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Wang Qinhua, Yang Haijun, Cai Zhenzhong, Li Yong, Yang Xianzhang, Chen Cai, Chen Changchao Exploration breakthrough and significance of Ordovician fault controlled karst hydrocarbon reservoirs of Well Luotan1 in Maigaiti Slope of Tarim Basin China Petroleum Exploration    2024, 29 (2): 1-15.   DOI: 10.3969/j.issn.1672-7703.2024.02.001 Abstract （337）         Knowledge map    Save The Luotan1 well in the Maigaiti slope of Tarim Basin has made a new breakthrough in the Ordovician carbonate rocks, marking the first exploration breakthrough of a new type of Ordovician fault controlled karst carbonate reservoirs in the Maigaiti slope and marking the discovery of an important strategic replacement area in the slope area. Based on regional drilling, logging, seismic and other data, a comprehensive analysis of the laboratory data of well Luotan1 is carried out to further understand the reservoir formation conditions of Ordovician carbonate rocks in the Maigaiti slope. The formation of Ordovician carbonate fault controlled karst reservoirs in the Maigaiti slope is mainly related to strike slip fault activity, and is one of the three main reservoir formation models in the Maigaiti slope. At present, it has been discovered that hydrocarbon in the Maigaiti slope comes from the source rocks of the Cambrian Yuertus Formation, and the basement paleostructure controls the sedimentation and distribution of the Lower Cambrian source rocks. The slope area has three stages of hydrocarbon charging and accumulation: the Caledonian, Hercynian-Indosinian, and Himalayan periods. Hydrocarbon source rocks, paleotectonic evolution, and the faults connecting hydrocarbon source rocks control the multi-stage hydrocarbon accumulation. The fault active stages and fault penetrating layers determine the hydrocarbon enrichment layers and reservoir properties. The Maigaiti slope is characterized by well-developed Ordovician strike slip faults, with an extension distance of over 1000km, which control the distribution of fault controlled karst carbonate reservoirs and hydrocarbon reservoirs. It has clear zoning characteristics on the plane, with a large resource scale and strong deployability, demonstrating huge exploration potential. It is an important practical field for large-scale hydrocarbon exploration discovery and strategic succession in the southwestern Tarim Basin. Related Articles | Metrics

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Wang Guangyun, Wang Fenglan, Zhao Bo, Sun Guoxin, Meng Qi’an, Wang Yongzhuo, Liang Jiangping, Fang Yanjun Exploration and development situation and development strategy of Daqing Oilfield Company#br# China Petroleum Exploration    2021, 26 (1): 55-73.   DOI: 10.3969/j.issn.1672-7703.2021.01.005 Abstract （1170）   HTML    PDF （942KB）（2160）    Knowledge map    Save The PetroChina Daqing Oilfield Company (hereinafter referred to as the Company) is currently facing problems which can be summarized as “insufficient replacement resources, increasing difficulties in petroleum development”. This paper reviews the history of exploration and development of the Company, illustrating its achievements and technological advances in exploration and development and various business sectors. The major concerns and research directions are summarized, and development strategies outlined. It is considered that the exploration practice of Daqing Oilfield has been instrumental in improving the general theories of continental oil generation and source-controlled hydrocarbon accumulation. The company has developed exploration theories for continental depression lake basins, complex fault depressions, volcanic rocks, and tight oil and gas, with characteristic associated supporting technologies for petroleum exploration and development. The company faces issues with the expansion and extension of the scope of petroleum exploration and development, and a series of problems in developing the ultra-high water-cut Daqing Changyuan oilfield and the difficult-to-recover oil and gas reserves in the periphery of Changyuan oilfield. For this reason, the company has made it clear that research on supporting technologies for shale oil and carbonate rocks exploration and development should be accelerated, based on improving existing exploration and development technologies. Oil recovery and effective production of difficult-to-recover reserves should achieve the twin goals of effective replacement of resources and increasing oil and gas production. Meanwhile, based on analysis of the major contradictions and challenges, as well as the advantages and potentials of self-development, the Company has proposed a development strategy of “sustainable and effective development of local oil and gas business, large scale and ‘leap forward’ development of the overseas oil and gas business, steady and orderly development of emerging replacement business, and optimization and upgrading development of the service business”. Based on the strategic development objectives of the Company, the “14th Five-Year Plan” for petroleum exploration and development has been formulated, which provides resources guarantees for the transformation, upgrading and development of the Company. Reference | Related Articles | Metrics

