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Sedimentary characteristics and models of shallow water delta front subfacies reservoirs: A case study of Sapugao oil layer in north-Ⅱ block of Sabei oilfield, Daqing placanticline
LIU Zongbao, LI Xue, ZHENG Ronghua, LIU Huaqing, YANG Zhanlong, CAO Song
2022, Vol.34(1): 1–13
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415 )
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411
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Sedimentary characteristics of gravity flow of middle Es32 member in Yingbei area, Dongying Sag
HUANG Yarui, YANG Jianping, LU Huidong, LI Yuzhi, HUANG Zhijia, DANG Pengsheng, FANG Ping, MU Yingshun
2022, Vol.34(1): 14–23
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314 )
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(7736 KB)
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274
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Simulation experiment of argillaceous sedimentary law of delta-shallow sea sedimentary system: A case study of Yanan Sag, Qiongdongnan Basin
QU Tong, GAO Gang, XU Xinde, WANG Rui, GAN Jun, LIANG Gang, YOU Junjun
2022, Vol.34(1): 24–33
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259 )
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(6944 KB)
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296
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Quantitative characterization of point bar sand bodies in meandering river under different curvatures: A case study of modern deposition of Baihe river in the source area of Yellow River
YI Zhifeng, ZHANG Shangfeng, WANG Yaning, XU Enze, ZHAO Shaohua, WANG Yuyao
2022, Vol.34(1): 34–42
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251 )
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(6101 KB)
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319
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Characteristics of paleotectonic stress field and fractures of WufengLongmaxi Formation in Luzhou area, southern Sichuan Basin
DONG Min, GUO Wei, ZHANG Linyan, WU Zhonghai, MA Licheng, DONG Hui, FENG Xingqiang, YANG Yuehui
2022, Vol.34(1): 43–51
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366 )
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(3994 KB)
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373
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Geochemical characteristics and geological significance of siliceous rocks of Wufeng-Longmaxi Formation in Xianfeng area, western Hubei
WANG Deng, ZHOU Bao, LENG Shuangliang, WEN Yaru, LIU Hai, ZHANG Xiaobo, YU Jianghao, CHEN Wei
2022, Vol.34(1): 52–62
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399 )
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(6276 KB)
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259
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Gas-water distribution characteristics and main controlling factors of Lower Permian Qixia Formation in Shuangyushi area, NW Sichuan Basin
XU Shiyu, LIN Yi, ZENG Yiyang, ZHAO Chunni, HE Kailai, YANG Jing, LI Yang, ZHU Yi
2022, Vol.34(1): 63–72
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328 )
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(3571 KB)
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269
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Biomarker characteristics and geological significance of Paleogene source rocks in Liaodong Bay
ZHANG Xiaoqin, LI Wei, WANG Feilong, WANG Ning, XU Yaohui, LIU Yan, CHENG Rujiao, LIU Huaqiu
2022, Vol.34(1): 73–85
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259 )
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(4457 KB)
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246
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Main controlling factors and models of Jurassic coalbed methane accumulation in Longdong coalfield
ZHU Zhiliang, GAO Xiaoming
2022, Vol.34(1): 86–94
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341 )
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(3548 KB)
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519
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New method of shale gas evaluation of Wufeng-Longmaxi Formation in Changning area, southern Sichuan Basin
WEN Kang, YAN Jianping, ZHONG Guanghai, JING Cui, TANG Hongming, WANG Min, WANG Jun, HU Qinhong, LI Zhipeng
2022, Vol.34(1): 95–105
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360 )
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(3795 KB)
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299
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Relationship between pore structure and oil production capacity of low permeability sandstone: A case study of block F154 in south slope of Dongying Sag
HE Xian, YAN Jianping, WANG Min, WANG Jun, GENG Bin, LI Zhipeng, ZHONG Guanghai, ZHANG Ruixiang
2022, Vol.34(1): 106–117
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293 )
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(6525 KB)
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316
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Logging identification method of lacustrine shale interlayers of Shahejie Formation in Zhanhua Sag
ZHAO Xiaoxiao, YAN Jianping, WANG Min, HE Xian, ZHONG Guanghai, WANG Jun, GENG Bin, HU Qinhong, LI Zhipeng
2022, Vol.34(1): 118–129
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312 )
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(8885 KB)
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233
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Evaluation of shale TOC content based on two machine learning methods: A case study of Wufeng-Longmaxi Formation in southern Sichuan Basin
YANG Zhanwei, JIANG Zhenxue, LIANG Zhikai, WU Wei, WANG Junxia, GONG Houjian, LI Weibang, SU Zhanfei, HAO Mianzhu
2022, Vol.34(1): 130–138
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436 )
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(2822 KB)
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401
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Seismic sedimentary characterization of thin sand layers of shallow water deltas: A case study of Qingshuihe Formation in Fangcaohu area, Junggar Basin
CHANG Shaoying, LIU Lingli, CUI Yuyao, WANG Feng, SONG Mingxing, MU Xiaoliang
