volcanic gas reservoirs in Daqing

  XU Zhengshun; WANG Yuming; PANG Yanming; SHU Ping; GAO Xiang and AI Xingbo

  , 2006, 33(5): 1372-0.

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  Geological reserves in the Xushen gas field have accumulated hundred billions of cubic meters, of which 89.8% is from volcanic reservoir. It is the bottleneck-difficulty of exactly describing volcanic reservoir that always restricts the exploration and exploitation of deep gas. Daqing Oilfield organized scientists and technicians of different levels to tackle the hard-nut problems during the period of Tenth Five-Year Plan. The article discusses a set of research techniques applicable to volcanic gas pool, including lithology identification and description, lithofacies identification and description, volcanics identification, reservoir space description, and comprehensive reservoir evaluation. The practical application of these technologies in the Xushen gas field is expounded.
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  A numerical model of overpressure history with higher accuracy

  SHI Guang-ren

  , 2006, 33(5): 1373-0.

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  Overpressure history is one of the important results of basin modeling. Its accuracy mainly depends on the calculation of effective stress of rock matrix. There exists the problem that the accuracy of the stress calculated is so low, especially in the middle and deep formations, that it affects the accuracy of the subsequent histories of hydrocarbons generation, expulsion and migration-accumulation. Based on the works from pioneer contributors and the author, and by using Darcy's law and mass conservation law, the mathematical model of the stress is improved so that it can be used in basin modeling, and the corresponding module is programmed. In the application to several basins and especially to the present values of overpressure histories of Well Kela 2 and Well Yinan 2, the results closely match the field-measured pressure data, showing that the model is of higher accuracy and enables the practical stress simulation without rock mechanics experiment.
油气勘探
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  Application and prospect of 3D seismic pre-stack time migration processing technique

  ZHANG Ying

  , 2006, 33(5): 1374-0.

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  3D seismic pre-stack time migration is a new seismic imaging technique under development, and is being used in petroleum industry both at home and abroad. Pre-stack time migration processing techniques of 3D seismic data are systematically studied in terms of practical aspects. The technical features of pre-stack time migration and the differences between this kind of migration and the others are analyzed. Three key techniques, which strongly affect the results of 3D pre-stack time migration, are studied and summarized in detail. The application conditions are proposed. The future development of this technique is also forecasted.
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  Mercury in oil and natural gas and its critical assessment

  LIU Quanyou; DAI Jinxing; LI Jian and HOU Lu

  , 2006, 33(5): 1375-0.

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  Abundance and forms of mercury in oil and gas have been increasingly paid attention to. There are mercury and its compounds in natural gas, condensate gas and crude oil. In natural gas, mercury exists exclusively in its elemental forms. Condensate gas and crude oil contain Hg of different forms, including elemental, organic, inorganic and suspended mercury. Hg stems from the hydrocarbon sources in natural gas, with Hg abundance higher in coal derived gas than in the oil derived gas. The abnormally high abundance of mercury in natural gas is related to the deep structure. Owing to its strong adsorption, Hg can easily form amalgams with a variety of metals causing problems in transportation pipeline or tank and other processing equipments, and even resulting in catastrophic events. So the abnormally high mercury must be removed from natural gas.
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  Sequence stratigraphy pattern of the terrestrial rifted basin

  GUO Shaobin

  , 2006, 33(5): 1376-0.

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  The sequences of continental Tertiary rifted basin in East China show that there are two basic types of slope-break: syndepositional fault slope-break and bend slope-break. When the horizontal level falls down the slope-break, it makes a full horizontal level fluctuating cycle, forming lowstand system tract, lake expansion and lake shrinking tracts (trisection tracts). When the horizontal level does not fall down the slope-break, it makes an incomplete horizontal fluctuating cycle, forming lake expansion and lake shrinking tracts (dimidiate tracts). The two sequences stacked regularly in the vertical make the sequence filling of the basin. In the sequence of dimidiate tracts, mudstone and oil shale in the lake expansion system tract are good source rocks and seals, providing favorable conditions for forming giant oil/gas fields. In the sequence of trisection tracts, lowstand sandbody with favorable oil-accumulation conditions and identifiable seismic profiles is preferred for subtle traps.
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  Modeling and application of the lithofacies-controlled primarypore reservoir of proximal sandstone

  ZHOU Cancan; WANG Yongjun and ZHOU Fengming

  , 2006, 33(5): 1377-0.