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Sun Huanquan, Zhou Dehua, Cai Xunyu, Wang Feng, Feng Dongjun, Lu Ting Progress and prospects in shale gas development of Sinopec China Petroleum Exploration    2020, 25 (2): 14-26.   DOI: 10.3969/j.issn.1672-7703.2020.02.002 Abstract （1950）   HTML    PDF （1031KB）（71）    Knowledge map    Save China is rich in geological shale gas resources. However, when compared with North America, these resources are characterized by greater geological age, deep burial depths, and high degrees of thermal evolution, as well as complex structures and surface conditions. It is therefore very challenging to achieve commercial development of shale gas in China. Since 2006, Sinopec’s shale gas exploration and development has experienced three stages: investigation and favorable area selection and evaluation; exploration breakthrough, and rapid progress of exploration and development. In 2012, major breakthroughs were made in marine shale gas exploration, and the first shale gas field in China, the Fuling shale gas field, was efficiently established. The commercial development of deep shale gas in the Weirong block has been achieved, and other exploration areas continuously expanded. The proven reserves and production of shale gas have been increasing rapidly. After more than 10 years of scientific and technological research, and development of major equipment, Sinopec has innovatively pioneered a fine description and comprehensive evaluation technology system for shale gas reservoirs, developed a stereoscopic development adjustment technology, and formed a series of supporting technologies for optimized fast drilling and long horizontal well staged fracturing in mountainous areas, as well as green development of gas fields. In the future, Sinopec will continue to strengthen geological evaluation and exploration, consolidate the resource base for sustainable development, adhere to the development idea of geology- engineering integration, strengthen the upgrading of technical equipment, promote cost decreasing and benefit increasing in the oil and gas industry by using big data and artificial intelligence, emphasize the integrated management of whole projects, and improve the development efficiency of shale gas, so as to achieve a steady increase in shale gas proven reserves and production of Sinopec. Reference | Related Articles | Metrics

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Zhao Wenzhi, Jia Ailin, Wei Yunsheng, Wang Junlei, Zhu Hanqing Progress in shale gas exploration in China and Prospects for future development China Petroleum Exploration    2020, 25 (1): 31-44.   DOI: 10.3969/j.issn.1672-7703.2020.01.004 Abstract （2007）   HTML    PDF （783KB）（35）    Knowledge map    Save Shale gas exploration and development in China has entered a golden age of rapid progress. The increasing proportion of natural gas in the energy consumption structure of the nation, and the success of commercial shale gas development in the southern Sichuan Basin, indicate that shale gas will be the most reliable succession energy source for the future in China. This paper reviews achievements in theoretical understanding and technologies related to shale gas development over the past 10 years, summarizes successful experiences in commercial shale gas development, and clarifies the prospects for, and status of, shale gas in future natural gas development in China. China's shale gas resources have enormous potential, and provide a practical base for future growth in natural gas production. The conditions for obtaining industrial shale gas resources are described as ‘2 highs’ (high gas content and high porosity), ‘2 larges’ (large thickness of intervals with high TOC and large distribution areas), ‘2 moderates’ (moderate thermal evolution and moderate burial depth), and ‘2 goods’ (good preservation conditions and good fracability). Marine shale gas in China is of the highest potential, and at present is the major objective for natural gas production growth. Exploitation of the Ordovician Wufeng Formation and Silurian Longmaxi Formation shale gas in the Sichuan Basin and its surroundings has relied on developments in six technology areas: comprehensive geological evaluation; development optimization; fast drilling of horizontal wells; volume fracturing of horizontal wells; factory-like operation, and efficient and clean production. The successful achievement of commercial development of shale gas in China can be summarized as stemming from four key factors: ① optimized horizontal section targets; ② supporting technologies for effective and fast drilling and volume fracturing stimulation; ③ geological and engineering integration, and ④ advanced organization and management. Three proposals for the future development of shale gas in China are: ① to develop key technologies and equipment for low-cost development of non-marine and deep marine shale gas; ② to enhance block-scale shale gas recovery and achieve efficient development of the entire Sichuan basin; ③ to pay attention to the influence of non-resource factors on shale gas production. Reference | Related Articles | Metrics