2022, Vol.34(1): 139–147
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332 )
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314
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Least-squares reverse time migration in visco-acoustic medium based on GPU parallel acceleration and its application
ZHANG Meng
2022, Vol.34(1): 148–153
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261 )
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(3310 KB)
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248
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Modified flowing material balance method for fault-karst reservoirs
LI Dongmei, LI Huihui, ZHU Suyang, LI Tao
2022, Vol.34(1): 154–162
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281 )
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(3690 KB)
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322
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Geological characteristics and resource potential of overseas terrestrial shale oil
LI Mengying, ZHU Rukai, HU Suyun
2022, Vol.34(1): 163–174
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374 )
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(4187 KB)
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481
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Genesis of zeolite minerals and its influences on reservoir properties
WANG Tao, ZHANG Shengyin, WEI Pu, LI Junfei, GUO Hui, ZHANG Shuncun
2022, Vol.34(1): 175–186
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462 )
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332
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Distribution characteristics and controlling factors of global giant carbonate stratigraphic-lithologic oil and gas fields
XIONG Jiabei, HE Dengfa
2022, Vol.34(1): 187–200
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768 )
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696
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Sedimentary characteristics and models of shallow water delta front subfacies reservoirs: A case study of Sapugao oil layer in north-Ⅱ block of Sabei oilfield, Daqing placanticline
LIU Zongbao, LI Xue, ZHENG Ronghua, LIU Huaqing, YANG Zhanlong, CAO Song
2022, Vol.34(1): 1–13
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415 )
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doi: https://doi.org/10.12108/yxyqc.20220101
Shallow water delta front subfacies reservoir is an important research field for reservoir increase and production stabilization in China's main oil fields. In order to further explore the distribution characteristics of reservoir sand bodies,the sedimentary microfacies of 65 units of Sapugao oil layer in north-Ⅱ block of Sabei oilfield,Daqing placanticline were studied by using dense well pattern data,the sedimentary models of shallow water delta front subfacies reservoirs were established under the conditions of sufficient and insufficient provenance supply respectively. The results show that:(1) The Sapugao oil layer develope large shallow water delta front subfacies,which are characterized by fine lithologies,interbedded sand and mud,discontinuous positive rhythm,incomplete vertical facies sequence,subaqueous distributary channel as framework and undeveloped mouth bar. (2) The subaqueous distributary channels can be divided into nearshore broad-band type,middle shore narrowband type and far shore broken branch type. The distributary angle gradually increases,the bifurcation angle first increases and then decreases,and the width to thickness ratio gradually decreases along the provenance direction. (3) The outer front subfacies are controlled by source supply and wave transformation. The sheet sands were divided into thick and stable type,thick and unstable type,thin and stable type,thin and unstable type. The distal sand bars were divided into thick and wide band type,thin and narrow band type.(4) The Sapugao oil layer experienced a sedimentary evolution sequence of high-frequency oscillation in the early stage,slow decline in the middle stage and rapid rise in the late stage.(5) When the source supply is sufficient,the subaqueous distributary channel extends far and has high density,and the sheet sand scale is large and the distal sand bar is developed. When the source supply is insufficient,the subaqueous distributary channel extends near and has low density,and the sheet sand scale is small and the distal sand bar is undeveloped. The research results have reference significance for guiding the exploration and development of similar lithologic reservoirs.
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Sedimentary characteristics of gravity flow of middle Es32 member in Yingbei area, Dongying Sag
HUANG Yarui, YANG Jianping, LU Huidong, LI Yuzhi, HUANG Zhijia, DANG Pengsheng, FANG Ping, MU Yingshun
2022, Vol.34(1): 14–23
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doi: https://doi.org/10.12108/yxyqc.20220102
To study the sedimentary characteristics and evolution of gravity flow of the middle third member of Shahejie Formation(Es32) in Yingbei area, Dongying Sag, the sedimentary characteristics were analyzed by using rock cores, well logging, logging and analysis test data, sand groups were refined, and sedimentary microfacies map was drawn. The results show that gravity flow sand bodies of Es32 can be divided into channel-controlled deposit and non channel-controlled deposits. Channel-controlled deposit includes gravity flow channel and anterior complex subfacies. Gravity flow channel mainly includes gravity-flow channel and embankment microfacies, and anterior complex includes channelized lobes, tongue-like debris, turbidite lobes and turbidite sheet sands. Non channel controlled deposits mainly includes slide and slump. The sedimentary evolution model is:During the sedimentary period of Z6-Z4 sand groups, the water was relatively deep, which was mainly developed as the gravity flow deposition. During the sedimentary period of Z3-Z1 sand groups, with the decline of the lake level, shallow lake delta mouth bar sand bodies were developed in the east of the study area, and gravity flow deposit was mainly developed in the middle and west. This sedimentary evolution model of gravity flow can provide a geological model for reservoir prediction in the study area.
