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    01 June 2019, Volume 40 Issue 3 Previous Issue    Next Issue
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    Densification Mechanism of Tight Reservoirs from Mixed Sedimentation in Saline Lacustrine EnvironmentA Case Study of Permian Lucaogou Formation, Jimsar sag
    MA Ke1, LIU Yuming1, HOU Jiagen1, HUANG Su2, YAN Lin3, CHEN Fuli3, YANG Wenze1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190301
    Abstract ( 152 )   PDF (300KB) ( 78 )   Save
    The tight oil in Permian Lucaogou formation of Jimsar sag is the important target for terrestrial unconventional oil and gas exploration in China. In order to describe and predict the difference in densification process of terrestrial tight reservoirs, and to define the development model of the sweet spots, the paper takes the tight reservoir of the Permian Lucaogou formation in Junggar basin as an example to analyze the interaction of diagenesis within the closed diagenetic system of the Lucaogou formation, reveals various reservoir densification paths and clarifies the development mechanism of sweet spot based on the data of thin section, SEM, physical property, stable carbon and oxygen isotopes analysis and fluid inclusion homogenization temperature. The research indicates that according to their diagenesis evolution paths,four densification types of the tight reservoirs in Lucaogou formation are summarized such as weak dissolution of carbonate rock, strong compaction of plastic debris, normal compaction and strong calcite cementation, and carbonate cementation + clay mineral cementation and superposition. Three forming mechanisms of sweet spots are classified including primary pore preservation of local overpressure and early chlorite protection, one period of strong dissolution and superposition of two-period dissolution. These three types of sweet spots are more likely formed in the dominant sedimentary microfacies with high terrigenous clastics content such as thick sandy beach bars and distal bars in deltas
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    A Study on Differentiated Oil-Bearing Controlling Factors and Distribution Patterns of Continental Tight Oil Reservoir
    YAN Lin1, YUAN Dawei1, CHEN Fuli1, GAO Yang2, WANG Shaojun1, CHENG Fucheng1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190302
    Abstract ( 105 )   PDF (300KB) ( 270 )   Save
    The oil-bearing properties of continental tight oil reservoir are characterized by decentralized distribution, wide range and big differences. Based on the comparative analysis on controlling factors of oil-bearing properties of source rocks, reservoir and the relation between source rock and reservoir, the paper reveals the distribution rules of Chang 7 tight oil in Ordos basin, Lucaogou tight oil in Junggar basin and Fuyu tight oil in Songliao basin. Using porosity and permeability measurement, core observation, logging interpretation and dynamic analysis, the paper identifies the general law of continental tight/shale oil that reservoir physical property is controlled by lithology and the oil-bearing property is controlled by reservoir physical property. The overlapped areas of prevailing microfacies and diagenetic facies are generally the enrichment areas of tight oil, based on which differentiated distribution patterns are established for the typical tight/shale oil in China. The study results can guide well deployment and horizontal well trajectory design and obvious effects have been gained
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    Influencing Factor Analysis and Comprehensive Evaluation Method of Lacustrine Shale Oil: Cases from Dongying and Zhanhua Sags
    Zhu Deshun
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190303
    Abstract ( 118 )   PDF (300KB) ( 176 )   Save
    A series of exploration wells targeted at shale oil have been deployed in Dongying sag and Zhanhua sag of Shengli oilfield since 2011. But the shale oil production rate can’t achieve the expected results, which indicates the understanding about the continental shale oil accumulation in Dongying and Zhanhua sags are not clear. Taking the shale oil wells in the 2 sags and combining mathematical statistics, well analysis and experimental simulation, the paper considers that the accumulation and production of the shale oil in the areas are mainly controlled by four factors such as lithofacies, fracture, mobility of shale oil and formation pressure. The boundary conditions of these factors favorable for shale oil enrichment are analyzed and a comprehensive evaluation method suitable for lacustrine shale oil evaluation is established based on single factor evaluation of lithofacies, fracture, mobility and formation pressure and multi?factor combined evaluation of shale oil sweet spot, which effectively improves the prediction accuracy for shale oil and forecasts the favorable area of sweet spot. The study shows good potential for shale oil exploration in Dongying sag and Zhanhua sag
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    Fracture Characteristics and Main Controlling Factors of Tight Reservoirs in Lucaogou Formation of Jimsar Sag, Junggar Basin
    ZHU Deyu, LUO Qun, JIANG Zhenxue, YANG Wei, LIU Dongdong, LUO Jingling