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Wang Haige, Huang Hongchun, Ji Guodong, Chen Changchang, Lv Zehao, Chen Weifeng, Bi Wenxin, Liu Li Progress and challenges of drilling and completion technologies for deep,ultra-deep and horizontal wells of CNPC China Petroleum Exploration    2023, 28 (3): 1-11.   DOI: 10.3969/j.issn.1672-7703.2023.03.001 Abstract （611）   HTML    PDF （1246KB）（28）    Knowledge map    Save The deep, ultra-deep and unconventional resources have grown to be the major exploration and development fields for increasing reserves and production in China. Since the 13 th Five-Year Plan period, the engineering technology has continuously been researched by focusing on the key exploration and development targets in six basins (including five oil basins and three gas basins) and drilling speed acceleration difficulties, such as high temperature and high pressure formations and narrow fluid density window, and a large number of technical achievements have been obtained. For example, the key drilling and completion technologies for deep, ultra-deep and unconventional horizontal wells have been developed rapidly, forming key technologies with the core of unconventional well structure optimization, safe, highefficiency,optimal and fast drilling, high-temperature resistant drilling fluid, finely pressure-controlling drilling and completion, and expansion pipe, and a number of landmark ultra-deep wells have successfully been drilled; The equipment has been developed such as high-power top drive, integrated geo-steering system, and green economic reservoir reconstruction tool, as well as core additives such as temperature resistance high-performance drilling fluid and high-efficiency leak-proof and plugging materials have been researched, which have accelerated the lowcost,large-scale and cost-effective development of unconventional oil and gas resources. The drilling depth of deep wells exceeds 9000 m, the horizontal section length of horizontal wells is up to 5000 m, and the maximum footage of one trip drilling is 3700 m, with some indicators comparable to those in North America. The research achievements have boosted the discovery and development of large oil and gas fields such as Tarim Fuman, Sichuan Shuangyushi and Daqing Gulong, and provided powerful engineering and technical supports for improving the utilization rate and benefits of resource exploration and development. Associated with the continuous progress of petroleum exploration and development, the engineering geological risks and new challenges faced by drilling operations occur frequently. Therefore, further research is still necessary, including accurate prediction of formation pressure, optimization and expansion of wellbore structure, well trajectory control,high-temperature resistant working fluid system, high-efficiency rock breaking and speed-up tools, as well as integration of geology and engineering, so as to realize the continuous iteration and upgrading of key drilling technologies and equipment, and support the high-efficiency exploration and development of deep, ultra-deep, and unconventional oil and gas resources. Reference | Related Articles | Metrics

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Li Guoxin, Lei Zhengdong, Dong Weihong, Wang Hongyan, Zheng Xingfan, Tan Jian Progress, challenges and prospects of unconventional oil and gas development of CNPC China Petroleum Exploration    2022, 27 (1): 1-11.   DOI: 10.3969/j.issn.1672-7703.2022.01.001 Abstract （1714）   HTML    PDF （1156KB）（81）    Knowledge map    Save The China National Petroleum Corporation Limited (CNPC) has preliminarily achieved the large-scale production of unconventional oil and gas. However, considering its abundant resources, the output still has great potential for improvement. The exploration and development progress of unconventional oil and gas of CNPC during the 13 th Five-Year Plan period is summarized, and unconventional oil and gas development trend in the 14 th Five-Year Plan period is discussed. On this basis, the main challenges and key problems are analyzed,and strategies are put forward to promote the high-efficiency development of unconventional oil and gas of CNPC. The results show that: (1) During the 13 th Five-Year Plan period, CNPC has gradually focused on low-grade resources represented by unconventional oil and gas; (2) During the 14 th Five-Year Plan period, the proportion of unconventional oil and gas production will further increase, and production capacity in key areas will grow rapidly; (3) Four aspects of challenges, such as the technology, cost, management and idea, are faced with high-efficiency development of unconventional oil and gas. In view of the above challenges, six key countermeasures are proposed: (1) Properly understand the unconventional resources; (2) Implement the engineering management concept and mode of “one engine with six drives”; (3) Improve management rules and assessment methods; (4) Fully use the big data platform; (5) Effectively promote market-oriented business operation and socialized services; (6) Formulate rational policies for unconventional resource development. The above measures will enable CNPC to promote the high-quality development of its unconventional oil and gas business and contribute to “ensuring the rice bowl of energy firmly in our own hands” by developing the unconventional oil and gas. Reference | Related Articles | Metrics

