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    01 April 2020, Volume 41 Issue 2 Previous Issue    Next Issue
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    OIL AND GAS EXPLORATION
    Genesis of Dolomitization of Permian Maokou Formation in Langzhong Area, Northeastern Sichuan Basin
    LI Rong, HU Hao, SHI Guoshan, XI Chengwei
    2020, 41 (2):  127-132.  doi: 10.7657/XJPG20200201
    Abstract ( 372 )   HTML ( 24 )   PDF (17959KB) ( 164 )   Save

    As an important oil and gas reservoir in Langzhong area of northeastern Sichuan basin, the second member of Permian Maokou formation is primarily composed of dolomite. There is no general understanding on dolomite genesis due to limited research literatures. Based on thin section authentication, cathodoluminescence analysis, quantitative analysis on inclusions and isotopes of carbon, oxygen and strontium, and combined with regional geological setting, the paper studies the petrologic and geochemical features of the dolomite in the second member of Maokou formation in Langzhong area, and discusses the genesis and significance of the dolomite. The results show that the dolomite in the study area is dominated by fine-medium crystalline, automorphic-semi-automorphic dolomite with relatively flat surface, which indicates the temperature of diagenetic environment was not high. The fine-medium crystalline dolomite in the study area is characterized by dark cathodoluminescence, low positive value of δ 13C and high negative value of δ 18O, 87Sr/ 86Sr slightly higher than that of the seawater of the same period, indicating a shallow burial and unobvious influences of high-temperature fluid. The fluid in the dolomitized rocks came from the seawater of the shallow-burial period, took grain-limestone as a carrier and then laminar and layered dolomite formed. Large scale reservoir spaces formed due to the dolomitization in the shallow-burial period, which is one of the most important diagenetic modes of carbonate reservoirs.

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    Differences Between Weathering Crust Reservoirs in Magmatic Rocks and Metamorphic Rocks: A Case Study of Bedrock Reservoirs in the Eastern Segment of Altun Piedmont Area
    LI Xin, XIE Qingbin, NIU Huapeng, ZHANG Yongshu, LI Chuanlong, SONG Shuyu, WU Zhixiong
    2020, 41 (2):  133-146.  doi: 10.7657/XJPG20200202
    Abstract ( 561 )   HTML ( 15 )   PDF (11088KB) ( 141 )   Save

    The bedrock weathering crust reservoirs in the eastern segment of the Altun piedmont area are dominated by magmatic weathering crust and metamorphic weathering crust. In order to understand the differences between the two kinds of weathering crust reservoirs, the weathering crust structures of the bedrock are identified through core observation, conventional logging curves and FMI image logging. The weathering crust structures in typical wells are classified and well-tie sections are mapped. Based on core observation, thin section identification, scanning electron microscopy, elemental energy spectrum logging, conventional logging, constant element testing and helium porosity-air permeability testing data, the differences in mineral composition, geochemical response, conventional logging, reservoir spaces and characteristics between the two kinds of weathering crust reservoirs are summarized, and the development model of weathering crust reservoirs of magmatic and metamorphic rocks are established. The results show that the weathering crust of bedrock can be divided into four layers according to its weathering degree, namely soil layer, full-weathered layer, semi-weathered layer and unweathered layer, and the semi-weather layer is further divided into dissolved zone and disintegrated zone. There is little difference in the vertical distribution of magmatic minerals. The contents of mafic minerals and clay in the metamorphic rocks from shallow to deep decrease as a whole. It can be discovered from SiO2/Al2O3 that the bedrock in the study area is mostly in semi-weathering state, the SiO2/Al2O3 of granite ranges from 5.13 to 6.50 and that of the metamorphic rock is 3.01-6.53. In the magmatic rock, the reservoir space of the dissolved zone in the semi-weathered layer is fractured-vuggy type, and the reservoir space of the disintegrated zone in the semi-weathered layer is fractured type; in the metamorphic rock, the reservoir space of dissolution zone in the semi-weathered layer belongs to vuggy type, and that of the disintegrated zone of semi-weathered layer is vuggy-fractured type. The porosities of the dissolved zones of the semi-weathered layer in the metamorphic rock and magmatic rock are 0.413%-8.509% and 0.926%-7.152%, respectively; the porosities of the disintegrated zones of the semi-weathered layers in the metamorphic rock and magmatic rock are 1.367%-5.211% and 1.429%-8.572%, respectively. In the magmatic rock and metamorphic rock, the correlation between porosity and permeability of the disintegrated zones in the semi-weathered layers are better than that of the dissolved zones in the semi-weathered layers. The dissolved zone of the semi-weathered layer in the metamorphic rock is the most important reservoir of the weathered crust, and is also the key factor for stable oil production, followed by the disintegrated zone of the semi-weathered layer. The disintegrated zone of the semi-weathered layer is the most important reservoir of weathered crust reservoir in the magmatic rock, followed by the dissolved zone of the semi-weathered layer. The reservoir performance of the metamorphic weathering crust reservoir is better than that of magmatic weathering crust reservoir.