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190304
    Abstract ( 82 )   PDF (300KB) ( 207 )   Save
    The tight oil reservoirs of the Lucaogou formation are widely distributed in the Jimsar sag of Junggar basin, Northwest China. However, the effects of its exploration and development are unstable because the fracture development characteristics and main controlling factors on fractures are not verified. This study aims to clarify the basic characteristics of fractures and study the main controlling factors on fractures. Based on the data analysis of outcrop, core, rock thin section, SEM, image logging and X-ray diffraction, the paper studies the relationships of fractures with mineral brittleness, lithology, total organic carbon content, stratum thickness and sedimentary microfacies. The study results indicate that the development of the fractures in Lucaogou formation is positively correlated with mineral brittleness and TOC content, and negatively correlated with stratum thickness. The influence of sedimentary microfacies on fractures is complex because the factors of mineral brittleness, lithology, TOC content and stratum thickness should be comprehensively considered. Dolomitic sand flat and sand bar are the developed in the shore-lacustrine facies, while distal sand bar and sheet sand are developed in the delta facies, all these microfacies are favorable for fracture development
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    Quantitative Characterization of Pore Structure of Lucaogou Formation in Jimsar Sag
    LIU Yishan1, DONG Xiaohu1, YAN Lin2, CHEN Fuli2, GAO Yanling1, CHEN Zhangxing1,3
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190305
    Abstract ( 119 )   PDF (300KB) ( 237 )   Save
    The Lucaogou formation in the Jimsar sag is a typical shale oil reservoir, and the “sweet spot” of shale oil reservoir is the main target for oilfield development. The pore structure of the reservoir is the foundation of reservoir research. The pore characteristics of the reservoir of Lucaogou formation in the Jimsar sag are analyzed by using low temperature liquid nitrogen adsorption, high pressure mercury injection, scanning electron microscopy and nuclear magnetic resonance. The results show that the pore types of the Lucaogou formation are mainly nanopores and submicron pores. The diameter of the nanopores is mainly distributed in the range of 10~80 nm,and the submicron pore diameters are mainly distributed in the range of 0.1~0.3 μm. The four methods are compared and the advantages,disadvantages and priorities of the various methods are clearly explained
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    Meandering River Deposit and Sand Body Architecture in Qigu Formation of Jiangong Coal Mine Section in the Southern Margin of Junggar Basin
    GUAN Xutong1, WU Jian2, WEI Lingyun2, ZHAO Jinyong2, FENG Geng1, LI Yan1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190306
    Abstract ( 107 )   PDF (300KB) ( 58 )   Save
    Guided by the theories of sedimentary and architecture element analysis, the paper analyzed the architecture elements of the meandering river sand body in Upper Jurassic Qigu formation in the southern margin of Junggar basin, counted the scale and shapes of the architecture elements and sand bodies and classified the superimposition types. In this field outcrop, 7 lithofacies are found, boundaries with 6 levels are classified and 4 key architectural elements are identified. When the A/S is bigger than 1, the isolated channel sand bodies are developed. As the A/S decreases and approaches to 1, the bridging channel sand bodies and superimposed channel sand bodies are developed. When the A/S is smaller than 1, the truncated channel sand bodies are developed. During the deposition of Qigu formation, the climate was arid and hot. During the deposition of Toutunhe formation, the broad lake level dropped, a sandy meandering river formed with the depth of about 33.3 m, width of 139.2 m, bankfull width of 805.2 m and single meander belt width of 6405.2 m. In the early stage of the deposition of Qigu formation, the A/S was smaller than 1, corresponding to the development of isolated channel and flood lake sand bodies, in the middle stage, the bridging channel sand bodies, superimposed channel sand bodies and the truncated channel sand bodies were developed. In the late stage, the A/S increased again corresponding to the development of the isolated channel sand bodies
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    Architectural Element Analysis of Channel Sand Body in Sangonghe Formation on Tuositai Gully Section in the Southern Margin of Junggar Basin
    SHUANG Qi1, ZHANG Changmin1, ZHAO Kang1, Wang Bing2, WANG Xin2, DONG Yan2
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190307
    Abstract ( 124 )   PDF (300KB) ( 77 )   Save
