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    01 October 2021, Volume 42 Issue 5 Previous Issue    Next Issue
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    OIL AND GAS EXPLORATION
    Distribution of Natural Fractures and Mechanical Characteristics of Orogenic Movement in Carbonate Formations in Shunbei Oilfield
    CHEN Xiuping, SHEN Xinpu, LIU Jingtao, SHEN Guoxiao
    2021, 42 (5):  515-520.  doi: 10.7657/XJPG20210501
    Abstract ( 330 )   HTML ( 18 )   PDF (8992KB) ( 197 )   Save

    Natural fractures in the Ordovician carbonate formations in the Shun 8B block in Shunbei oilfield were investigated, and the classification and distribution laws of the natural fractures were summarized. Then through damage and finite element numerical simulation, a theoretical tool for simulating the damage to the carbonate formations was developed, and the displacement direction and strain of orogenic movement corresponding to the development of natural fractures were determined. The results are as follows: ① Based on the stratigraphic structure from seismic waves and the histories of sedimentation and orogenic movement in the study area, the natural fractures/faults in 7 sections in the Carboniferous Kalashayi formation to the Middle Ordovician Yijianfang formation are divided into 5 natural fracture systems; ② The natural fractures in the Upper Ordovician Qarbag formation to the Middle Ordovician Yijianfang formation correspond to the orogenic movement of the middle Caledonian PhaseⅠand the middle Caledonian PhaseⅡ, and they are mainly open fractures and strike-slip fractures/faults penetrating the formations; ③ Based on seismic horizons, a 3D finite element model was established and 3D damage finite element numerical analysis was carried out. Forward numerical calculation provided the 3D distribution of the natural fractures/faults represented by localized damage zones under the action of the middle Caledonian orogenic movement in the study area. Numerical calculation verified that the mechanics of the middle Caledonian orogenic movement extruded the Ordovician carbonate formation at the azimuth of 15°, and the extrusion degree of the formation is equivalent to 2.4% of the strain.

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    Genesis and Coupling Relationship of Fractures in Shale Reservoir of Lucaogou Formation in Jimsar Sag, Junggar Basin
    LIANG Chenggang, XIE Jianyong, CHEN Yiwei, LIU Juanli, HE Yongqing, ZHAO Jun, WANG Wei, WANG Liangzhe
    2021, 42 (5):  521-528.  doi: 10.7657/XJPG20210502
    Abstract ( 285 )   HTML ( 17 )   PDF (10928KB) ( 263 )   Save

    According to the data of outcrops, cores and thin sections of the shale reservoir of the Lucaogou formation in the Jimsar sag, Junggar basin, and considering the imaging logging data, physical simulation of oil and gas migration and triaxial rock fracturing experiment etc., we studied the genesis and coupling relationship of fractures in the shale reservoir in micro and macro scales based on the stress-strain curve. The results show that: (1) The mutual coupling of bedding fractures and structural fractures can greatly improve the physical properties of the shale reservoir; (2) Bedding fractures and structural fractures are influenced by each other during their devlopment. When the rock with bedding fractures is compressed in the direction vertical to the bedding plane, multi-stage fractures are likely to appear and form a fracture system with interlaced bedding fractures and structural fractures; when the rock is compressed in the direction parallel to the bedding plane, a fracture system with less stages may occur, which is mainly composed of bedding fractures; (3) The parallel coupling of structural fractures and bedding fractures has no significant impact on the permeability of the shale reservoir, while their vertical coupling can significantly increase the permeability of the shale reservoir.