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    Quantitative Characterization of Reservoir Architecture of Meandering-River Deposits in Sparse Well Blocks: A Case Study of Chunguang Oilfield, Junggar Basin
    FAN Xiaoyi, XUE Guoqin, LIU Bin, YUE Xinxin, XIE Qi
    2020, 41 (2):  147-157.  doi: 10.7657/XJPG20200203
    Abstract ( 397 )   HTML ( 15 )   PDF (6555KB) ( 357 )   Save

    The sandstones from the Neogene Shawan formation in Chunguang oilfield were deposited in a meandering-river environment. Due to the frequent migration of the ancient river channel, the sandstones are characterized by rapid pinchout and complex vertical stacking, and the internal architecture characterization of the sandstones becomes a problem to be solved. But small well density brings difficulties to the characterization. Based on the analyses of stratigraphic slice, seismic and logging data and combined with the modern sedimentary characteristics, this paper conducts a detailed hierarchical anatomy of the meandering-river reservoir in Shawan formation. The research results show that abandoned river channel deposition, channel elevation difference and interchannel fine deposition can be taken as the typical markers to distinguish single channel boundary. There are 8 point bars developed in the study area, point bar sandbodies show a multi-stage lateral stacking vertically, and mudstone are developed in lateral accretion layers. The scale, trending, dip angle and horizontal spacing can be characterized through quantitative analysis of modern fluvial deposits. Large-scale composite point bars resulted from river channel migration and stacking formed in the study area. The understandings provide theoretical basis for further potential tapping of remaining oil in the single sandbodies at the late oilfield development stage, and enrich the studies on the quantitative characterization of reservoir architecture and single sandbody in the areas with small well density.

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    Study on Reservoir Physical Properties of Oil Shale During Heating in Minhe Basin
    ZHAO Kang’an, SUN Pingchang, YU Fengning, LIU Rong, ZHANG Daoyong
    2020, 41 (2):  158-163.  doi: 10.7657/XJPG20200204
    Abstract ( 284 )   HTML ( 5 )   PDF (2896KB) ( 295 )   Save

    In order to study the influences of heated hydrocarbon expulsion process on reservoir physical properties of oil shale, selecting the immature oil shale in Minhe basin as the research object, reservoir physical properties of the oil shale samples in different heating stages are analyzed by means of 3D scanning observation of cracks, high-pressure mercury intrusion experiment, low temperature nitrogen adsorption and X-ray diffraction analysis after low temperature carbonization, and the evolution of oil shale reservoir physical properties during heating are further revealed. The results show that in the stage of low temperature heating (185-350 ℃), small amount of hydrocarbon is expulsed from the oil shale and the production rates of oil-water and semicoke change a little; in the stage of medium temperature heating (350-475 ℃), large amount of hydrocarbon is expulsed from the oil shale, the production rates of oil-water and semicoke significantly rise; in the stage of high temperature heating (475-520 ℃), residual hydrocarbon is expulsed and the production rates of oil-water and semicoke remain the same. During the heating process of the oil shale, as the temperature rises, the amount of cracks increases, micro-cracks widen and extend and then large fractures are formed. The fractures are mainly developed at the bedding surface and there are no obvious fractures on vertical bedding surface. The specific surface area of the oil shale gradually increases, micro pores become large pores. With the expulsion of hydrocarbon, partial large pores connect with each other and micro fractures are formed. The adsorption of the semicoke in the oil shale increases with the rise of relative pressure and temperature and the clay content decreases. The smectite in the illite/smectite formation gradually transforms into illite, the grain sizes of minerals desease, leading to the forming of micro fractures in mudstone and finally the porosity and permeability of mudstone increase.