    The braided river sand body is a kind of important oil and gas reservoir and its internal structural features have guiding effects on oil and gas exploration. Based on the braided river outcrop survey, lithofacies analysis and architectural element analysis of the Tuositai gully in the southern margin of Junggar basin, 6 types of lithofacies are summarized,and 5 levels of bounding interfaces are divided,and 5 types of 4-level architectural structural units are identified including stable flow channel, high flow regime channel, sand bar, abandoned channel filling and floodplain, which are characterized by the lithofacies assemblages of St-Spx-Sp-Sr, St-St-St, St-Spx-St-Sr, St-Sr-Fl and Sr-Fl-M, respectively. According to the characteristics of each structural unit and its bounding surface, 4 types of muddy interlayer such as mud in floodplain, interchannel mud, mud within sand bar and mud in cross-bedding layer are identified. The study results show that the target stratum is a typical sandy braided river deposit characterized by multiple periods and cycles with coarse grain in the lower and fine grain in the upper and gradually decreased flow energy. In the braided river sand body, the St and Sp lithofacies are the most stable, which are the basic elements of dominant reservoir units. The high flow channel and sand bar are favorable reservoir structural units. The sand bodies formed by these two types of structural units are featured with large thickness, good lateral continuity and weak heterogeneity, which are conducive to oil and gas accumulation and can be the most favorable intervals in braided river reservoirs
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    Time-Varying Sequence Analysis of Generalized Vogel Equation for Fracturing Wells in Fractured Volcanic Reservoirs
    WANG Liqiang1, CUI Yinghuai2, JING Wenbo2, FU Yonghong2, DONG Ming2, WANG Xuewu1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190308
    Abstract ( 67 )   PDF (300KB) ( 96 )   Save
    From the non-dimensional typical chart of bottom hole pressure during fracturing, combining with the generalized Vogel equation for fractured reservoirs, the article establishes a solving method of the inflow performance curves with different producing days in fractured reservoir fracturing wells. The reliability of the research results are verified by an example and the variations of the inflow performance curves with different producing days and different non-dimensional fracture conductivity are analyzed. The results show that when the non-dimensional fracture conductivity is large, the initial well production is high but the production decline is large and it is difficult to maintain the well production. Therefore, selecting a reasonable non-dimensional fracture conductivity value has practical significance for efficient development of fractured volcanic reservoirs
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    Experimental Investigation on the Influence of CO2-Brine-Rock Interaction on Tight Sandstone Properties and Fracture Propagation
    LI Sihai, MA Xinfang, ZHANG Shicheng, ZOU Yushi, LI Ning, ZHANG Zhaopeng, CAO Tong
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190309
    Abstract ( 132 )   PDF (300KB) ( 157 )   Save
    Based on the experiments of static tight sandstone soaked in CO2-saturated brine and indoor fracturing simulation, the influence of CO2-brine-rock interaction on tight sandstone properties and hydraulic fracture propagation were studied, and the special chemical effect of CO2 was simulated by soaking the open-hole section of fracturing sample in CO2-saturated brine. The study results show that after soaking in CO2-saturated brine, the contents of calcite and dolomite in the rock sample significantly decrease, kaolinite occurs after the corrosion of potassium feldspar and anorthose; the contents of quartz and clay minerals increase and those of illite and chlorite decrease; the amount of dissolved pores rises, the pore diameter, porosity and permeability become larger; the tensile strength of the tight sandstone decreases, and the decrement extent of the tensile strength in parallel bedding is larger than that in vertical bedding; compared with slickwater fracturing, the formation fracture pressure of supercritical CO2 fracturing reduces by 14.98% and the number of hydraulic fractures increases. After the openhole section soaking in CO2-saturated brine, the formation fracture pressure of supercritical CO2 fracturing decreases by 21.61% compared with that of supercritical CO2 fracturing without the soaking treatment and the fracture complexity is greatly enhanced. The experiment result proves that the physical and chemical properties of CO2 can effectively improve the fracture complexity during CO2 fracturing
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    Digital Core Reconstruction and Research on Microscale Flow Characteristics of Shale Oil Reservoir: A Case of the Shale Oil in Permian Lucaogou Formation, Jimsar Sag
    LI Jiaqi, CHEN Beibei, KONG Mingwei, LYU Bei, MENG Xue
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190310
    Abstract ( 115 )   PDF (300KB) ( 107 )   Save