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Fu Jinhua, Niu Xiaobing, Dan Weidong, Feng Shengbin, Liang Xiaowei, Xin Honggang, You Yuan The geological characteristics and the progress on exploration and development of shale oil in Chang7 Member of Mesozoic Yanchang Formation, Ordos Basin China Petroleum Exploration    2019, 24 (5): 601-614.   DOI: 10.3969/j.issn.1672-7703.2019.05.007 Abstract （1102）   HTML    PDF （3827KB）（8）    Knowledge map    Save Rich unconventional petroleum resources are developed in the Chang 7 Member of the Mesozoic Triassic Yanchang Formation in the Ordos Basin. At present, there are still disputes on whether it is tight oil or shale oil. According to the current situation at home and abroad, and its geological characteristics, we call it shale oil in this paper, i.e. the Chang 7 Member of Yanchang Formation in the Ordos Basin shale oil refers to the oil accumulation in tight sandstone and shale in the Chang 7 Member source rocks, which was formed without a long-distance migration. Depending on lithologic association and other factors, the shale oil reservoirs are classified into 3 types as multiphase sand overlay type (type I), shale interbedded with thin sandstone type (type II) and pure shale (type III). According to the comprehensive geological study, Chang 7 shale oil is characterized by the following: sand-mud reservoir with large area distribution, dense reservoir with good fluidity, high oil saturation, light oil, high gas-oil ratio, shallow burial, and large quantity of resources, etc. In recent years, through seismic survey, well logging, research on engineering and development technologies, achievements on exploration and development of shale oil in Chang 7 Member are achieved, such as: defined the scale reservoir area of type I shale oil, and 3 pilot areas for horizontal well development of type I shale oil were constructed; for type II and type III shale oil, production of oil was achieved through vertical well exploration; the scale development of type I shale oil has achieved remarkable results, and shale oil of Chang 7 Member has become an important resource guarantee for the "second acceleration" development of Changqing oilfield. Reference | Related Articles | Metrics

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Hu Dongfeng, Wei Zhihong, Liu Ruobing, Wei Xiangfeng, Liu Zhujiang, Chen feiran Major breakthrough of shale oil and gas in Well Taiye 1 in Bashansi Syncline in the Sichuan Basin and its significance#br# China Petroleum Exploration    2021, 26 (2): 21-32.   DOI: 10.3969/j.issn.1672-7703.2021.02.003 Abstract （1076）   HTML    PDF （5213KB）（14）    Knowledge map    Save In January 2021, Well Taiye 1, the first shale oil and gas exploratory well targeting at the Jurassic Lianggaoshan Formation, was deployed in the Bashansi Syncline in the northern part of Fuling area in the Sichuan Basin, and obtained oil and gas flow rate of 9.8 m3/d and 7.5×104 m3/d respectively, by multi-staged fracturing and testing of the horizontal section, indicating a major breakthrough in lacustrine shale oil and gas exploration. Based on drilling results of Well Taiye 1, hydrocarbon accumulation conditions and enrichment rules of lacustrine shale oil and gas in the Jurassic Lianggaoshan Formation were analyzed in detail. Results indicate that the producing layer in Well Taiye 1 is organic rich shale in the 2nd member of Lianggaoshan Formation (Liang 2 member) developed in semi-deep lake facies. In this layer, the 4th sub-layer is about 25.20 m in thickness, with the average TOC greater than 1.5%, organic matter type predominated by Type II, Ro ranging from 1.01%?1.41%, gas content of 1.81 m3/t, and an average porosity of 3.52%. Inorganic pores are dominant (clay mineral interlayer pores, intergranular pores, intragranular pores, etc.), and organic pores are developed locally, with pore diameter mainly of mesopores (2?50 nm) and macropores(>50 nm). Compared with other thin layers, the 4th sub-layer has the largest continuous thickness, the highest TOC, porosity, and gas content, representing a self-generation and self-storage shale oil and gas reservoir of “pure shale type”. The high-quality semi-deep lacustrine shale are widely developed in the northern part of Fuling area, which is favorable for shale oil and gas enrichment.The area with good preservation conditions, high formation pressure, and well-developed micro-fractures are conducive to the high production of shale oil and gas. Key technology of volume fracturing with characteristics of “few stages and multi cluster + temporary plugging and diversion + high pumping rate + medium to coarse sand proppants and high intensity sand injection” has been researched and developed, which enables effective stimulation on lacustrine shale. In conclusion, breakthrough of Well Taiye 1 is of great significance to the commercial development of lacustrine shale oil and gas in China. Reference | Related Articles | Metrics

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Li Xiu Classifications and Establishment of SPE Reserve China Petroleum Exploration    2010, 15 (4): 52-56,9,10.   Abstract （513）   HTML       Knowledge map    Save With the development of international oil exploration of SINOPC abroad, some technological specifications relevant to oil and gas exploration need to be in line with international standards. Among of this, it gets more urgent and necessary to establish reserves specifications. In recent years, Chinese companies have required that reserve estimation be implemented for all foreign-related oil fields as per SPE. Therefore, understanding and extending SPE reserves specifications is an important task in oil and gas explorations nowadays. Through analysis and research on documents related to SPE, this paper gives a detailed description to the concept relevant to oil reserves, classifications and applications, illustrates the applied conditions for SPE reserves classifications with some examples, and clarifies the reserves classifications and principles for different reservoirs based on SPE specifications Related Articles | Metrics