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  Proximal sandstone, characterized by fast lithologic changing and strong heterogeneity, occupies a large proportion in terrestrial sedimentary formation. The numerical reservoir model generated with the general method (generating the model with homogeneous reservoir parameters) has poor precision, and it can not meet the needs of well log interpretation, evaluation, reserves calculation, and the description and modeling of reservoirs. Although facies-controlled modeling improves, to some extent, the precision of the reservoir parameter model, some problems such as artificial factors and poor precision remain to be solved in the lithofacies identification. To improve the precision of the model, the concept of lithofacies-controlled modeling is brought forth on the basis of petrophysics. The change of primary pore reservoir parameters of proximal sandstone is mainly controlled by lithofacies, and the model generated under the effective classification of the proximal sandstone based on lithofacies is more precise and easier for computer processing. The application of the method got good results in Guantao Formation of the Laoyemiao area in Jidong Oilfield.
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  AVO fluid inversion: theory and practice

  GAO Jianrong; TENG Jiwen; LI Ming and ZHANG Yunmian

  , 2006, 33(5): 1378-0.

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  AVO fluid inversion can quantitatively determine the probability distribution of fluids in a reservoir. Procedures are as follows: establish a Monte-Carlo simulation model from logging curves, get the synthetic data using Biot-Gassman theory as the fluids are oil, gas, and water in the model, get intercept and gradient using Shuey's function, compare the intercept and gradient values from the seismic data with the model values, and finally determine the probability of each fluid using Bayesian theory. Compared to the one phase fluid, when the fluid is composed of two or three phases, the predicted value is low owing to the overlapping of the probability distribution graph, but its precision is still high. The technology was successfully applied in the middle Sichuan Province.
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  Distribution of the Middle-Late Ordovician reef bank reservoir in Central Tarim Basin

  LIU Yanli; FAN Tailiang; XUE Yanmei; QIU Chun-guang and ZENG Qing-bo

  , 2006, 33(5): 1379-0.

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  Reef bank facies, developed in the Middle-Late Ordovician in the Central Tarim (Tazhong area), includes organic reef, bioclastic bank and lime-mud hillock. The reef bank in logging curves has lower SDT, lower gamma, and higher resistance rate. The seismic reflection has direct or indirect characteristics. The reef-bank reservoir can be vertically divided into two periods: the earlier period is dominated by reef-bank, while the later period by lime-mud hillock. The migratory trend is toward platform. Horizontally, the reef bank is distributed, in the form of strips, in the developed tectonic zones, hanging walls, paleogeomorphic bumps, platform margins, and geomorphic breaks. The earlier reef bank is mainly distributed nearby the fault zone of Tazhong No.1 and inside the platform along Well Z1-TZ23. The later reef bank is mainly distributed nearby the No.10 fault zone and inside the platform along Well Z1-TZ23.
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  Application of DR (Dynamic Register) technology in T3x gas reservoirs in West Sichuan

  LI Xiangui; FAN Jufen and ZHANG Xueying

  , 2006, 33(5): 1380-0.

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  The T3x gas reservoirs in the depression of West Sichuan is the deep continental tight clastic rock gas reservoirs with the characteristics of tight, low permeability, thin interbed, multi-layer nappe, and high heterogeneity. Aimed at the problems of difficult oil & gas prospecting and low profit in the reservoirs, the DR (Dynamic Register) technology, a seismic technology for detecting oil and gas, is developed based on scattering of seismic waves. A big DR value means that the seismic data has a high decay rate of dominant frequency and an abnormally high speed, indicating a high probability of rich gas in the reservoir. The technology only applies to the reservoir whose thickness is bigger than the minimum reservoir thickness identifiable in the seismic section. The technology is successfully used in the T3x gas reservoirs.
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  Application of impedance-constrained logging data in reservoir facies modeling

  LI Yujun; DENG Hongwen; TIAN Wen; CHENG Yanwu and ZHANG Yanqiu

  , 2006, 33(5): 1381-0.