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Simulation experiment of argillaceous sedimentary law of delta-shallow sea sedimentary system: A case study of Yanan Sag, Qiongdongnan Basin
QU Tong, GAO Gang, XU Xinde, WANG Rui, GAN Jun, LIANG Gang, YOU Junjun
2022, Vol.34(1): 24–33
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259 )
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296
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doi: https://doi.org/10.12108/yxyqc.20220103
The delta-shallow sea sedimentary system has attracted the attention of many scholars due to its combination of terrestrial organic matter and marine organic matter. In recent years,oil and gas exploration practices in the South China Sea have shown that terrigenous marine mudstone of Yacheng Formation is one of the important sources of oil and gas generation. The source rocks are buried deep and there are few existing wells,which greatly limits the research and exploration progress of source rocks in this area. In order to study the deposition and distribution of argillaceous sediments,based on the geological background of Yacheng Formation in Yannan Sag, Qiongdongnan Basin,a sedimentary simulation experiment was designed to observe the sedimentary process,and the sedimentary bodies were sampled to determine the particle size composition of the samples. Combined with qualitative observation and quantitative comparison,the sedimentary law of argillaceous sediments in delta shallow sea sedimentary system was explored,and the dominant development position of terrestrial marine source rocks was revealed. The results show that from the provenance to the shallow sea,the argillaceous content of sediments increases as a whole. At the delta front slope,the argillaceous content increases suddenly due to the sudden drop of hydrodynamic conditions,but the total amount of the sediments increases first and then decreases,which makes the total amount of the argillaceous sediments decrease to the deep water. The delta front slope-shallow sea sedimentary area is the dominant area for the development of terrestrial marine source rocks,and argillaceous sediments can also be developed in the low-lying and weak hydrodynamic parts of the delta sedimentary body. The increase of terrain slope is conducive to the transportation of argillaceous sediments to the deep-water area. The delta frontshallow sea area is the main part of argillaceous sediment accumulation,that is,the nearshore area near the sea basin,which provides an important basis and guidance for the prediction of the dominant development parts of continental marine source rocks in the deep-water area of Qiongdongnan Basin.
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Quantitative characterization of point bar sand bodies in meandering river under different curvatures: A case study of modern deposition of Baihe river in the source area of Yellow River
YI Zhifeng, ZHANG Shangfeng, WANG Yaning, XU Enze, ZHAO Shaohua, WANG Yuyao
2022, Vol.34(1): 34–42
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doi: https://doi.org/10.12108/yxyqc.20220104
A correct understanding of the shape and scale of meandering river point bar sand bodies is of great significance to the understanding of interwell sand body connectivity,fluid migration path analysis and efficient and accurate tapping of remaining oil. Taking the modern Baihe river in the Yellow River source area as an example, ArcGIS software was used to vectorize the 31 typical point bar sand bodies in the Baihe satellite image,and the basic measurement data table of the parameters of point bar sand body scale was established. The typical point bar meandering sections were selected for characterization through slope division,and the quantitative relationship between the scale of the point bar sand bodies and the width of the river channel was discussed on the basis of curvature division. The results show that the larger the slope,the smaller the river width and the smaller the curvature. There is a positive correlation among point bar length,point bar width and river channel width,and the correlation is different under different curvatures. When the curvature k is less than 2,the correlation coefficient between point bar length and river channel width is 0.790,the correlation coefficient between point bar width and point par length is 0.812,and the correlation coefficient between point bar width and river channel width is 0.414. When k is 2.0-2.5,the correlation coefficient between point bar length and river channel width is 0.709,the correlation coefficient between point bar width and point bar length is 0.883,and the correlation coefficient between point bar width and river channel width is 0.841. The research results can be used for reference to the quantitative characterization of meandering river reservoirs.