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Du Jinhu, He Haiqing, Yang Tao, Li Jianzhong, Huang Fuxi, Guo Bincheng and Yan Weipeng Progress in China ’s Tight Oil Exploration and Challenges China Petroleum Exploration

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Liang Xing, Zhang Lei, Jiang Liwei, Shan Chang’an, Pan Feng, Luo Yufeng, Meng Yang, Wang Gaocheng, Shu Honglin, Zhu Douxing, Li Boshuo, Wang Zhendong, Yao Qiuchang, Xu Zhengyu Exploration breakthrough and resource potential of limy source rock gas in Da’an area in the western Chongqing, Sichuan Basin China Petroleum Exploration    2024, 29 (2): 30-45.   DOI: 10.3969/j.issn.1672-7703.2024.02.003 Abstract （123）         Knowledge map    Save A major breakthrough has been made in the exploration of limy source rock gas in the first member of Maokou Formation (Mao 1 member) in Well DB1H in Da’an area in the western Chongqing, Sichuan Basin, which has important reference and demonstration significance for the intra-source exploration of limy source rock unconventional gas in the Basin. The first horizontal well DB1H was drilled to evaluate the dark limy source rock gas reservoir in Mao 1 member in Sichuan Basin and a high gas rate of 55.6×10 4 m 3/d was tested after acidizing and fracturing. The discovery process of limy source rock gas in Mao 1 member in Da’an area has systematically been introduced, and the resource prospect in Sichuan Basin has been estimated. The analysis of geological characteristics of limy source rock gas in Mao 1 member in Da’an area in the western Chongqing shows that the main lithology is composed of medium-gentle slope facies deep gray-black organic-rich micritic bioclastic limestone, with stable distribution in the region, which is an important marine limy source rock in the Middle and Upper Yangtze region in South China. The hydrocarbon accumulation process of limy source rock gas in Mao 1 member showed an “intra-source integrated evolution” of organic-rich carbonate rock deposition, diagenesis, hydrocarbon generation, reservoir formation, hydrocarbon accumulation and preservation, which had characteristics of “source rock and reservoir integration, in-situ hydrocarbon enrichment, and contiguous gas distribution”. The micro-sized pores in source rock, and the dissolution pores and micro-fracture network system associated with faults served as the main reservoir space, forming two types of reservoirs, i.e., matrix porosity type (primary) and fracture-porosity type (transformed). The hydrocarbon accumulation pattern of “mainly source rock and reservoir integration and enrichment in local structural transition zone after short-distance migration” has been established and the sweet spot evaluation system has been constructed. The key factors for gas enrichment and high-yield production in the new type of limy source rock reservoir in Mao 1 member include the development of organic rich dark limy source rock, favorable paleo uplift, anticlinal tectonic settings at present, and fault-controlled karst and extensional micro-fractures. The estimated resources of limy source rock gas in Mao 1 member are 2×10 12 m 3 in Sichuan Basin, which is a new unconventional field for increasing reserves and production in the basin. Reference | Related Articles | Metrics

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Zhou Lihong, Liu Xuewei, Fu Daqi, Li Dongping, Liao Xingsong, Zhang Shengchuan, Chai Gongquan, Zhao Min, Tian Fuchun, Zhao Yudong, Pu Xiugang, Liu Jianfeng, Yin Shunli Evaluation and application of influencing factors on the fracturability of continental shale oil reservoir: a case study of Kong 2 Member in Cangdong sag China Petroleum Exploration    2019, 24 (5): 670-678.   DOI: 10.3969/j.issn.1672-7703.2019.05.013 Abstract （740）   HTML    PDF （4133KB）（21）    Knowledge map    Save The Kong 2 Member in the Cangdong sag, the Dagang exploration region, is typical continental shale oil reservoir. It can’t be fractured based on the applicable brittleness index model for marine shale oil reservoir at home and abroad. According to geological analysis and core triaxial test, a brittleness index model describing the whole deformed and damaged process of the rock was established for the shale oil reservoir in the Kong2 Member using the fractal method. Then based on the analysis of how natural fractures propagate, the method for calculating the influencing factors of natural fractures and geostress were defined, and finally a fracture network index model integrating rock brittleness, natural fractures and geostress was built for quantitative prediction of the fracturability of the shale reservoir. The model is used to build the fracturability index profile and optimize the cluster spacing, perforating and fracturing parameters of horizontal wells. And together with optimized slip water + low-damage fracturing fluid, and quartz sand + ceramsite proppants, the volume fracturing technology for shale oil horizontal wells was developed. The technological achievements have been applied in Wells GD1701H and GD1702H. And micro-seismic survey and stable electrical field monitoring have found complex fracture networks, indicating remarkable effect of increasing production. Reference | Related Articles | Metrics