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    Prediction of Reef Reservoir in Changxing Formation of Damaoping Area, Eastern Sichuan Basin
    DING Chuanqi, ZHOU Lu, ZHONG Kexiu, WU Yong, ZHONG Feiyan, LIU Yi
    2020, 41 (2):  164-171.  doi: 10.7657/XJPG20200205
    Abstract ( 313 )   HTML ( 5 )   PDF (5209KB) ( 535 )   Save

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

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    Diagenetic Evolution of the Ordovician Ma51+2 Sub-Member Reservoir in the Southern Jingbian Gasfield, Ordos Basin
    LI Zhaoxu, QIN Qirong, TIAN Guoqing, SUN Jinghu, CUI Han, ZOU Kaizhen
    2020, 41 (2):  172-179.  doi: 10.7657/XJPG20200206
    Abstract ( 331 )   HTML ( 6 )   PDF (4184KB) ( 341 )   Save

    The Ordovician Ma51+2 sub-member in Ordos basin is known to be rich in natural gas resources, which is the key target for oil and gas exploration in Ordovician formation in Jingbian gasfield. Based on the data of core, thin section and reservoir physical property, this paper analyzes and summarizes the diagenesis as well as porosity evolution of Ordovician Ma51+2 submember reservoir in the southern Jingbian gasfield. A series of restricted-evaporative platform dolomite reservoir is developed in the Ordovician Ma51+2 sub-member of the southern Jingbian gasfield, which is a low porosity, low permeability reservoir of micro-fracture-pore type with the main reservoir space dominated by gypsum dissolved pores and dissolved fractures. The reservoir has experienced multiple stages of diagenesis including dolomitization, compaction and pressure dissolution, cementing-filling, epigenic karstification, metasomatism and tectonic fracturing. Among them, the syngenetic-penecontemporaneous dolomitization and gypsum precipitation in high salinity seawater provided favorable conditions for epigenic karstification and fracture formation during Caledonian Movement, which were the basis of reservoir formation. During the supergene period, gypsum nodules were dissolved and micro-fractures were enlarged by meteoric freshwater, thus the reservoir properties were significantly improved. During the burial diagenesis period, the cementing-filling of quartz and calcite caused the reduction of pores, displaying a destructive diagenesis. Additionally, the tectonic activities at the late diagenesis period resulted in some open micro-fractures, which improved local reservoir properties, and finally the dolomite reservoir was formed with the reservoir spaces dominated by gypsum dissolved pores and dissolved fractures, and with the micro(dissolved) fractures as the main filtration channels.

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    RESERVOIR ENGINEERING
    High-Resolution Numerical Simulation for Gas Injection Gravity Drainage in Buried-Hill Reservoirs
    WANG Ruisi, ZENG Qingqiao, HUANG Pu, LIAN Liming, LI Junjie, CHENG Peng
    2020, 41 (2):  180-187.  doi: 10.7657/XJPG20200207
    Abstract ( 346 )   HTML ( 11 )   PDF (5447KB) ( 427 )   Save

    The buried-hill reservoir in the Wumishan formation of Yanling oilfield is a massive carbonate reservoir with bottom water, in which field tests of nitrogen injection had been carried out in the past and a 44 m-high oil column was formed. At present, the reservoir has entered the late development stage of high water cut and high recovery factor, and the development mode needs to be changed. Based on the data of laboratory experiments, early nitrogen injection field tests and well logging interpretation, the paper optimizes the geological model and establishes a high-performance cloud computing platform for numerical simulation. The simulation model for dual porosity buried-hill reservoirs is optimized, a high-resolution numerical simulation is carried out based on the model with grid precision of 60 m×60 m×3 m and the total grid number of 97×10 4, and a gas injection gravity drainage plan has been made for the buried-hill reservoir in Yanling oilfield. It is predicted in the plan that the recovery factor will be improved by 11.8%, the ultimate recovery factor will reach 43.4% and good results will be obtained, which can provide references for the development of similar reservoirs.