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    Seismic Response Identification of Karst Reservoir in Lower Permian Maokou Formation in Southern Sichuan Basin
    LI Yuan, CHEN Sheng, WANG Peng, LIU Wei, FAN Kun, SUN Fu
    2021, 42 (5):  529-540.  doi: 10.7657/XJPG20210503
    Abstract ( 233 )   HTML ( 9 )   PDF (19937KB) ( 93 )   Save

    Oil and gas resources are very abundant in Block Y101 in southern Sichuan basin, and fractures and caves are very developed in the karst reservoirs of the Lower Permian Maokou formation which is the primary gas pay zone. However, the reservoir is thin and laterally heterogeneous, and the velocities of different lithologies of the Lower Permian Maokou formation and the overlying Upper Permian Longtan formation are very different. This results in a strong reflector with “two troughs and one peak”, which shields the karst reservoir in the underlying Maokou formation, and makes it difficult to identify and predict the seismic response of the karst reservoir. To identify the seismic response of the karst reservoir, a technical flow for wavelet reconstruction and waveform decomposition is established in frequency domain based on forward modeling. First, a karst reservoir model of the Maokou formation is established according to the drilling, logging and geological data in the study area, then forward modeling is conducted with acoustic wave equation based on finite difference methods, then the strong reflector is removed through frequency-domain wavelet reconstruction and waveform decomposition after multi-wavelet decomposition, and finally the seismic response of the karst reservoir is identified. Field application in Block Y101 has verified the effectiveness of the method. The frequency-domain wavelet reconstruction and waveform decomposition based on forward modeling can eliminate the shielding effect of the strong reflector, and the reservoir seismic response coincides with the well data.

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    Pore Structure and Sensitivity of Shale Reservoir in Lu 1 Member of Jimsar Sag
    LI Jingjing, SUN Guoxiang, LIU Qi, LIU Miao
    2021, 42 (5):  541-547.  doi: 10.7657/XJPG20210504
    Abstract ( 268 )   HTML ( 7 )   PDF (612KB) ( 216 )   Save

    In order to determine reservoir sensitivity of the shale in the first member of the Lucaogou formation (Lu 1 member for short) in Jimsar sag, we analyzed the pore structure and carried out physical simulation experiments on the reservoir sensitivity after understanding the reservoir mineral composition. The Lu 1 member reservoir belongs to terrigenous clastic deposits with complex mineral composition and rich clay minerals, most of which are swellable. The high content of brittle minerals and complex pore structures in the reservoir aggravated stress sensitive damage; the high content of swellable clay minerals increased water sensitive damage; the high contents of (iron) dolomite and clay minerals induced acid and alkali sensitive damage, but the high content of calcite slightly reduced acid sensitive damage. In conclusion, the Lu 1 member shale reservoir in the study area is moderately-strongly sensitive to stress and water, weakly-strongly sensitive to acid and weakly-approximately moderately sensitive to alkali. Reservoir sensitivity damages from acid, water and stress should be prevented in oilfield development.

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    Fractal Characteristics of Shale Pores From Taiyuan Formation to Shanxi Formation in Qinshui Basin
    YAN Gaoyuan, ZHANG Junjian, LU Guanwen, QUAN Fangkai
    2021, 42 (5):  548-553.  doi: 10.7657/XJPG20210505
    Abstract ( 297 )   HTML ( 8 )   PDF (588KB) ( 201 )   Save

    Based on the data of shale samples, including TOC, vitrinite reflectance and mineral composition, and through high-pressure mercury intrusion experiment, the pore structure parameters such as pore diameter, pore volume, specific surface area and porosity were obtained from the Taiyuan formation to the Shanxi formation in the Qinshui basin, and then fractal analysis was performed on the shale pore structure with a Sierpinski carpet model. The results show that the fractal mercury intrusion curve of the shale samples from the Taiyuan formation to the Shanxi formation can be divided into 3 sections such as AB, BC and CD. The pore diameter corresponding to the BC section is 21 to 6,035 nm. When performing fractal processing on a Sierpinski model, the pore structure of the BC section has the best characterization. In the range from 21 to 6,035 nm, the higher the clay mineral content, the stronger the heterogeneity and the more complicated of the pore structure. Pore volume, specific surface area and porosity are all negatively correlated with fractal dimension. Among them, pore volume and porosity have a good correlation with fractal dimension, and can be used as an indirect criterion for judging the complexity of pore structure.