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Shi Yujiang, Liu Guoqiang, Zhong Jibin, Wang Juan, Zhang Wenjing Development and application of intelligent logging interpretation system based on big data#br# China Petroleum Exploration    2021, 26 (2): 113-126.   DOI: 10.3969/j.issn.1672-7703.2021.02.012 Abstract （1265）   HTML    PDF （3683KB）（42）    Knowledge map    Save Artificial intelligence technology has been used in well logging interpretation for a long time, but there are more researches on single model interpretation and less on application of system integration. Nowadays, large-scale application of cloud computing, big data and artificial intelligence technology has promoted the intelligent development of logging interpretation once again. Based on the data lake of multidisciplinary data fusion, intelligent interpretation module is developed in the logging interpretation software. That is, the intelligent logging interpretation method is introduced into the traditional interpretation process to assist logging analysts to quickly mine the hidden high-value information. Big data governance tools are used to connect data lake to intelligent model, so that big data and intelligent algorithm are integrated. The system integrates intelligent interpretation model based on big data with traditional professional software and builds an intelligent logging interpretation environment based on geological map navigation, realizing intelligent logging interpretation working mode with integration of geology and reservoir,strengthening the ability of complex reservoir evaluation, and improving the working efficiency. Reference | Related Articles | Metrics

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Qi Rong, He Faqi, Wang Fubin, Jia Huichong, Wang Wei Exploration breakthrough of Upper Paleozoic of Well Changtan 1 in southern Ordos Basin and its significance China Petroleum Exploration    2021, 26 (3): 68-78.   DOI: 10.3969/j.issn.1672-7703.2021.03.006 Abstract （489）   HTML    PDF （4379KB）（6）    Knowledge map    Save Binchang Block in the southwestern margin of Ordos Basin is with complex structural features, In 2020, Well Changtan 1, a risk exploration well drilled by Sinopec, tested commercial gas flow in the Upper Shihezi Formation, marking the natural gas breakthrough in Upper Paleozoic in the southern margin of Ordos Basin. Subsequently, several wells tested commercial gas flow or penetrated good gas shows in Upper Shihezi Formation, Lower Shihezi Formation and Shanxi Formation, showing multiple gas bearing layers of Upper Paleozoic in the complex structural zone of southern basin, which is different from the Longdong area inside basin. In order to find out gas accumulation pattern and improve understanding of the provenance system in the southern margin of the basin, in this paper, the gas accumulation conditions of Upper Paleozoic in Binchang block were systematically studied, including the regional tectonic evolution, fault activities, characteristics of coal measures source rocks, sedimentary facies, reservoir distribution, regional preservation conditions, and natural gas transportation characteristics by means of lithologic logging, formation test, chromatography-mass spectrometry analysis, logging interpretation, seismic interpretation and attribute analysis, and regional geological analogy, etc. The study results show that there are favorable geological conditions for natural gas accumulation of Upper Paleozoic in the southern basin, which is characterized by “multi-layer superposition, fault transportation, lower generation and upper storage, and stereoscopic gas accumulation”. The gas enrichment is jointly determined by the distribution of high-quality reservoirs and high angle fault transportation. The areas where large-scale delta sand bodies are developed with large thickness and good physical properties, as well as high angle faults for gas migration and accumulation are favorable targets for gas exploration. Reference | Related Articles | Metrics