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    Monitoring and Description Methods of Fire Flooding Combustion Front in Hongqian Area, Karamay Oilfield
    GAO Chengguo, null null, ZHAN Hongyang, WANG Yong, YANG Fengxiang, YUAN Shibao
    2020, 41 (2):  188-192.  doi: 10.7657/XJPG20200208
    Abstract ( 330 )   HTML ( 8 )   PDF (537KB) ( 328 )   Save

    The position of combustion front is the focus of fire flooding research, and it is also the guarantee of the correct understanding about fire flooding sweep status. In Hongqian fire flooding pilot test area of Xinjiang, thermometric well method, electromagnetic method and numerical simulation method are used to monitor the position of combustion front, but these methods can’t fully meet the requirement of fast and accurate determination of the combustion front in the oilfield. Based on the laboratory experiment and in-situ test of dry fire flooding, a linear relationship between the acid value of crude oil and advancing distance of combustion front is established, and then the position of combustion front is calculated with the relationship. The synchronous change of the pressures in two adjacent gas injection wells in fire flooding field reflects an important characteristic of the interconnection of the two combustion chambers. Based on the variations of crude oil acid value and pressure, the crude oil acid value-pressure method for combustion front description is established. The combustion front positions at different times are described by using the acid value-pressure method according to the acid value and injection pressure obtained from the Hongqian fire flooding pilot test area in Xinjiang. By the end of 2016, the combustion front in the up-dipping direction had reached the producers, that in the down-dipping direction had gone beyond the producers, and most combustion chambers had been connected. Finally, the results of fire line description are verified by electromagnetic method and thermometric well method. It is concluded that the calculation of the combustion front position with the acid value-pressure method is reliable, which can accurately reflect the advancement of the combustion front.

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    Stress Simulation of Vetical Hydraulic Fracture Propatation Mechanism in Tight Conglomorate Reseriors of Mahu Area
    WANG Shuo, QIN Jianhua, YANG Xinping, LI Xiaoshan, ZHANG Yi, WANG Yingwei
    2020, 41 (2):  193-198.  doi: 10.7657/XJPG20200209
    Abstract ( 428 )   HTML ( 11 )   PDF (4103KB) ( 535 )   Save

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

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    Combustion State and Burning Front Prediction During Combustion Assisted Gravity Drainage Process in Horizonal Wells
    PENG Xiaoqiang, HAN Xiaoqiang, YANG Yang, ZHANG Jizhou, XU Jingrun
    2020, 41 (2):  199-203.  doi: 10.7657/XJPG20200210
    Abstract ( 233 )   HTML ( 5 )   PDF (684KB) ( 340 )   Save

    Accurate prediction of combustion state and burning front in super-heavy oil horizontal wells during combustion assisted gravity drainage process is beneficial to the timely regulation and control of field test. Physical simulation experiments have been carried out with a self-developed 3D physical simulation model for fire flooding. Combining with the production data, the paper calculates the volume of combustion chamber to predict the combustion front in horizontal wells during combustion assisted gravity drainage process, and characterizes the combustion states of oil zone by using parameters such as gas components, temperature and pressure during production. The results show that temperature is a parameter which can directly reflect combustion state; under the steady combustion state there is an angle about 30° between the combustion chamber and the extension direction of the horizontal section in horizontal wells, showing an overlapping combustion feature; coking zone and oil bank form in the upper end of the horizontal well, which can prevent fire from advancing into the horizontal well. In the steady combustion stage during the combustion assisted gravity drainage process, the content of CO2 in the produced gases is higher than 10%, the content of O2 is lower than 3%, the temperature of the horizontal section is lower than 300 ℃ and the pressure differential of oil wall is lower than the half of the production pressure differential. Gas channeling will occur during fire flooding when the above conditions can not be reached.

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    Microscopic Characteristics of Oil Displacement With Different CO2 Injection Modes in Extra-Low Permeability Reservoirs
    QIAN Kun, YANG Shenglai, DOU Hong’en, ZHANG Jichang
    2020, 41 (2):  204-208.  doi: 10.7657/XJPG20200211
    Abstract ( 410 )   HTML ( 8 )   PDF (561KB) ( 477 )   Save

    In order to investigate the microscopic characteristics of oil displacement and the lower limit of the pore diameter of CO2 injection with different injection modes in extra-low permeability reservoirs, NMR technology is used to analyze the microscopic residual oil distributions in cores for different injection modes such as continuous CO2 flooding, CO2 flooding after waterflooding and alternative water-gas flooding. The experiment results show that relatively good oil displacement effects of CO2 flooding after waterflooding and alternative water-gas flooding have been gained. Continuous CO2 flooding can displace oil in smaller pores, CO2 flooding after waterflooding can displace oil in small pores and micropores(pore size less than 0.5 μm)which can’t be recovered by water flooding, and good effects of alternative water-gas flooding can be gained in medium pores (0.5-5.0 μm). For the cores with different pore structures, the stronger the heterogeneity of the reservoir is and the more the small pores account for, the higher the lower limit of pore diameter in different injection modes will be. As a whole, good oil displacement effects can be gained by applying alternative water-gas flooding in Chang-8 reservoir of Huang-3 block in Changqing oilfield.