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  The multi-step modeling technique is used in the description of sandstone and shale reservoir with seismic and well-logging data in the area of large well distance and less well drilled. The natural gamma and spontaneous potential are simulated in the way of collocated co-Kriging simulation. In this process the well-logging data is constrained by seismic information according to the relationships between impedance with natural gamma and spontaneous potential. Then a lithofacies modeling is built on the relationships between GR and SP with lithofacies. The method was used to establish the lithofacies modeling of J1s22 in Moxizhuang, middle Junggar Basin. The modeling can predict the sandstone's distribution and explain the complicated distribution of oil and water.
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  Cenozoic tectonic evolution and hydrocarbon accumulation in Bonan Region

  MA Baojun; QI Jiafu; LIU Yang and CAO Aifeng

  , 2006, 33(5): 1382-0.

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  Based on the balanced section and the decompaction correction principle, the tectonic evolution of Cenozoic in the Bonan Region is analyzed from tectonic geometry and movement. The marginal slip normal faults are the main feature of the structure. Influenced by basement rocks and border faults, the structures in the west and in the east are obviously different. The Cenozoic tectonic evolution is divided into Paleogene faulting episode, Neogene depressing episode and Quaternary Depressing episode. The period between Ek and Es3 is the primary faulting phase. The tectonic movement controls the distribution and type of traps. The Tertiary traps mainly occur in the northward bulge in the northern slope of the Chenjiazhuang uplift, with the stratigraphic trap in the south and the structural and structural-lithologic traps in the north. The stratigraphic trap is the main type in the upper position of the slope south of the slope break, while the structural trap and the structural-lithologic trap dominate in the deep water area and the in the vicinity of the slope break.
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  Vertical distribution and genesis of the secondary pore in deep formation of Paleogene at Dongpu Sag

  WANG Yong; ZHONG Jianhua; CHEN Hao; LI Guoying and JIANG Lin

  , 2006, 33(5): 1383-0.

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  Through the analyses of various data, including thin section analysis, SEM, carbonate content, reflectance of vitrinite, clay, reservoir property and others, it is found that the corrosion of the acidic compositions of feldspar, carbonate, sulfate, etc., is the key factor for the generation of reservoir secondary pores. With burial depth, the corrosion degree of carbonate decreases and that of feldspar increases. The main types of the secondary pores are intergranular pores, intragranular dissolved pores, cement dissolved pores, moldic pores, and fractures. Vertically, there are four secondary pore systems distributed in the formations from 2375m to 2675m, from 2975m to 3350m, from 3675m to 4200m, and below 4500m. The mechanisms of genesis include: thermal evolution of organic matter, experiments indicate that the thermal degradation makes kerogen produce a large amount of organic acid before it goes into the oil-generation windows; abnormally high fluid pressure, the fluid thermal cycle convection and curtain-draining hydrocarbon will enlarge oil-generation windows and lead to the forming of secondary pores; eluviations at unconformities or fracture zones produce weathered crust secondary pores.
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  Differential accumulation of oil and gas between hanging and lower walls of fault and its genetic mechanism in the northern edge of Qaidam Basin

  LI Hongyi; JIANG Zhenxue; PANG Xiongqi; LUO Qun and LI Yu-xi

  , 2006, 33(5): 1384-0.

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  Oil-gas reservoirs in middle and shallow strata exist in the traps of lower walls of faults in the northern edge of Qaidam Basin, which is opposite to the Kunbei area in the southern edge of the basin. Geological conditions of faults and faulted belts in the middle-shallow strata show that the reasons for the enrichment of oil and gas in the lower walls of detachment faults in the northern edge are as follows: detachment faults in the middle-shallow strata don't incise source rocks and cannot provide oil and gas to the hanging wall; faulted belts have zonations because of sealing differences in the direction vertical to fault-plane; the sealing of the zones below the main fault-plane gets better gradually down the slope, providing favorable conditions for the formation of multilayer oil-gas reservoirs in the lower walls of detachment faults. The lower walls of detachment faults connected by faults incising source rocks are important exploration fields in the northern edge of the basin.
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  Sedimentation mechanism of "gypsum rock" in Kongdian Formation and Sha 4 Member of Shahejie Formation in Huimin Sag—With the "gypsum rock" of Well MS1 as an example

  YUE Zhipeng; ENG Jun; GAO Zhiwei and LIU Yuliang

  , 2006, 33(5): 1385-0.