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Tian Han, Wang Guiwen, Duan Shufu, Xin Yongguang, Zhang Hao Reservoir characteristics and exploration target of the Middle Triassic Leikoupo Formation in Sichuan Basin China Petroleum Exploration    2021, 26 (5): 60-73.   DOI: 10.3969/j.issn.1672-7703.2021.05.006 Abstract （344）   HTML    PDF （2672KB）（7）    Knowledge map    Save The Middle Triassic Leikoupo Formation is a major strategic replacement fi eld for petroleum exploration of PetroChina Southwest Oil and Gas Field Company in Sichuan Basin. The exploration situation is changing, and the rule of reservoir distribution in basin scale is necessary to be identifi ed, so as to provide guidance for gas exploration in the near future. The lithofacies paleogeography within sequence framework is further understood and reservoir characteristics are comprehensively analyzed by using a large number of core samples, well logging, seismic and outcrop data. The results show that: (1) It was a limited platform environment in Sichuan Basin during the deposition of Leikoupo Formation. The formation is subdivided into four tertiary sequences, and the favorable reservoirs are mainly developed in L1 1(1st sub-member of the 1st member of Leikoupo Formation), L33 and L43 sub-members of transgressive system tract; (2) The paleogeographic pattern of “one subsag and two uplifts” during the deposition of Leikoupo Formation controlled the distribution of beach reservoir, in which it was composite superimposed in the piedmont of Longmen Mountain in the western basin while it was migration superimposed of themarginal beach body of gypsum salt lake in the eastern basin; (3) There are two types of reservoirs of Leikoupo Formation, i.e., the faciescontrolled reservoir and karst reservoir. The former is dominated by grain beach dolomite and microbial dolomite, which is mainly developed in the basin margin and paleo highs inside the basin, while the latter is developed in the superimposed area of favorable facies zones and karst residual mounds. Finally, the favorable exploration targets are proposed by comprehensively considering source rocks, reservoir types and trap conditions, including grain beach dolomite and microbial dolomite reservoirs of L3 and L4 members in Jiange-Jiangyou-Mingshan area, beach dolomite reservoirs of L1 member in Ziyang-Nanchong area and the western margin of Luzhou paleo uplift, and karst reservoir in central Sichuan region. Reference | Related Articles | Metrics

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Li Junting, Li Song and Wen Zhifeng Strategies for Risk Management and Management Control of Overseas Exploration Projects China Petroleum Exploration    2013, 18 (4): 50-57.   Abstract （961）   HTML       Knowledge map    Save Overseas risk exploration projects are faced with the threats of geological conditions, political situation, fi nance and taxation items and so on in the running process, resulting in the limit of incertitude factors and self-experience as for the management, and the exploration decision is normally difficult to make and the operation methods may be improper, associated with the pressure of HSE and the problem of staff instability. Aiming at these problems, project managers should make appropriate exploration decisions from the angle of full risk management, and establish scientifi c and systematic evaluation system and response system by understanding the internal relationship among different risk factors. Overseas exploration projects are confronted with uncertainty factors such as space, time, budget, goal and task and so on in terms of management control, so they need to be constantly adjusted and optimized in terms of decisions and strategies in line with external factors. Domestic oil enterprises should continue to improve the quality of personnel, make efforts to improve the level of bidding, decision demonstration, and HSE management to be in line with international standards. By improving the technical strength and management level to maximize economic benefi ts of overseas exploration, it will precipitate overseas exploration to develop effi ciently and scientifi cally Related Articles | Metrics

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ZouCaineng,Tao Shizhen,Bai Bin,Yang Zhi,Zhu Ruka,HouLianhua,Yuan Xuanjun,ZhangGuosheng,Wu Songtao,Pang Zhenglian and Wang Lan Differences and Relations between Unconventional and Conventional Oil and Gas    Abstract （3360）   HTML       Knowledge map    Save With the world ’s oil and gas industry developing from conventional oil exploration and development to unconventional oil field, the study of unconventional oil exploration is drawing great attention. Unconventional and conventional oil and gas are substantially different in terms of eight aspects – basic conception, subject system, geological study, exploration method, evaluation of “sweet-spot zone, ” technological research, development method and production pattern. The geological theories of unconventional and conventional oil and gas are based separately on continuous hydrocarbon accumulation theory and buoyant trap accumulation theory. Unconventional oil and gas has two key characteristics. One is continuous distribution of oil and gas in a large area without obvious boundaries of traps. The other is no stable natural industrial output. The Darcy seepage is not obvious. There are two key parameters – porosity is lower than 10% and pore throat diameter is lower than 1μm or air permeability is lower than 1mD. As for conventional oil and gas, the above-stated characteristics and parameters are apparently different. The porosity usually ranges from 10% to 30% and the permeability is usually higher than 1mD. Unconventional oil evaluation is focused on six geological properties, such as source rock characteristics, lithologic character, physical property, brittleness, petroliferous property, and stress anisotropy. Conventional oil evaluation is focused on source rock, reservoir, cap rock, trap, migration and preservation as well as the optimum coupling relations of these six characteristics. There are eight elements for evaluation of “sweet spot zone ” of unconventional oil and gas abundance, of which three key elements are TOC higher than 2%, high porosity (tight oil and gas higher than 10% and shale oil and gas higher 3%) and development of micro-fractures. Evaluation of conventional oil reservoir is focused on core elements of accumulations and matching of time and space, emphasizing high-quality hydrocarbon source kitchen, favorable reservoir body, scale of trap, and effective conducting system. Unconventional oil and gas is obviously different from and closely related to conventional oil and gas. Unconventional oil and gas has something in common with conventional oil and gas, such as in the same oil and gas system and sharing the same hydrocarbon source system, the same primary migration force and the similar oil and gas components. Based on the substantial relations in genesis and distribution, conventional and unconventional oil and gas are in “orderly accumulations, ” related to each other in genesis, and symbiotic in time and space, forming a set of unified oil and gas accumulation system. In accordance with the law that conventional and unconventional oil and gas are in “orderly accumulations, ” the two different types of oil and gas resources should be taken into account as a whole in the process of exploration and development for harmonious development. Related Articles | Metrics