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    RESERVOIR ENGINEERING
    Characteristics of Water Breakthrough and Optimization of Production System of Oil Wells Drilled in Ultra-Deep Fault-Karst Reservoirs: A Case Study on Well Z in Shunbei Oilfield, Tarim Basin
    CHENG Xiaojun
    2021, 42 (5):  554-558.  doi: 10.7657/XJPG20210506
    Abstract ( 309 )   HTML ( 7 )   PDF (1641KB) ( 310 )   Save

    In order to optimize the production system after water breakthrough in the oil wells drilled in ultra-deep fault-karst reservoirs and taking Well Z in Shunbei oilfield in Tarim basin as a case, the characteristics of reservoir geology and water breakthrough in the oil wells were analyzed through reservoir engineering method and numerical simulation. The well productivities before and after water breakthrough were compared, the water invasion rate and producing reserves were calculated, the water channeling characteristics was studied based on numerical simulation and the production system after water breakthrough was optimized. The results show that: 1) The inflow performance curve of Well Z is upturned, because the fluid flows at a higher rate after reducing the bottom hole flowing pressure or increasing the bottom hole producing pressure difference, and new fractures and caves open and more flowable channels occur, resulting in a great increase of the oil productivity in the well; 2) After water breakthrough, the daily oil production dropped sharply, and the productivity reduced dramatically; 3) The producing reserves in Well Z are about 338×104 t, bottom water invaded in January 2020 at a rate of about 0.61×104 m³/month, and by November 3, 2020, the water cone in Well Z was about 395 m from the initial oil-water contact and about 131 m from the bottom hole. According to the results, a 7 mm choke was recommended and used in Well Z. After field application, the daily oil production has increased from 96 t to 170 t and the water cut has been controlled less than 2.00%, indicating a satisfactory result.

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    Proppant Migration Law in Fractures of Conglomerate Reservoirs of Wuerhe Formation in Mahu Sag
    CHEN Chaofeng, WANG Jia, YU Tianxi, LI Yi, ZOU Yushi, MA Xinfang, LIU Li
    2021, 42 (5):  559-564.  doi: 10.7657/XJPG20210507
    Abstract ( 294 )   HTML ( 14 )   PDF (3768KB) ( 426 )   Save

    Fractures induced by volume fracturing stimulation to tight conglomerate reservoirs of the Wuerhe formation in Mahu sag are very complex, so that the migration and distribution laws of proppants are not clear, which seriously influences the fracturing effect. Based on 3D reconstruction of fracture shapes and considering the interaction between proppants and rough fracture surface, the influences of gravel size, gravel concentration and width attenuation of the fractures around gravels on proppant migration and distribution were investigated by using a Fluent two-phase flowing model. The results show that gravel size has obvious impacts on proppant migration, and it is negatively correlated to balanced height of proppant bank and positively correlated to balanced time of proppant bank; gravel concentration has weak impacts on proppant migration, and it is negatively correlated to balanced time and balanced height of proppant bank; width attenuation of the fractures around gravels has great influences on proppant migration, and both balanced time and balanced height of proppant bank decrease with the increase of the fracture width attenuation degree around gravels.

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    Full-Diameter Physical Simulation of Oxygen-Reducing Air Assisted Gravity Drainage: A Case Study of Gasikule E13 Reservoir in Qinghai Oilfield
    LONG Anlin, QI Qingshan, CHEN Xiaolong, LI Yiqiang, LU Shanshan, ZHANG Pei, LI Xin
    2021, 42 (5):  565-571.  doi: 10.7657/XJPG20210508
    Abstract ( 107 )   HTML ( 0 )   PDF (557KB) ( 68 )   Save