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  Based on the in-situ log data of Well MS1 and the analyses of the structure and depositional history of the study area, "sedimentary differentiation", "hybrid sedimentation" and the "regularity of the reversed rocks" in source and sedimentation areas are introduced to track and compare the source materials of the "gypsum rock" layers of Kongdian Formation and Sha 4 Member in Huimin Sag. Different from the conventional gypsum layer, the layers are the hybrid sediment of sandstones and the lake-basin chemical salts formed by physical and chemical actions.They are the result of the combination of the source supplied by the salient Lower Paleozoic carbonate mass which experienced weathering and the shrinking of the lake basin caused by drought. The exact nomenclature for it should be "fine sandstone with gypsum silt".
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  Mesozoic deformation and tectonic evolution in Chengdao, Southern Bohai Bay

  CHENG Xiaogan; TANG Qisheng; CHEN Hanlin; QIN Du and YANG Shufeng

  , 2006, 33(5): 1386-0.

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  The paper applies seismic and well-log data to the study of the Mesozoic structural characteristics and tectonic evolution in Chengdao Region. In Triassic, the NW-trending folds and NNW-trending reverse faults developed in Chengdao Region as a result of compressive stress, and the Chengbei 20 fault was a representative reverse fault. From Late Jurassic to Early Cretaceous, the structural characteristic was mainly extension in the region, and there developed fault basins controlled by NNW-trending normal fault. The Chengbei 20 fault, which controlled the very thick Mesozoic deposits, was the chief basin-controlled fault in Chengdao Region at the stage. Simultaneously, EW-trending dextral strike-slip faults cut Chengbei 20 fault. Because of contracting deformation, the unconformity between Cenozoic and Mesozoic and inversion structures were formed in Late Cretaceous.
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  Origin of 3rd Member salt rock of Shahejie Formation in Dongpu Sag

  SU Hui; XU Huazheng; ZHANG Jinchuan; QU Liping; WANG Pingxia; ZENG Tan; LI Guixia and QIAO Zhaoze

  , 2006, 33(5): 1387-0.

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  In Dongpu Sag, red sediments can be found within the salt-gypsum developed in 3rd Member of Shahejie Formation(Es3). Shallow-water and exposed signs are also found as scour surfaces, mud cracks and ripple marks in the cores. Lakeshore on-off signs of lowstand wedge, truncation and downlap are recognized from seismic profiles. These indicate that the water depth of paleolake changed during the deposition of Es3. Deep-grey and dark mudstones and a few gravity sandbodies developed in the highstand period, while salt rock, gypsum rock, lowstand deltas and fan deltas developed in the lowstand period. As a result, deep lake mudstones are interbedded with evaporites and lowstand sandbodies. The paper argues that the salt rocks are deposited in shallow water, the salt comes from the Lower-Middle Ordovician series of the surrounding uplifts. This argument is different from the past theories of "high mountain deep lake", "salt deposited in deep water" and "salt deposited in marine facies".
油气田开发
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  Establishing applied divisions of oilfield development geology

  JI Bingyu and LIANG Wenfu

  , 2006, 33(5): 1388-0.

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  Conventional oilfield development geology is no longer able to meet the demand of the flourishing development techniques. Aimed at this situation, this paper discusses the necessity to establish the applied divisions of development geology. According to the tendency of the application and development of oilfield development techniques,it suggests that within the near future, oilfield development geology be divided into two divisions (water-flooding geology and tertiary-recovery geology) and individualized and specialized research is conducted on them. Though both are on the basis of conventional geology, water-flooding geology focuses on the development geology for horizontal well and profile controlling, while tertiary-recovery geology emphasizes the construction of development geology for polymer flooding, combination chemical flooding, microbe-enhanced oil recovery, and thermal recovery. The research contents, methods and criteria for the establishment and development of the applied divisions of oilfield development geology should be based on the studies about recovery mechanisms, focused on the demand of oilfield development design, and continuously developed and improved.
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  Compatibility between polymer molecular size and pore throat in reservoirs

  ZHU Huaijiang; LIU Qiang; SHEN Pingping; LUO Jianhui; YANG Jingbo and LIU Yuzhang

  , 2006, 33(5): 1389-0.