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    Adaptability of Combined Well Pattern to Sedimentary Facies Model in Thin Interbedded, Extra-Low Permeability Reservoirs
    ZHANG Min, WANG Wendong, GAO Hui, SU Yuliang, ZHAN Shiyuan
    2020, 41 (2):  209-216.  doi: 10.7657/XJPG20200212
    Abstract ( 315 )   HTML ( 6 )   PDF (1672KB) ( 358 )   Save

    The thin interbedded, extra-low permeability reservoir is characterized by small thickness and poor physical properties and the application of a combined well pattern of vertical and horizontal wells can improve single well productivity and reservoir producing degree. But due to the impacts of reservoir heterogeneity and hydraulic fractures, it is very easy for water breakthrough in horizontal wells, which will result in serious watered out and bring risks to oilfield development. Therefore, a reasonable adaptability of well pattern and fracture should be designed to elongate the production life of horizontal wells. Taking a typical thin interbedded, extra-low permeability reservoir in Daqing oilfield as an example, the paper establishes a fine reservoir numerical model for the combined well pattern of vertical and horizontal wells, which considers different sedimentary facies assemblages. The paper also studies the staged producing status of the fractured horizontal well and reveals the staged production rule and flowing characteristics in single fracture. Because the physical properties of the reservoirs of different sedimentary models are greatly different, the rise of the water cut in the fractured horizontal well doesn’t follow the rules of uniform displacement. The displacement in the channel facies with relatively good physical properties is enhanced while weakened in the sheet sands with relatively poor physical properties. Meanwhile, the hydraulic fracture will lead to the change of streamline direction and speed up the formation of high-permeable paths. In order to delay the formation of the high-permeable paths, the paper further studies the optimum configuration of typical sedimentary facies model and fracture parameters and proposes some suggestions to improve development effect.

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    Characteristics of In-Situ Stress Field in Heterogeneous Ultra-Heavy Oil Reservoir of Fengcheng Oilfield
    WU Han, LIN Botao, PAN Jingjun, CHEN Sen
    2020, 41 (2):  217-222.  doi: 10.7657/XJPG20200213
    Abstract ( 331 )   HTML ( 7 )   PDF (604KB) ( 262 )   Save

    The heterogeneous ultra-heavy oil reservoir in the Fengcheng oilfield is characterized by shallow-burial, strong heterogeneity and developed interlayers, which are the main obstacles for the steam chamber development during SAGD. In order to form flowing channels by hydraulic fracturing, the paper analyzes sedimentary characteristics, in-situ stress field distribution and the influences of interlayers on in-situ stress field and establishes a 3D stress field model for the reservoir with the burial depth of 282~332 m based on the results of rock mechanics experiment, logging data interpretation and stress test. The comparison of the simulation results with mini-fracturing test shows that the established 3D stress field model accords with the actual lateral formation pressure coefficient and the ratio of the max. horizontal principal stress to vertical principal stress, which can better reflect the features of lithology interfaces and stresses in the reservoir. The ultra-heavy oil reservoir is dominated by vertical principal stress which is in favor of guiding vertical fractures. The sudden stress changes at lithology interfaces result in the min. horizontal principle stress of sandstone being lower than that of mudstone interlayer. The mudstone interlayer has relatively high breakdown pressure, Young modulus and min. horizontal principle stress, and the fracture propagation capacity of the mudstone interlayer is lower than that of oil sand interval. The positions within interlayers or below interlayers should be selected for perforation during fracturing design, by which fracture height can be controlled, sand plugging can be avoided and reservoir seepage can be improved.