    To make clear pore structures and flow characteristics of shale oil reservoir, taking the shale oil reservoir of Permian Lucaogou formation in Jimsar sag as the study object, the paper uses Micro-CT and FIB-SEM scanning technologies to establish a 3D digital core model and to obtain parameters of pore throat structures. Based on which a microscale physical simulation instrument for porous media is established to study the low-velocity flow laws of fluids in micro paths. Meanwhile, the physical simulation model is used to measure flow characteristics and damage degree of different fracturing fluids. The study results show that the pore structure of the shale oil reservoir is featured with strong heterogeneity and poor connectivity, the main reservoir space is dominated by nanoscale pores and the fluidity depends on the amount and sizes of the micron-scale pores; the low-velocity flow of fluid at micro scale is non-darcy flow with a threshold pressure gradient, and with the increase of driving differential pressure, the fluid in more pores will continue to flow; the residue of guar gel breaker and the aggregates of macromolecular structure are easy to block pores. It is suggested that less guar gel and more slick water should be used to reduce reservoir damage during shale oil reservoir fracturing
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    Key Geological Factors of High-Yield Coalbed Methane Development in Fukang Syncline
    GE Yanyan1, LI Xin1, GAO Lin2, JIAO Chunlin3, WANG Haichao1, FENG Shuo1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190311
    Abstract ( 76 )   PDF (300KB) ( 107 )   Save
    Based on the geological units divided by pervious researchers for coalbed methane development and combined with logging and production data obtained from coalbed methane wells, the paper studies the geological characteristics of high-yield coalbed methane wells in Fukang syncline. The results show that in the fourteen geological units divided in Fukang syncline, the fissure water between coal beds in the stagnant area mainly come from pore phreatic water in loose rock mass and the lateral supply of the aquifer in the same zone, coalbed methane may easily accumulate under the action of hydraulic sealing and plugging and the production in the stagnant area is higher than that in the runoff area; due to the influence of burial depth on reservoir vertical stress, the stagnant area with medium burial depth has relatively good permeability, whose production is higher than that of the deep-burial stagnant area; the dual lateral resistivity logs are used to judge the development degree of cracks in the coal beds, the reservoir with slight deformation in deep strata has good permeability, whose production is higher than that with serious deformation. It is considered that the combined development of coal-series conventional natural gas is helpful for the high yield of coalbed methane wells
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    Spontaneous Imbibition of Tight Oil Reservoirs Based on NMR Technology
    JU Mingshuang, WANG Xiuyu, YU Wenshuai, YANG Shenglai, YE Wenzhuo, ZHANG Tianqing
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190312
    Abstract ( 128 )   PDF (300KB) ( 345 )   Save
    China’s tight oil resources are rich in reserves and have huge economic value, but it is difficult to develop due to the features of low permeability and low porosity of tight oil reservoirs. The spontaneous imbibition principle based on capillary pressure becomes an effective production mechanism for such reservoirs. Combining with nuclear magnetic resonance(NMR) experiments, the paper clarifies the spontaneous imbibition flow law of fluids in tight core, studies the influences of core permeability, core length and one-way imbibition on the recovery percent of spontaneous imbibition based on T2 spectrum and imaging maps obtained from the nuclear magnetic experiment, and observes 2D fluid flowing and distribution in the core. The comparison result shows that the recovery percent of spontaneous imbibition obtained from T2 spectrum is consistent with that obtained from the mass method, which verifies the applicability using NMR experiments to study tight reservoir spontaneous imbibition and provides a reliable theoretical basis for tight oil development
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    Pressure Sensitivity Characteristics of Cretaceous Tight Fractured Reservoirs in Dabei Gas Field
    YI Yana, ZHANG Zekaib, CUI Xiaohub, LIAN Lingfengc, YANG Guoa, ZHANG Boa
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190313
    Abstract ( 83 )   PDF (300KB) ( 224 )   Save
    The reservoirs in Dabei gas field of Kuqa depression, Tarim basin are characterized by large buried depth, tight lithology, undeveloped matrix pores and developed fractures. The relevant experimental study shows that a strong pressure sensitivity is found in the reservoir of Dabei gas field, and once pressure sensitivity occurs in gas layers, fractures will be closed and permanent damages to reservoir physical property and a sharp decline in production will happen. A static pressure value for reservoir pressure sensitivity in Dabei gas field is determined through core pressure sensitivity test. Based on the obtained tectonic stress field of the gas reservoirs and combining with the actual formation pressure, the formation pressure leading to pressure sensitivity is determined for the gas reservoirs at different structural positions in Dabei gas field. During the production process of the gas field, before the gas reservoir pressure decreases to the pressure sensitivity threshold value, measures should be taken timely to avoid pressure sensitivity, maintain gas production and enhance gas recovery