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  In polymer flooding, polymer molecules undergo sifting by pore throats when passing through porous media. According to the "bridging" principle, the relationship between the hydrodynamic radius (Rh) of molecule that can block pore throat and the radius of pore throat (R) is: Rh＞0.46R. The median of average radii of pore throats in reservoirs suitable for polymer flooding ranges from 4μm to 16μm. The main peak of normalization weighting distribution function (f (Rh)) relating to the size of polymer molecular clew appears in the range of 10nm to hundreds of nm, sometimes with a secondary peak in which Rh is thousands of nanometers or even bigger. With salinity increasing and electric field strengthening in solution, the bigger the size of the clew, the easier is it to be compressed. The compression makes the peak of f (Rh) move to the direction of bigger molecular size. The molecular structure modification of comb-shape polymer (CP) boosts the rigidity of backbone chain, as a result, the Rh of CP and accordingly the viscosity of solution increase. Compared with HPAM with almost the same molecular weight and degree of hydrolysis, the change of viscosity of CP solution is a bit bigger than that of Rh. Polymer molecular clews with Rh of thousands of nanometers or bigger can block the porous medium with small pore-throat radius, especially when the polymer solution is prepared with fresh water.
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  低序级断层识别技术在复杂断块油藏注采调整中的运用

  ZENG Xiangping; YANG Haizhong; WANG Hong and JIANG Kaihui

  , 2006, 33(5): 1390-0.

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  The southern district of Gudao Oilfield is a heavy oil and sparse sandstone reservoir, which is complicated by faults, and has complex geologic conditions. 13 faults separate the whole district into 11 blocks, and every block has its own oil and water system, which brings bad effect on polymer flooding. In order to recognize the rupture system, adjust the injection-production corresponding relation and improve the effect of polymer flooding, the technologies of small wave and more scales test and coherence analysis are used to explain farewell faults, and the distribution map of the faults is redrawn in the south district. The methods of interference test and performance analysis are employed to test the veracity of the new rupture system. Based on above, the injection-production corresponding relation is adjusted, with the polymer flooding effect improved.
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  Mechanisms and applications of removing blockage with oscillating jet and acid

  HUANG Zhongwei; LI Gensheng; LIU Quanguo; LIU Lingling and NIE Xiaoli

  , 2006, 33(5): 1391-0.

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  Although the conventional blockage removal technology with physical or chemical methods can clean the damage of the formations near wellbore, it is difficult to drain impurities, especially the residue from acidization, out of the formations. The paper presents a novel technology with two steps: using two sets of guns (equipped with oscillating nozzles and blasting acid) as two oscillating sources, the overlapped vibration in the formations and the acid will loose and shed the blockage; lowering a packer into the wellbore and pumping clean water from an annular pump, the water will flow into the formations and bring the impurities to the surface through well tubing. This technology was applied to 13 water-injection wells in Shengli Oil Production Plant, Shengli Oilfield, and satisfactory results were achieved in removing blockage and enhancing water injection.
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  Horizontal well development technique and its practice for complex fault-block reservoirs in Jidong Oilfield

  ZHOU Haimin; CHANG Xuejun; HAO Jianming and ZHENG Jiapeng

  , 2006, 33(5): 1392-0.

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  Jidong Oilfield is a complex small-fault-block reservoir in the fault basin of Bohai Bay. On the basis of the fine description of the reservoir, the newly developed horizontal well technique is generalized and applied with the application scale speedily extending and satisfactory achievements. A series of techniques suitable for the features of the reservoir are formed, including adaptable evaluation of horizontal wells, scheme deployment, design, drilling, well logging, borehole log, oil production and production management etc. The utilization of the complete techniques ensures the result of the horizontal well development technique in Jidong Oilfield and paves the way for its further advancement. The workability of the method is proved by the reservoir with multi-reservoir, small fault-block, bedded edge-bottom waterflood in Gao 63 fault block of the south area in the shallow formation in Gaoshangpu Oilfield, the highly effective development of the difficult-to-produce reserves in Ng8 subzone of the reservoir in the north area, and the practice of improving the development efficiency in maturing oilfields by the slim-hole sidetracking horizontal well.
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  A segmentally numerical calculation method for estimating the productivity of perforated horizontal wells

  WANG Ruihe; ZHANG Yuzhe; BU Yuhuan; LIU Jilin and ZHANG Rui

  , 2006, 33(5): 1393-0.