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    APPLICATION OF TECHNOLOGY
    Analysis on Pseudo-Fault in Fault Shadow During Seismic Interpretation: A Case Study of Aogula Fault in Northern Songliao Basin
    LI Cao
    2020, 41 (2):  223-227.  doi: 10.7657/XJPG20200214
    Abstract ( 382 )   HTML ( 7 )   PDF (4329KB) ( 397 )   Save

    The ascertain of Aogula fault and its nearby structures has important significance in exploration and development of Qijiagulong sag in the northern Songliao basin. During the seismic interpretation of the footwall of Aogula fault, from 4 aspects like regional structure, logging curve comparison, structural interpretation of dense well pattern and seismic forward modeling, it is proved that a previously interpreted near-upright fault is a pseudo-fault due to the inaccurate structural imaging and the existence of fault shadow. It is concluded that all or partial low-velocity intervals are broken in local areas and the interval velocities of the strata located on both sides of the fault abruptly change laterally, resulting in an inaccurate fault shadow in the footwall of the fault, both of which can be attributed to a large fault-throw normal fault passing through the low-velocity interval of the Lower Cretaceous Nenjiang formation in the northern Songliao basin. The paper proposes that the pre-stack depth migration technology based on high-precision velocity modeling can improve the phenomenon of the fault shadow. Regarding the seismic data in conventional time domain, structural interpretation can be carried out by using seismic forwarding modeling results and logging-seismic integration. The identification of the pseudo-fault in the fault shadow provides technical support for well allocation in Aogula oilfield.

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    Application of Intercalative Gel-Particle Profile Control Technology in Hade Oilfield
    TAN Liangbo, CHANG Lunjie, CHEN Hong, YANG Zhizhao, HE Xianghui, LIU Yishi, LI Hongbo
    2020, 41 (2):  228-231.  doi: 10.7657/XJPG20200215
    Abstract ( 255 )   HTML ( 4 )   PDF (999KB) ( 232 )   Save

    In order to improve the water flooding effect in high-temperature high-salinity reservoirs in the Hade oilfield, a research on the intercalative gel-particle profile control technology was performed. The performance evaluation and field application of the technology were carried out based on compatibility experiments, temperature resistance and salt tolerance tests and core flooding experiments. The results indicated that the intercalative gel particles, which could be uniformly dispersed in the solution and had a good compatibility with formation water. Under the condition of formation water in the Hade oilfield, the water absorption expansion rate became 5.00 times larger after the intercalative gel particles were aged for 30 days, indicating that the system had better performance in temperature resistance, salt tolerance and imbibition. In the process of injecting intercalative gel particles with different particle sizes into the cores with similar permeabilities, the maximum blocking rate reached 99.79%, indicating that the intercalative gel particles had good blocking performance. The intercalative gel particles were applied in the deep profile control in the Donghetang sandstone reservoir of Hade oilfield. By the end of October, 2018, the average daily oil production of the well groups with deep profile control increased from 104.07 t to 121.52 t, the water cut decreased from 83.95% to 74.40%, and the cumulative incremental oil production was 1.7×10 4 t. Good development effects have been gained.

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    A Method and Application of Horizontal Well Segmentation in Heavy Oil Reservoirs With Bottom Water
    SHI Hongfu
    2020, 41 (2):  232-236.  doi: 10.7657/XJPG20200216
    Abstract ( 294 )   HTML ( 15 )   PDF (485KB) ( 246 )   Save

    Segmented well completion technology can cope with the problems of early water breakthrough and liquid profile modification in horizontal wells. The paper establishes a set of methods of segmented well completion and optimized production allocation in horizontal wells in the reservoirs with bottom water by using flowing mechanics theory, reservoir engineering method, clustering analysis method and reservoir numerical simulation. Firstly, based on the comprehensive consideration of reservoir heterogeneity, pressure system, water avoidance height and well completion cost, a horizontal well is reasonably segmented by using clustering analysis method. Then the optimum additional resistance is calculated on the basis of a seepage-pipe coupling model and the principle of balanced liquid production in each segment. Finally, reservoir numerical simulation is used to compare the results of segmented well completion and conventional open-hole completion to verify the reliability of the method. The actual applications of the method in Caofeidian oilfields and Qinhuangdao 32-6 oilfield show that the average water breakthrough time is delayed by 152 days and the recovery factor can be improved by 3%-5%.