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Characteristics of paleotectonic stress field and fractures of WufengLongmaxi Formation in Luzhou area, southern Sichuan Basin
DONG Min, GUO Wei, ZHANG Linyan, WU Zhonghai, MA Licheng, DONG Hui, FENG Xingqiang, YANG Yuehui
2022, Vol.34(1): 43–51
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366 )
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doi: https://doi.org/10.12108/yxyqc.20220105
As a key area for deep shale gas exploration in southern Sichuan Basin,Luzhou area has experienced multi-stage tectonic movements since Mesozoic. Studies have shown that fractures of deep shale reservoirs in Wufeng-Longmaxi Formation of Lower Paleozoic are mainly controlled by regional paleotectonic stress field. In order to explore the favorable deep shale exploration areas in Luzhou area,taking the deep shale reservoir of Wufeng-Longmaxi Formation in southern Sichuan Basin as the research object,based on fold-fault system,comprehensive interpretation of seismic data,buried paleostructure depth map and testing of mechanical parameters of shale rocks,an ANSYS finite element numerical simulation method was applied to carry out numerical simulation of the palaeotectonic stress field of the target layer of Yanshan Episode Ⅲ(the main formation period of fractures). Combined with the measured results of drilling fractures,the characteristics of fractures of WufengLongmaxi formations were predicted by using the mechanical principle of fracture formation. The results show that the in-situ stress of the deep shale reservoirs in this area has the characteristics of differential distribution. The maximum principal stress direction of Yanshan Episode Ⅲ is NW,with a value of about 135°. Fractures are developed in the narrow anticlinal core and near faults,relatively developed in the low and steep syncline area,and weakly developed in the wide and gentle synclinal core. Horizontal bedding fractures and high-angle fractures are mainly developed in the study area. The fracture density distribution gradually decreases from NE to SW. In the low and steep syncline area with high stress value,fractures in deep shale reservoir are developed,which is conducive to the accumulation of free natural gas. The results can provide geological basis for deep shale gas exploration and development in Luzhou area.
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Geochemical characteristics and geological significance of siliceous rocks of Wufeng-Longmaxi Formation in Xianfeng area, western Hubei
WANG Deng, ZHOU Bao, LENG Shuangliang, WEN Yaru, LIU Hai, ZHANG Xiaobo, YU Jianghao, CHEN Wei
2022, Vol.34(1): 52–62
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doi: https://doi.org/10.12108/yxyqc.20220106
In order to study the geochemical characteristics and genesis of siliceous rocks of Wufeng-Longmaxi Formation in Xianfeng area of western Hubei, the siliceous rocks of Shaling profile in Xianfeng area were identified by thin section identification, scanning electron microscope, major and trace elements analysis, and compared with typical hydrothermal siliceous rocks. The results show that the siliceous rocks of Wufeng Formation and Longmaxi Formation in the study area have high SiO2 content(the average mass fraction is 83.58% and 76.47% respectively). The siliceous minerals are mainly chalcedony, containing a small amount of micro quartz and terrigenous clastic quartz, with high Al(/Al+ Fe+ Mn), low MnO/TiO2 and high LaN/YbN values. The average values of w(LaN)/w(CeN) of Wufeng Formation and Longmaxi Formation are 1.15 and 1.06 respectively, with weak negative Ce anomaly and negative Eu anomaly, which are obviously different from hydrothermal siliceous rocks. The siliceous rocks of Wufeng Formation and Longmaxi Formation in the study area are of normal marine sedimentary origin, mainly biological sedimentation, accompanied by terrigenous input, and the sedimentary environment is a semi-restricted deep-water shelf on the continental margin. The relationship between biogenic silica content and TOC content is not a simple linear one, but increases at first and then decreases. Furthermore, the quartz intragranular pores and organic pores developed in radiolarians can significantly increase the reservoir space of siliceous rocks and improve shale gas capacity storage of siliceous rocks.
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Gas-water distribution characteristics and main controlling factors of Lower Permian Qixia Formation in Shuangyushi area, NW Sichuan Basin
XU Shiyu, LIN Yi, ZENG Yiyang, ZHAO Chunni, HE Kailai, YANG Jing, LI Yang, ZHU Yi
2022, Vol.34(1): 63–72
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doi: https://doi.org/10.12108/yxyqc.20220107
The Lower Permian Qixia Formation in Shuangyushi area of northwestern Sichuan Basin is one of the most potential exploration fields at present. Aiming at the unclear gas water distribution characteristics and main controlling factors of gas reservoirs of Qixia Formation in this area,the fluid properties and gas water distribution characteristics in this area were systematically clarified through experimental test analysis,drilling and logging data analysis,seismic data interpretation and production dynamic data analysis,and the main controlling factors of gas-water distribution were further discussed. The results show that the natural gas of Qixia Formation in shuangyushi area is typical dry gas,and the produced fluid can be divided into three types:formation water,flow-back fluid and condensate water. The chemical characteristics of formation water show that the gas reservoir has good preservation conditions. The production wells are mainly distributed in the low part of the structure or near the fault close to the low part. The gas reservoir has the characteristics of continuous gas-bearing in the high part of the structure,local water-bearing in the low part of the structure blocked by the fault,and the local gas-water relationship is complex. The main controlling factors of gas-water distribution are structural location and amplitude,local sealing of faults,hydrocarbon generation intensity of source rocks,reservoir physical properties,heterogeneity and paleogeomorphology. The research results can provide theoretical support for guiding the evaluation of favorable exploration zones of Qixia Formation and seeking the replacement field of large-scale reserves.