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    Application of Chromatographic Fingerprint Technology in Determining Contribution Rate of Single-Layer Productivity in Commingled Production WellsA Case from Shale Oil of Permian Lucaogou Formation in Jimsar Sag
    LI Erting1, JIN Jun1, HOU Dujie2, LI Jiang3, MI Julei1, JIANG Yuhan2
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190315
    Abstract ( 129 )   PDF (300KB) ( 247 )   Save
    Based on the principle of chromatographic fingerprint and proportion tests, a chromatographic fingerprint map database for three single layers such as P2l2-12, P2l2-22 and P2l2-32 of the upper sweet spot shale oil in Jimsar sag is established. The partial least square method is used to realize the productivity contribution rate calculation and dynamic monitoring of the single layers during 2-layer and 3-layer commingled productions for shale oil in the upper sweet spot of Lucaogou formation in Jimsar sag. The result shows that P2l2-12 and P2l2-22 are the main contributors for shale oil production in the upper sweet spot of Lucaogou formation in Jimsar sag, among which P2l2-12 is the main contributor to the commingled production of P2l2-12 and P2l2-22 in Well Ji-37 and Well Ji-171; while P2l2-22 acts as the main contributor to the commingled production of P2l2-22 and P2l2-32 in Well Ji-25 and Well Ji-173. During the commingled production of P2l2-12+P2l2-22 +P2l2-32, P2l2-22 provides most hydrocarbons in Well Ji-31, P2l2-12 is the main contributor and P2l2-22 is the minor contributor in Well Ji-174 and Well Ji-176. Additionally, the tracking study shows that the productivity contribution rate of P2l2-12 gradually decreases in wells Ji-174 and Ji-176 and P2l2-22 becomes the major hydrocarbon provider. An analysis is performed by combining the calculation results with the corresponding reservoir physical properties and oil saturation of each well, which proves the accuracy and rationality of the calculation results
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    A New Method for Cluster Spacing Optimization During Volumetric Fracturing in Tight Sandstone Oil Reservoirs
    WANG Tianju1, CHEN Zan2, WANG Rui1, WU Chunfang3, XU Hongzhi1, HAO Zhiwei1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190315
    Abstract ( 0 )   PDF (300KB) ( 43 )   Save
    To increase the stimulated reservoir volume during volumetric fracturing in tight sandstone reservoirs, perforation cluster spacing of staged fracturing in horizontal wells needs to be optimized. The traditional method based on the induced stress analysis can’t be effectively combined with the actual pump program, and also can’t optimize the cluster spacing more precisely. A crack initiation model is established with ABAQUS software based on the finite element method. Taking the natural fracture opening criterion and critical cluster spacing for fracture reorientation as the optimization standards and combining with the actual pump program, a cluster spacing optimization method is developed by considering the coupling effect of induced stress and net fracture pressure. It is considered that under the effect of induce stress, there is a critical cluster spacing for fracture reorientation which can make the principle stress inverse between clusters, and the critical cluster spacing for fracture reorientation becomes larger with the increase of slurry rate. When the critical value is taken as the cluster spacing, the two principal stresses are close to each other, the main cracks link up with natural fractures and complex fractures form, which can be used as a standard to optimize the cluster spacing. Field application shows that with the optimized cluster spacing obtained from this method, the main cracks can connect with natural fractures, increase stimulated reservoir volume and improve the volumetric fracturing effect in tight sandstone reservoirs
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    A Well Test Analysis Method for Multi-Stage Fractured Horizontal Wells in Shale Oil Reservoirs
    CHEN Haoshu1, LIAO Xinwei1, GAO Jingshan2, CHEN Zhiming1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190316
    Abstract ( 131 )   PDF (300KB) ( 335 )   Save
    Multi-stage fracturing in horizontal well is a great way to improve the oil recovery of shale oil reservoir. Therefore, it is important to establish a reliable method for accurate fracturing parameter evaluation in multi-stage fractured horizontal wells. Based on the actual well test data and pressure derivative curves, a stimulated reservoir volume(SRV)model considering both the main and secondary fracture networks is established for multi-stage fractured horizontal wells in shale oil reservoirs, and the type curves of the bottom hole pressure difference and its derivative of the model are analyzed, which are mainly composed of six stages: wellbore storage effect stage, skin effect stage, bilinear flow stage of main and secondary fracture networks, linear flow stage in secondary fracture network, interporosity flow stage in fracturing treatment zone and pseudosteady-state flow stage. The sensitivity analysis of parameters shows that the larger the storage ratio, the smaller the sinking amplitude of the pressure difference derivative curve; the longer the fracture half-length, the longer the duration of the bilinear flow phase on the pressure derivative curve and the shorter the duration of the linear flow stage, and the pressure difference and its derivative curves of the pseudosteady-state flow stage are shifted downward. Based on this model, a well test analysis method for fracture evaluation of multi-stage fractured horizontal wells in shale reservoirs is proposed. The actual example shows that this model can effectively fit the actual well testing data. The actual production data and pressure coupling analysis verify the accuracy of the results. This method can be applied in fracturing parameter evaluation in other similar shale oil reservoirs