    Compared with conventional gas injection methods, the gas-injection assisted gravity drainage has the advantages of restraining gas channeling and expanding swept volume. In this study, a static low-temperature oxidation experiment was conducted to investigate the adaptability of the oxygen-reducing air-assisted gravity drainage in the Gasikule E13 reservoir. Oxygen-reducing air-assisted gravity drainage experiment was carried out with the help of natural full-diameter long core, so as to study the influences of oxygen volume fraction, gas injection rate and core inclination angle on the oxygen-reducing air-assisted gravity drainage. The results show that the oxygen-reducing air with low oxygen volume fraction (5%) plays a significant role in low-temperature oxidation in the Gasikule E13 reservoir, and the oxygen consumption rate can reach 2.19 mol/(h·mL). For the oxygen-reducing air-assisted gravity drainage, under the conditions of the Gasikule E13 reservoir, the ultimate recovery increases with an increased oxygen volume fraction of the injected air. The incremental recovery factor of the core experiment ranges from 1.2% to 6.9%. From the perspective of recovery ratio and safety, oxygen-reducing air with the oxygen volume fraction slightly lower than 10% can be applied as the displacement medium. Viscous fingering may occur when the gas injection rate is more than 1.0 mL/min, while capillary retention may occur when the oxygen injection rate is less than 0.1 mL/min, resulting in relatively low recovery factor. When the gas injection rate is 0.3 mL/min, it is a stable oil and gas flooding with a higher recovery factor. The process of the oxygen-reducing air-assisted gravity drainage is relatively sensitive to gravity. For the reservoirs with small inclination angles, the oxygen-reducing air-assisted gravity drainage is still feasible to some extent. The factors that affect the oxygen-reducing air-assisted gravity drainage in the Gasikule E13 reservoir are gas injection rate, core inclination angle and oxygen volume fraction in sequence according to their sensitivities.

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    Division and Application of Gas/Water Occurrence Models in High-Rank Coal Reservoirs
    LIU Zhong, WANG Ning, ZHANG Yongping, LU Xiuqin, LI Zheng, GAO Yan
    2021, 42 (5):  572-578.  doi: 10.7657/XJPG20210509
    Abstract ( 126 )   HTML ( 0 )   PDF (1216KB) ( 70 )   Save

    By analyzing the factors controlling hydrocarbon accumulation in Zhengzhuang block and Mabidong block in the southern Qinshui basin, and using molecular simulation technology, the microscopic laws of gas/water occurrence in the coal reservoirs were studied, then the occurrence models of methane in microscopic pores were demonstrated, and finally dynamic balance occurrence models considering the dynamic boundary effect of low-permeability fractures were established based on evaluation well data (i.e. measured gas content, fracturing stimulation and production data), microfracture models and boundary layer effects. The results show that anhydrous methane mainly adsorbs to the pores with a diameter of 2 nm, and as the gas saturation increases, the competition among water molecules weakens. The balance relationship among viscous force, gas/water phase pressure and capillary force is defined. The gas/water pressure balance models are divided into escaping and occluding modes. After analyzing the influences of 4 types of gas/water occurrence models on later production, it is believed that the gas output of Type Ⅲ and Type Ⅳ models is relatively higher.

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    Natural Energy Partition in Offshore Thin Heavy Oil Reservoirs With Edge Water
    XIE Mingying, YAN Zhenghe, WEI Xihui, WU Liulei, ZHANG Yu
    2021, 42 (5):  579-583.  doi: 10.7657/XJPG20210510
    Abstract ( 213 )   HTML ( 3 )   PDF (498KB) ( 269 )   Save

    The E heavy oil reservoir with edge water in eastern South China Sea has thin pay zones, gentle structures and a large oil-bearing area. The regional energy is insufficient and the production capacity can’t support oilfield development at a high rate, so it is urgent to update the development model. Numerical simulation was carried out on the influence of controlling factors on oil well performance and reservoir pressure, and the extreme distance from an oil well to the edge water was estimated when natural energy supply is sufficient, then the zones with sufficient energy and insufficient energy were determined, and finally natural energy partition charts for different water multiples were established after analyzing the controlling factors and grey correlation. The research results indicate that: (1) The higher the reservoir permeability, the higher the oil mobility, the thicker the pay zone, the greater the water multiples and the lower the fluid recovery rate, and the larger the sufficient energy zone range; (2) The natural energy boundary in the E reservoir, namely the extreme distance between an oil well and the edge water, is 922 m, which is consistent with the regional production performance. The findings above have proved that the charts are reliable and can be a reference to developing similar oil reservoirs.