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Biomarker characteristics and geological significance of Paleogene source rocks in Liaodong Bay
ZHANG Xiaoqin, LI Wei, WANG Feilong, WANG Ning, XU Yaohui, LIU Yan, CHENG Rujiao, LIU Huaqiu
2022, Vol.34(1): 73–85
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doi: https://doi.org/10.12108/yxyqc.20220108
The third member(E2s3) and the first member(E2s1) of Paleogene Shahejie Formation,and the third member of Dongying Formation(E3d3) are the main source rocks in Liaodong Bay,with good oil and gas exploration prospects. In order to reveal the geochemical characteristics,sedimentary environment and biological source of source rocks,the abundance,types,maturity and biomarker characteristics of organic matter in these three sets of source rocks were studied by pyrolysis,total organic carbon content determination and saturated hydrocarbon chromatography-mass spectrometry. The results show that the source rocks of E2s1 have the highest abundance of organic matter,which is deposited in the reduced lacustrine environment with high salinity,and the organic matter mainly comes from lower aquatic organisms. The source rocks of E2s3 with high abundance of organic matter and more for mixed source are mainly deposited in freshwater lake facies sedimentary environment. The source rocks of E3d3 have the lowest organic matter abundance,which mostly come from terrigenous higher plants and are deposited in freshwater lacustrine sedimentary environment. The sedimentary environment and biological origin of the three sets of source rocks are obviously different. The gammacerane index,Pr/Ph and the relative content of regular sterane can effectively identify and distinguish the three sets of source rocks.
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Main controlling factors and models of Jurassic coalbed methane accumulation in Longdong coalfield
ZHU Zhiliang, GAO Xiaoming
2022, Vol.34(1): 86–94
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341 )
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519
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doi: https://doi.org/10.12108/yxyqc.20220109
Longdong coalfield in the southwestern margin of Ordos Basin is rich in low-grade coalbed methane resources. The exploration, exploitation and research in this area are still in the initial stage, and the understanding of main controlling factors and models of reservoir accumulation is still insufficient. To clarify coalbed methane enrichment law and optimize the exploration target areas, the drilling(field desorption, well test and core),logging, hydrological and geochemical test data were used to discuss the coal reservoir characteristics, main controlling factors and gas rich accumulation mechanism of the gas reservoir from the aspects of tectonic evolution,buried depth, sedimentary environment and hydrogeology conditions, and four coalbed methane accumulation models and corresponding gas reservoir types were classified and three favorable exploration areas were optimized. The results show that the thickness of coal seam in Longdong area is large,the heterogeneity of coal measure strata is strong, the coalification degree of coal rock is low, and the lateral variation of gas content is fast. Coal rocks have strong hydrocarbon generation capacity and good reservoir performance, the main controlling factors of rich gas accumulation are the development degree of caprocks and the adjustment of secondary biogas in the later stage. Buried depth controlling reservoir presents the characteristics of "optimal depth". The results provide reference and guidance for the well deployment of coalbed methane exploration in the later stage.
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New method of shale gas evaluation of Wufeng-Longmaxi Formation in Changning area, southern Sichuan Basin
WEN Kang, YAN Jianping, ZHONG Guanghai, JING Cui, TANG Hongming, WANG Min, WANG Jun, HU Qinhong, LI Zhipeng
2022, Vol.34(1): 95–105
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360 )
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doi: https://doi.org/10.12108/yxyqc.20220110
In order to evaluate the gas content of marine shale of Wufeng-Longmaxi Formation in Changning area,southern Sichuan Basin,the shale gas was divided into adsorbed gas and free gas and then calculated separately. Based on isothermal adsorption experimental data,a new adsorbed gas volume evaluation model was proposed and constructed based on micropore filling theory and D-A(Dubibin-Astakhov) equation. The key parameters affecting the adsorbed gas volume, such as formation pressure,total organic carbon(TOC) content and porosity, were taken into account in the calculation of the variable parameter V0 which is the maximum micropore adsorption capacity,the constant B related to the affinity of the adsorption system for gas,and the parameter t related to the surface heterogeneity of the adsorption system. Based on the gas saturation method and combined with the effect of adsorbed methane on pore volume,an evaluation model for quantitative correction of free gas volume was established. The results show that the newly established evaluation model of adsorbed gas and free gas volume has a good application effect in the evaluation of shale gas content in the study area,and the correlation coefficient between the calculated gas content and measured data is more than 0.90. The research results provide a basis for shale gas resource potential evaluation and sweet spot prediction.