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  Owing to the non-uniform inflow profile, it was difficult to estimate the productivity of horizontal wells accurately by traditional analytical equations or calculation methods with constant production index. The well is partitioned into many segments on the assumption of homogeneous formation. The whole three-dimension flow is divided into three parts using the pseudo-three-dimension method: flow from infinite boundary into a vertical fracture, radical flow around the well bore, and convergent flow through perforations. Taking the influence of formation damage into account, a correlation equation between reservoir flow rate and pressure difference is obtained for each segment. According to the influence of perforation inflow on the main flow, the pressure drop along the horizontal well is attributed to friction and acceleration losses. A general pressure-drop expression is established based on the principles of conservations of mass and momentum. The resulting models, coupled together, are validated by the close match between numerical calculation results and field data. The calculation results also show that the perforation-influx rate increases gradually from the toe to the heel of the horizontal well bore.
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  A 3-D analytical model and interpretation method of pressure decline for acid fracturing well

  REN Yong; GUO Jianchun; ZHAO Jinzhou and YE Dengsheng

  , 2006, 33(5): 1394-0.

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  With the rapid development of hydraulic fracturing, more and more attention has been paid to the techniques of fracture diagnosing and evaluating after fracturing. There are still few studies about fracture diagnosing and evaluating for acid fracturing well. The pressure decline analysis method for acid fracturing well is a kind of "curve fitting" method whose main idea is simulating the physical and chemical changes before and after pump off, and whose main line is the material balance equation. The models consider the influence of temperature and the compressibility of fluids (residual acid and CO2). They can effectively simulate the pressure decline after pump off, in turn, interpret the acid fracture geometry, closure pressure, acid loss coefficient, etc, and provide dependable techniques for evaluating acid fracturing as well as optimizing the reservoir stimulation.
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  Techniques for oil increasing of extra-low permeability Triassic Yanchang Formation, Ansai Oilfield, Northern Shaanxi

  LI Yongtai and SONG Xiaofeng

  , 2006, 33(5): 1395-0.

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  The geology of Triassic Yanchang Formation in Ansai Oilfield is extra-low permeability(0.96～2.90mD), extra-low porosity(11.00%～13.25%), fractured oil reservoir with dominant small pores and throats, little differences between formation and saturation pressure(2.94～3.66MPa), high percentage of acid-sensitive minerals in cements(6.19%), and high formation water salinity(89 850mg/L). Severe scaling problems and production reductions appear in water flooding production wells. Fracturing treatments were performed in 16 production wells leading to an average increase of 1.85t/d per well in oil production, the average effective life was 84.1d; foam flushing was operated in 10 production wells, leading to an average increase of 1.13t/d per well, the average effective life was 52.8d; acidizing treatments in 99 production wells led to an average increase of 1.10t/d per well, the average effective life was 128.9d; scale control and removal treatments in 18 production wells led to an average increase of 1.90t/d per well, the average effective life was 330d. The better result of the scale control and removal treatment is mainly attributed to its larger radius. Enhancing the radius in fracturing and acidizing treatments can further improve their performance.
国际交流与合作
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  Petroleum geological characteristics and exploration potential analysis of Maranon Basin, Peru

  WANG Qing; ZHANG Yinghong; ZHAO Xinjun; ZHU Enyong; YANG Ruicai; NONG Gong and LIU Yu

  , 2006, 33(5): 1396-0.

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  Maranon Basin is one of Sub-Andean foreland basins. With the basin's exploration history and current situation, drilling, seismic and geochemical data are analyzed to evaluate the petroleum geological factors and exploration potential. There are two sets of source rocks, Triassic-Jurassic Pucara and Cretaceous Chonta Formations. They began to be mature and expel hydrocarbons in the late Jurassic and Eocene. Hydrocarbons from the Pucara formation moved through unconformity towards Cretaceous formations, and re-accumulated after the Quechua tectonic movement. Hydrocarbons expelled from the Chonta Formation migrated toward the Northeast of the basin. Anticlinal, faulted and stratigraphic traps are commonly found in the basin. Three exploration targets exist in the basin: thrustfold-foredeep belt as well as Cretaceous reservoir without the background of hydrocarbon accumulation in Paleozoic; carbonate reservoir in the Pucara Formation; reservoir below the Chonta Formation.