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    Injection-Production Optimization of Carbonate Oil Reservoirs Based on a Well Connectivity Model
    LEI Sheng, ZHOU Yuhui, WANG Ning, Saierjiang AHATI, ZHENG Qiang, SHENG Guanglong
    2021, 42 (5):  584-591.  doi: 10.7657/XJPG20210511
    Abstract ( 307 )   HTML ( 13 )   PDF (636KB) ( 265 )   Save

    Carbonate oil reservoirs are very heterogeneous, so that injected water is easy to advance through high-permeability channels, and results in water channeling or flooding, and consequently fast rising water cut and low development effeciency in production wells. Based on the principle of well connectivity, and considering the geological features and development performance of fractured-vuggy carbonate oil reservoirs, parameters of well connectivity (conductivity and connected volume) were quantitatively characterized, then a vertical multi-layer well connectivity model was established, and parameters such as plane splitting coefficient and utilization rate of injected water were estimated for each layer of the oil reservoirs, and finally by using automatic history matching method and production optimization algorithm, real-time optimization and prediction of production performance of oil and water wells were realized. Field application has proved that the yearly incremental oil production is 1.1×104 m3 by using this method and good effect has been obtained. The method has important guiding significance for efficient development of similar oil reservoirs.

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    Comparison of Chromatographic Fingerprint Characteristics of Heavy Oil Based on Fire Flooding Experiments
    YAN Hongxing
    2021, 42 (5):  592-597.  doi: 10.7657/XJPG20210512
    Abstract ( 232 )   HTML ( 3 )   PDF (933KB) ( 187 )   Save

    In fire flooding development of heavy oil, oxidation at high temperature directly affects the evaluation on the development efficiency, and how to identify the combustion state is a technical difficulty. Physical simulation experiments on fire flooding were performed on natural cores, and fingerprint characteristics of saturated hydrocarbon, olefin and aromatic hydrocarbon in heavy oil were analyzed through gas chromatography. The results show that after fire flooding, influenced by oxidation at high temperature, (1) the content of saturated hydrocarbon in the heavy oil increases significantly, the chromatographic fingerprint is a pre-peak unimodal type, both the content of N-alkane and light-heavy ratio (∑nC21-/∑nC22+) increase, and no odd-even predominance appears; (2) on the chromatographic fingerprint, the olefins generated from cracking shows that the ratio of olefins to N-alkanes with the same carbon numbers is always less than 1, and the ratio decreases with the increase of the carbon number; (3) the chromatographic fingerprint of aromatic hydrocarbon is a pre-peak type, the content of methylnaphthalene is significantly lower than that of naphthalene in the naphthalenes, so it is easier to have methylation at the α place of the cracked naphthalenes, and the characteristics of the phenanthrenes are similar to those of the naphthalenes. Chromatographic fingerprint can effectively indicate microscopic changes of the heavy oil before and after fire flooding, which lays a foundation for identifying the combustion state of fire flooding.

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    APPLICATION OF TECHNOLOGY
    Application of Vertical P-Wave Slownesses in Porosity Evaluation of Shale Gas Reservoirs in Highly Deviated or Horizontal Wells
    ZHENG Jian, FU Yongqiang, CHEN Man, JING Cui, ZHANG Jing, ZHOU Hao, ZHANG Jiahao
    2021, 42 (5):  598-604.  doi: 10.7657/XJPG20210513
    Abstract ( 110 )   HTML ( 0 )   PDF (1337KB) ( 62 )   Save