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Relationship between pore structure and oil production capacity of low permeability sandstone: A case study of block F154 in south slope of Dongying Sag
HE Xian, YAN Jianping, WANG Min, WANG Jun, GENG Bin, LI Zhipeng, ZHONG Guanghai, ZHANG Ruixiang
2022, Vol.34(1): 106–117
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doi: https://doi.org/10.12108/yxyqc.20220111
The sandstone reservoirs of Shahejie Formation(Es3) in block F154 in the south slope of Dongying Sag are characterized by low permeability, complex pore structure and difficulty in productivity prediction. The pore structure characteristics and controlling factors were analyzed by using the data of core physical property test with overburden pressure,casting thin section,constant-rate mercury injection,high pressure mercury injection and X-ray diffraction. Based on the production data,the parameter of oil production intensity was obtained to represent the productivity. Relationships between pore structure parameters and oil production intensity were analyzed,and the pore structures were classified. The oil production intensity was calibrated to the logging curve through the identification of pore structure types. A multi-parameter oil production intensity prediction model was established based on sensitive logging variables,and verified with the data of actual wells. The results show that the number of large throats determines the permeability. The larger the oil production intensity,the better the pore structure. The intervals of pore structure with high oil production intensity usually have low natural gamma, high acoustic time difference,deep resistivity and deep and shallow resistivity difference. The correlation coefficient between the actual and the predicted oil production intensity is greater than 0.9,and the calculated results meet the requirements of production prediction. The research results provide a basis for the productivity prediction of low permeability sandstone reservoirs with complex pore structure.
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Logging identification method of lacustrine shale interlayers of Shahejie Formation in Zhanhua Sag
ZHAO Xiaoxiao, YAN Jianping, WANG Min, HE Xian, ZHONG Guanghai, WANG Jun, GENG Bin, HU Qinhong, LI Zhipeng
2022, Vol.34(1): 118–129
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doi: https://doi.org/10.12108/yxyqc.20220112
To study the relationship between lacustrine shale interlayer and shale oil productivity of the third member of Shahejie Formation in Zhanhua Sag,based on the analysis of core description,thin section identification,X-ray diffraction,scanning electron microscope and mercury injection,deconvolution method was used to process logging data to identify interlayer types.The results show that:(1) The content of brittle minerals in sandy interlayers and calcareous interlayers is high,which is easy to form fractures. The mass fraction of quartz-feldspar and calcite-dolomite is as high as 46.7% and 57.95% respectively.(2) Abnormal pressure fractures,mineral contraction fractures and interlayer fractures are developed in the interlayer,and structural fractures are also developed in the sandy interlayer. The average permeability of fractured interlayer is 7.59 mD.(3) The interlayers mainly develop micro and nano pores with good pore connectivity,including intergranular pores,dissolved pores and intergranular pores. Intergranular pores are shown in sandy interlayer. Dissolved pores are shown in calcareous interlayer,with more macropores.(4) The logging curve response characteristics of the interlayers are as following:both sandy interlayers and limestone interlayers are characterized by low natural gamma and high resistivity,sandy interlayer has low return under high natural gamma background,three-porosity curve and deep lateral resistivity shift to the right and three-porosity curve of limestone interlayer is obviously closed to the right. Overlapping the natural gamma and deep lateral resistivity curves processed by deconvolution method, it is quick to identify the interlayer with higher resolution and more intuitive,and effective to identify the lacustrine shale interlayer, which provides a basis for shale oil evaluation.
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Evaluation of shale TOC content based on two machine learning methods: A case study of Wufeng-Longmaxi Formation in southern Sichuan Basin
YANG Zhanwei, JIANG Zhenxue, LIANG Zhikai, WU Wei, WANG Junxia, GONG Houjian, LI Weibang, SU Zhanfei, HAO Mianzhu
2022, Vol.34(1): 130–138
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401
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doi: https://doi.org/10.12108/yxyqc.20220113
In order to establish a reasonable and accurate prediction method of shale total organic carbon(TOC) content of Wufeng-Longmaxi Formation in southern Sichuan Basin,the principal component analysis method was used to preprocess the logging curves and the measured TOC content data of 17 wells in Changning and Luzhou areas. Two TOC content prediction models were established based on BP neural network and gradient boosting decision tree(GBDT),and compared with the traditional TOC content prediction methods. The results show that:(1) The accuracy of the two models is higher than that of the traditional methods,and the consistence between the predicted results and the actual values can meet the requirements.(2) Compared with BP neural network model, GBDT has higher prediction accuracy,and the root mean square error is only 0.0387. The TOC content prediction model established by GBDT has the characteristics of low cost,high efficiency and continuity,and can be used to predict the TOC content of the target layer quickly and accurately. This achievement can provide effective technical support for improving the efficiency of shale oil and gas exploration and development.