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    Identification of Low-Resistivity Oil Layers Based on Clay Mineral Analysis
    FENG Yuan, QIN Kang, LI Erdang, ZHANG Renyan
    2020, 41 (2):  237-242.  doi: 10.7657/XJPG20200217
    Abstract ( 389 )   HTML ( 13 )   PDF (1553KB) ( 299 )   Save

    There are distinct differences between the resistivity of Chang 81 reservoir of the western and eastern blocks in Zhenbei Oilfield, Ordos basin. The reservoir resistivity in the western block is significantly lower than that of the eastern block of Zhenbei oilfield and there are low resistivity oil layers in local areas. As a result, it is hard to identify oil and water layers in the western block, which brings difficulties for oilfield development. Based on the data of cast thin section, X-ray diffraction, SEM, mercury injection and logging interpretation, the characteristics of clay minerals and their effects on the resistivity of Chang 81 oil reservoir in Zhenbei oilfield are studied in this paper. The results show that the controls of clay minerals on low-resistivity oil layer in western Zhenbei oilfield are mainly manifested in three aspects. The first is the additional conductivity of clay minerals—the contents of illite and chlorite with relatively strong cation exchange capacity are high in the reservoir of the western block, leading to stronger additional conductivity. The second is the adsorption of water molecules to clay minerals—the content of chlorite with strong adsorption capacity is high, so it is easy to form water film and increase electric conductivity. Thirdly, the relatively high contents of clay minerals make the pore structures of the reservoir more complicated, which increases irreducible water saturation. For this kind of low-resistivity oil layers with high clay mineral content, a model is established to calculate the clay mineral content in reservoir through analyzing the response characteristics of logging curves. Combining with production status, the water productivity of low-resistivity oil layer is eventually matched and finally the identification accuracy of low-resistivity oil layer is improved.

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    An Improved Growth Curve for Predicting Development Indexes in Water Flooding Oilfield
    ZHOU Peng
    2020, 41 (2):  243-247.  doi: 10.7657/XJPG20200218
    Abstract ( 266 )   HTML ( 4 )   PDF (442KB) ( 331 )   Save

    The 3Y4 growth curve is a mathematical model for predicting production and recoverable reserves of oilfields, but its prediction accuracy is relatively low and the prediction effect is relatively poor. Based on this model and the relationship between oilfield development time and cumulative production, an improved growth curve for predicting oilfield production and recoverable reserves is proposed, which covers a variety of growth curves and has certain generality. The actual application results of the improved model show that the improved growth curve has better application effect in the prediction of oilfield development index with higher prediction accuracy and better applicability and practicability, and can be used to predict oilfield production, recoverable reserves and water cut. The introduction of the improved growth curve is an effective supplementary to the existing methods for development index prediction in water flooding oilfields.

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    A Method to Calculate Gas Injection Volume in Fault-Karst Carbonate Reservoirs of Tahe Oilfield
    ZHU Guiliang
    2020, 41 (2):  248-252.  doi: 10.7657/XJPG20200219
    Abstract ( 344 )   HTML ( 4 )   PDF (1603KB) ( 291 )   Save

    Good development effects of nitrogen injection EOR technology have been achieved in the fault-karst reservoirs of Tahe oilfield, but there is no method to determine the reasonable gas injection volume especially for the reservoirs in the oilfield. Based on the production data analysis method and the matching of flow reforming pressure and material balance time curve, the total producing reserves of gas drive well groups in fault-karst reservoirs of Tahe oilfield is obtained. Considering the well pattern characteristics in the fault-karst reservoirs of Tahe oilfield, a method to calculate the plane sweep efficiency of gas drive in the linear well pattern is obtained. Based on the 3D fracture-cave body distribution in the fault-karst reservoirs, a method for calculating the vertical producing degree of gas drive in the fault-karst reservoirs is developed. Based on numerical simulation of the typical fault-karst reservoir, the reasonable gas injection volume is determined to be 0.75 PV of the remaining reserves. Based on the obtained total producing reserves, cumulative oil production before gas injection, plane sweep efficiency, vertical producing degree and reasonable gas injection volume of the gas drive well groups in the fault-karst reservoirs, a method to calculate the reasonable gas injection volume is established for the fault-karst reservoirs of Tahe oilfield. The reasonable gas injection volume obtained from the calculation method has been applied in the gas drive of the fault-karst carbonate reservoirs in Tahe oilfield and the oil production of the response producers can reach 2.5 times the production before gas injection.

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