    In Changning Shale Gas Pilot Development Area of Sichuan basin and based on vertical wells, a parameter model is built by using density, neutron, P-wave slowness, GR and resistivity logging data and core porosity and saturation to evaluate the resources. Horizontal well is used to develop the shale gas in the area. A parameter model is established with the same logging data from horizontal wells and core porosity and saturation from vertical wells to evaluate reservoirs in horizontal wells. P-wave slowness is the basic data for building the porosity and rock mechanical parameter model. The results show that the P-wave slowness measured in vertical wells is greater than those measured in highly deviated wells and horizontal wells in the Changning shale gas area. The P-wave slowness is greatly affected by well deviation, and the larger the well deviation, the greater the influence because of obvious velocity anisotropy in vertical and horizontal directions. In the same horizon and the same well interval, the porosity calculated from the model in highly deviated or horizontal wells is significantly different from the core porosity. In this study, we analyzed the relationships between P-wave slowness and well deviation in the same interval of the vertical, highly deviated and horizontal wells in the study area, and compared the P-wave slowness and porosities calculated by direct fitting method and anisotropic elliptic model method. It is considered that both of the two methods can reduce the influences of anisotropy and the anisotropic elliptic model method works better. Finally, the anisotropic elliptic model method has been widely used in porosity evaluation of shale reservoirs and good results have been gained in the study area.

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    Application of Thin Reservoir Prediction Technology Based on Frequency Domain in Coal Measure Strata
    FENG Xinpeng, WANG Tao, BAI Zhitao, NIE Wancai, HE Zhengguang
    2021, 42 (5):  605-611.  doi: 10.7657/XJPG20210514
    Abstract ( 220 )   HTML ( 7 )   PDF (17456KB) ( 245 )   Save

    The Lower Permian Taiyuan formation of marine-continental transitional facies and the second member of the Middle Permian Shanxi formation (Shan 2 member for short) of delta front facies are primary natural gas pay zones in eastern Ordos basin. They are tight lithologic gas reservoirs characterized by thin sand body and small scale. In the Taiyuan formation and the Shanxi formation, there are several coal seams, among which No. 4+5 coal seam in the middle-lower Shan 2 member and No. 9 coal seam at the bottom of the Taiyuan formation are most developed. With lower wave impedance, coal seams show stronger reflection than sandstone and shale with higher wave impedances, so that the former shield the weak reflection from the latter, making it difficult to effectively predict thin sand bodies by using conventional methods such as prestack inversion and seismic attributes. On the geological model of sandstone and shale reservoirs in the target intervals in the study area, we carried out forward modeling and time-frequency analysis, and found that generalized S-transform could adaptively adjust time-frequency analysis window according to signal frequency, and its resolution was higher. In the actual application, strong reflections from coal seams were suppressed, then generalized S-transform was performed to predict thin reservoirs in the study area. The result shows a high coincidence rate between seismic data and well logging data. The method can effectively predict thin reservoirs on the background of coal seams.

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    Lower Limits of Pore Throat Radius for Movable Fluids in Shale Reservoirs of Lucaogou Formation in Jimsar Sag
    TANG Hongjiao, LIANG Baoxing, LIU Weizhou, LIU Huan, SHI Feng, LAN Shangtao, WANG Qixiang
    2021, 42 (5):  612-616.  doi: 10.7657/XJPG20210515
    Abstract ( 218 )   HTML ( 10 )   PDF (499KB) ( 293 )   Save

    To get sufficient theoretical and experimental data for determining the lower limits of pore throat radius for movable fluids in shale reservoirs, core NMR, centrifugal, flowing and high-pressure mercury intrusion experiments were carried out on the physical characteristics of shale oil. Based on bridging theory and boundary layer theory, and combining macroscopic and microscopic analysis results, a method for determining the lower limits of pore throat radius in shale reservoirs was established. It is concluded that the lower limits of pore throat radius in the shale reservoirs of the Permian Lucaogou formation in Jimsar sag is 50 nm; the pore throats with the radius ranging from 50 nm to 500 nm are the primary contributors to movable fluids, and the contribution of the pore throats with the radius larger than 500 nm to movable fluids is less than 10%.