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Seismic sedimentary characterization of thin sand layers of shallow water deltas: A case study of Qingshuihe Formation in Fangcaohu area, Junggar Basin
CHANG Shaoying, LIU Lingli, CUI Yuyao, WANG Feng, SONG Mingxing, MU Xiaoliang
2022, Vol.34(1): 139–147
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doi: https://doi.org/10.12108/yxyqc.20220114
Shallow water delta thin sand layer is an important new field of lithologic reservoir exploration. It is difficult to identify the sedimentary structure of shallow water delta due to thin sand bodies and rapid lateral variation,which restricts the exploration and development of this kind of sedimentary body. Taking Fangcaohu area of Mosuowan uplift in Junggar Basin as an example,the seismic sedimentological analysis technology was deepened through comprehensive geological and geophysical analysis. The seismic sedimentological characteristics of shallow water deltas were studied,and the sedimentary models of shallow water meandering river deltas were summarized by using three technologies, such as high and low frequency cycle waveform separation in parasequence set, remov-ing interference effect of stratigraphic slice and attribute fusion of geological body and sedimentary background. The results show that:(1) Multiple fourth-order sequences are developed in the first member of Cretaceous Qingshuihe Formation in Fangcaohu area,reflecting the periodic change of lake level.(2) Incised channels and fanshaped sand bodies are widely developed.(3) There are three sets of reservoir-cap assemblages developed in the shallow meandering river delta sedimentary system of the first member of Cretaceous Qingshuihe Formation, which are exploration strata with great potential in this area. The application of seismic sedimentary characteristics identification technology of thin sand layers in shallow water deltas has promoted the drilling of risk wells and achieved good exploration results. This technology provides technical support for increasing reserves and production in this area, and it can provide reference for the identification of thin sand layers in other similar areas.
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Least-squares reverse time migration in visco-acoustic medium based on GPU parallel acceleration and its application
ZHANG Meng
2022, Vol.34(1): 148–153
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doi: https://doi.org/10.12108/yxyqc.20220115
Conventional reverse time migration(RTM) algorithm is easy to produce strong low-frequency noise in shallow imaging, which cannot eliminate the absorption attenuation effect of earth medium. Based on the generalized standard linear solid model, the visco-acoustic wave equation was established, GPU acceleration was carried out in the two core algorithms of Born forward and gradient calculation, and the implementation process of leastsquares reverse time migration algorithm in visco-acoustic medium was proposed. The method was applied to a 3D data in the exploration area of Shengli Oilfield. The results show that the calculation efficiency and migration imaging quality are improved effectively. The comparison with conventional acoustic least-squares reverse time migration was carried out. The results show that this method is of great significance to improve the imaging accuracy of deep reservoirs, realize true amplitude imaging, and explore lithologic reservoirs.
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Modified flowing material balance method for fault-karst reservoirs
LI Dongmei, LI Huihui, ZHU Suyang, LI Tao
2022, Vol.34(1): 154–162
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doi: https://doi.org/10.12108/yxyqc.20220116
Due to the special shape of "vertical plate" in fault-karst reservoirs,it is necessary to establish a new flowing material balance(FMB) method according to its flow characteristics. The oil and gas flow model of faultkarst reservoirs was analyzed by graphic approach,and the permeability of the reservoir was calculated according to different flow characteristics and corresponding productivity equations. On this basis,a new FMB method for fault-karst reservoirs was established,and the applicability of the new method was verified by numerical model. The results show that the flow pattern of vertical wells in fault-karst reservoirs is linear flow,which is similar to that of horizontal wells in conventional reservoirs. While the flow pattern of horizontal wells in fault-karst reservoirs is radial flow,which is similar to that of vertical wells in conventional reservoirs. The dynamic reserve difference between the new method and the MBE method is less than 5%. The calculation of reservoir permeability by the new method is closer to the actual well conditions. This study provides a guideline for the dynamic reserve accounting of fault-karst reservoirs.
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Geological characteristics and resource potential of overseas terrestrial shale oil
LI Mengying, ZHU Rukai, HU Suyun
2022, Vol.34(1): 163–174
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doi: https://doi.org/10.12108/yxyqc.20220117
China is rich in terrestrial shale oil resources. After more than a decade of exploration of terrestrial shale oil focusing on basic research,key areas and selection evaluation,remarkable progress has been made in technological innovation,industrial test and pilot production,large-scale development,making it a key area for future oil and gas exploration. The systematic analysis was carried out about the geological characteristics,resource potential and development status of typical terrestrial shale oil all over the world,which can provide a reference for the geological evaluation and exploration and development of terrestrial shale oil in China. The results show that:(1) It is a superiority of high organic matter abundance,overpressure,and fragile calcareous layers and porous dolomite of the Uteland Butte member,Uinta Basin,USA,providing favorable conditions for horizontal well drilling.(2) Except for the USA,of the 152 shale oil formations in 101 basins worldwide,24 are terrestrial shale oil formations,accounting for about 19% of the total terrestrial shale oil resources.(3) There are six terrestrial source rock units are developed in six petroliferous basins in Argentina where the exploration and development of terrestrial shale oil is limited by low TOC content and source rock thickness.(4) REM Formation in Cooper Basin was estimated for about 2.4×108 t of technically recoverable resource according to burial depth(less than 2 000 m),vitrinite reflectance(Ro=0.7%-1.0%) and reservoir thickness(greater than 15 m).(5) The Prosopis, Mimosa and Kubla Formation in the Bongor Basin of Chad are the target formations for shale oil development, estimated a technically recoverable resource of 3.42×108 t,with the characteristics of high TOC content,moderate thermal maturity(Ro=0.7%-1.2%) and shallow depth(500-3 000 m).(6) The technically recoverable resources of shale oil of Early Cretaceous in Doseo Basin are 9.77×108 t.(7) The counterpart of the Brown Shale Formation and Talang Akar Formation in Sumatra Basin are 3.8×108 t and 5.61×108 t,respectively.(8) The terrestrial shale oil resources in Western and Northern Europe are mainly found in the Permian-Carboniferous Formation in Paris Basin,France,and the Wealden Formation in Lower Saxony Basin,Germany,and the technically recoverable shale oil resources are 4.36×108 t and 0.18×108 t respectively based on organic matter maturity and burial depth. The study can provide a reference for terrestrial shale oil exploration in China.