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    Influencing Factors and Optimization Methods of Drainage Parameters in CBM Wells
    PENG Zeyang, LI Xiangfang, SUN Zheng
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190317
    Abstract ( 142 )   PDF (300KB) ( 232 )   Save
    In order to further understand the factors affecting the production of coalbed methane(CBD) wells, the possible damage mechanisms in the production process of coalbed gas wells including reservoir stress sensitivity, near-bore zone damage, pulverized coal migration and pressure drop transmission are analyzed. Based on the principle of minimizing the above mechanism damages, the pressure drop rates in different stages of coalbed methane production are studied theoretically in this paper and then the optimization method of coal seam gas well drainage is put forward. The results show that in the early stage of CBM production, the appropriate increase of production rate will not cause serious stress sensitivity effect, and not only the drainage effect can be effectively improved, but the damage to near-bore areas can be decreased; in the middle-late CBM production stage, it is suggested that the occasional increase of pressure difference should be adopted to release the trapped gas and improve production. For the reservoirs producing pulverized coal easily, when the bottom pressure of the well is slightly greater than the critical desorption pressure, increasing pressure difference for rapid drainage can promote the expulsion of the produced pulverized coal and make the gas-water two phase flow area appear as soon as possible, and the aims to prevent the rapid water production from the far-end of the reservoir and to suppress the pulverized coal can be realized
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    Improvement and Application of Pressure Drop Analysis Method for Mini-Fracturing in Tight Reservoirs
    JING Jiyun1, GUO Bumin1, WANG Xingzun1, LI Xiaogang2
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190318
    Abstract ( 109 )   PDF (300KB) ( 195 )   Save
    Fracturing characteristics and physical parameters of reservoirs can be acquired by analyzing pressure drop curves during mini-fracturing. But there are some defects of the commonly used methods of pressure drop analysis due to its unreasonable G function expression, unquantified filtration coefficient under the condition of natural fissure opening and weak effectiveness of the method for reservoir physical parameter calculation. Therefore, the reasonable selection method of G function expression on the basis of calculating fracture extension index is given at first. Then the method to calculate filtration coefficient with open natural fissures is modified and a method to analyze linear pressure drop after the closure of fissures is proposed to obtain reservoir physical parameters rapidly. The actual application results can verify the applicability and reliability of the improved method in tight reservoir fracturing analysis
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    Application of Foam Acidizing and Plugging Removal Technology in Well Donghe 1-10H
    TAN Liangbo1, CHANG Lunjie1, SUN Yuguo1, ZHENG Miao2, CHENG Chunjie1, YANG Zhizhao1
    2019, 40 (3):  1-1.  doi: 10.7657/XJPG20190319
    Abstract ( 99 )   PDF (300KB) ( 238 )   Save
    The sandstone reservoir CⅢ in Well Donghe1-10H of Donghe oilfield is characterized by poor physical property, high water cut, long horizontal section and low pressure coefficient. During drilling and workover operations, contamination occurred to the reservoir because of the uneven acid distribution and incomplete flowback of residual acid in the reservoir when applying conventional acidification, resulting in the poor acidizing effect in oil zones. Based on which, the paper proposed a foam acidizing method to remove plugging and performed core foam diversion acidizing experiments. The results show that the foaming ability and stability of the foam acid are pretty good and the foam can effectively plug the aquifer; the difference of the diversion flow rates in the high-permeability core and low-permeability core decrease from 19 times before foam acid injection to 1.7 times after the experiment. The actual field application of foam acidizing and plugging removal technology in the wellsite of Donghe 1-10H indicates a good stimulation effect. The technology can effectively solve the reservoir contamination in Well Donghe 1-10H and provides technical support for the oil production of horizontal well in the oilfield
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