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    Thin Reservoir Prediction Under Strong Reflection Shielding Background in Chunguang Area
    XIE Qi, LI Hengquan, LI Lei, ZHANG Xinchao, GUO Jiayu, YANG Xingxing, JIA Xiurong
    2021, 42 (5):  617-623.  doi: 10.7657/XJPG20210516
    Abstract ( 126 )   HTML ( 0 )   PDF (3883KB) ( 57 )   Save

    In the Chunguang exploration area, the Carboniferous strata show strong seismic reflections, while the Cretaceous reservoir above and vertically close to Carboniferous is thin and laterally superposed, and completely shielded by the strong reflections from the Carboniferous. Vertically, we used forward modelling to get the dominant frequencies of AC and GR curves, and reconstructed the acoustic impedance curve to improve reservoir identification effects. Horizontally, the distribution of thin reservoirs shielded by strong reflections is predicted using high-resolution seismic inversion with waveform indication. Twelve lithologic traps has been identified, and commercial oil and gas flows have been obtained from one preliminary exploration well and one evaluation well. It has been proved that the technology can effectively predict thin reservoirs shielded by strong reflections, and it is also of great significance for predicting thin reservoirs on other similar complex background.

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    BP Neural Network-Based Models to Predict Clay Minerals
    LI Xinyu, OUYANG Chuanxiang, YANG Bowen, ZHAO Hongnan, NIE Bin
    2021, 42 (5):  624-629.  doi: 10.7657/XJPG20210517
    Abstract ( 255 )   HTML ( 12 )   PDF (650KB) ( 219 )   Save

    Accurate prediction of clay minerals is the key to deep drilling operation and pay zone protection. In order to determine the distribution law of clay minerals in the Jurassic Ahe formation in the northern tectonic zone of the Kuqa depression, Tarim basin, a well logging model and a combined model based on BP neural network were constructed by using GR logging parameters, cation exchange capacity, hydrogen index and photoelectric absorption cross-section index. The average absolute errors of the two models are 5.34% and 2.38%, respectively. Applied to Well Yinan 5, the average absolute errors of the models are 4.64% and 3.45%, respectively, by considering X-ray diffraction data. The prediction result shows that the clay mineral contents from high to low are illite, chlorite, illite/smectite mixed layer and kaolinite in Well Yinan 5. Damages from velocity sensitivity and acid sensitivity should be prevented in reservoir development.

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    REVIEW
    Progress and Enlightenment of Exploration and Development of Major Shale Oil Zones in the USA
    LI Qianwen, MA Xiaoxiao, GAO Bo, CHEN Xinjun
    2021, 42 (5):  630-640.  doi: 10.7657/XJPG20210518
    Abstract ( 433 )   HTML ( 29 )   PDF (803KB) ( 448 )   Save

    We reviewed the geological features, reserves, production, drilling activities and progress of development technology in major shale oil zones in the Permian basin, the Bakken area in the Williston basin and the Eagle Ford area in the Gulf of Mexico basin, analyzed the development trend of shale oil in the USA, and summarized the experience and enlightenment from the USA, with the intent to provide a reference to the development of shale oil in China. The results show that the Permian basin has the highest reserves and production of shale oil in the USA, which is mainly produced from the Spraberry zone and the Wolfcamp zone, and they will also be of great importance in the future. In 2020, influenced by COVID-19, the amount of drilling rigs and the oil production in the three major shale oil zones mentioned above first declined and then increased, and the ultra-low oil prices drove a new round of technological innovation and cost-cutting measures to increase well production in oil companies. By referring to the experiences in shale oil exploration and development in the USA, to develop shale oil in China, priority should be given to highly matured light oil and condensate oil, and the advanced development technologies of condensate oil reservoirs in the USA should be studied and followed. Grading evaluation of sweet spot is the basis of efficient development of shale oil in the USA, and plays a particularly significant role at low oil prices. There is a long way to go to get profitable development of shale oil in China. Technological progress is the key to reducing cost and enhancing profit. Technological researches should be paid attention to in early exploration and development. Life-cycle and geological-engineering integration management is recommended. This may be a new way for efficient shale oil development and rapid cost reduction in China.

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