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Genesis of zeolite minerals and its influences on reservoir properties
WANG Tao, ZHANG Shengyin, WEI Pu, LI Junfei, GUO Hui, ZHANG Shuncun
2022, Vol.34(1): 175–186
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doi: https://doi.org/10.12108/yxyqc.20220118
In recent years,a large number of zeolite minerals have been discovered in the exploration and development of domestic oil and gas fields. In order to study the genesis of zeolite minerals and its influences on reservoirs,the zeolite types,development conditions and controlling factors in sedimentary basins,and the influences of zeolite minerals on reservoir were reviewed. The results show that:(1) Analcime,heulandite,laumontite and clinoptilolite are mainly developed in petroliferous sedimentary basins.(2) The genesis of zeolite can be divided into three types:volcanic vitreous water-rock reaction,lacustrine hydrothermal deposition and saline-alkaline riverlake. In China,the genesis of zeolite minerals in the Permian reservoirs in the northwestern margin of Junggar Basin,the Middle Jurassic in Sichuan Basin,the Upper Triassic in Ordos Basin,the Paleogene in Tarim Basin, the Paleogene to Neogene in Qaidam Basin and the Cretaceous in Songliao Basin are volcanic vitreous waterrock reaction. The zeolite minerals of Permian in Jimusar Sag and Shishugou Sag,Carboniferous to Permian in Santanghu Basin of Junggar Basin,Paleogene in Western Sag of Bohai Bay Basin,Cretaceous in Jiuquan Basin and Lower Cretaceous in Erlian Basin are derived from lacustrine hydrothermal deposition. Zeolite minerals of Paleogene reservoirs in Huanghua Sag of Bohai Bay Basin is saline-alkaline river-lake genesis.(3) The generation of zeolite occurs in alkaline environment,K+,Ca2+,Na+,Mg2+ plasma in water and temperature control of the types of zeolite,and pressure controls water content of zeolite,which makes the formation of zeolite under high pressure environment with less water content.(4) Zeolite minerals filled pores and played a certain supporting role in the early stage of diagenesis,and later dissolved under the action of organic acid to form secondary pores,which can improve reservoir properties. The research results can provide references for oil and gas exploration and reservoir reconstruction schemes zeolite-bearing basins in China.
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Distribution characteristics and controlling factors of global giant carbonate stratigraphic-lithologic oil and gas fields
XIONG Jiabei, HE Dengfa
2022, Vol.34(1): 187–200
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doi: https://doi.org/10.12108/yxyqc.20220119
Giant carbonate stratigraphic-lithologic oil and gas field is an important type of oil and gas field in the world. It has been proved to be rich in oil and gas resources and production. Ninety-four carbonate stratigraphiclithologic oil and gas fields were theoretically analyzed, including their geographical distribution, strata distribution, trap types, buried depth and reserve scale of reservoirs,and the main controlling factors of their distribution were discussed. Such oil and gas fields are mainly distributed in the North America, Middle East and Central Asia, among which North America has the most abundant oil and gas,and the oil and gas resources of carbonate reservoirs are mainly accumulated in the Ordovician, Carboniferous, Paleogene and Neogene. The traps can be classified as biological reef, grain beach, diagenetic trap, unconformity and weathering crust. The reservoir burial depth of these oil and gas fields is generally less than 5 000 m,and the oil and gas fields with reservoir burial depth of more than 5 000 m account for only 6.4%. The effects of the following five key factors on the formation and distribution of giant carbonate stratigraphic-lithologic oil and gas fields were discussed:(1) The stable and confined shallow water environment and mid-low latitude are conducive for the generation and preservation of organic matter.(2) Tectonic movement not only increases the reservoir spaces by producing a large number of faults and fracture zones, but also promotes the migration and accumulation of hydrocarbon(usually matching with the hydrocarbon generation stage), and provides a favorable background for paleo-karstification(. 3) Diagenesis such as paleo-karst improves reservoir performance.(4) Evaporite plays an important role in sealing oil and gas.(5) Trap finalization time and hydrocarbon generation and expulsion time of source rocks need to achieve a good matching relationship in time and space.