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Wei Ruibiao Factors Affecting Seismic Acquisition Effects on Red Bed in Chuxiong Basin China Petroleum Exploration    2015, 20 (3): 64-72.   Abstract （738）   HTML       Knowledge map    Save Seismic data of red bed in Chuxiong Basin show low signal-to-noise ratio and strong noise interference. Improvement of signal-to-noise ratio is one of the important areas in study of seismic exploration in this region. Based on the study of seismic geological conditions in this region as well as the data acquired in the past, this paper analyzes various factors affecting seismic acquisition effects in this region and draws the following conclusions. First of all, the dual complexity of surface and underground geological structure is the fundamental cause for poor quality of seismic data. Secondly, the main factors affecting seismic acquisition effects include shooting lithology, shot point location, watery stratum and development of interference wave, and limitation of geophone array and geometry design. Focusing on those factors and improvement of signal-to-noise ratio and stack section imaging effect, this paper comes up with a series of effective technologies seismic exploration of Chuxiong Basin, such as multiple channels, small group interval, long array and high folds. Meanwhile, it also points out that wide line acquisition technology is the study area of seismic acquisition method at the next stage in this basin to meet the demand for shale gas exploration. Reference | Related Articles | Metrics

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Yu Huilong, Xue Liangqing, Yang Fuzhong, Hong Guoliang and Kong Wei China Petroleum Exploration    2005, 10 (6): 64-70,10.   Abstract （73）   HTML       Knowledge map    Save Related Articles | Metrics

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Lei Qun, Weng Dingwei, Cai Bo, He Chunming, Shi Yang, Ma Zeyuan Progress, key challenges and countermeasures of reservoir stimulation technology of PetroChina China Petroleum Exploration    2023, 28 (5): 15-27.   DOI: 10.3969/j.issn.1672-7703.2023.05.002 Abstract （503）   HTML    PDF （1123KB）（8）    Knowledge map    Save In order to guarantee the policy of national energy resources security and accelerate domestic oil and gas production, confronting growing complex exploration objects, innovation and advance in reservoir stimulation are the most significant drivers for discovering resources and increasing reserves. By comprehensively reviewing the development history of reservoir stimulation and analyzing technical challenges for exploration target characteristics of PetroChina Company Limited (PetroChina), main progress of reservoir stimulation is systematically summarized, including the optimized design of fracture-controlled stimulation to maximize the release of reserves, the increasing operational capability of fracturing equipment, more robust downhole tools, lower cost of fracturing fluid and improved personalization, and the obvious trend of proppant to low-cost and small mesh size. The supporting role of reservoir stimulation for exploration discovery is clarified. A comprehensive analysis of the key problems faced by hydraulic fracturing is conducted in four aspects: i.e., primary elements of fracturing, fracturing design optimization, field operation quality, and technology evolution. Specifically, the countermeasures in four aspects are proposed: (1) igniting innovation of basic research to provide theoretical support for the progress of fracturing technology; (2) promoting the quality of five primary elements to support the high-quality development of reservoir stimulation technology; (3) promoting the precise technical scheme to provide guidance for more efficient exploration and development of oil and gas; (4) increasing the efficiency of technical management to create a new mode of efficient treatment of engineering management. Reference | Related Articles | Metrics

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Yang Xiangtong, Zheng Zijun, Zhang Yang, Yu Yinhua, Feng Jueyong, Wang Zhenlan, Teng Qi, Dong Jianyi Application of geology-engineering integration in productivity prediction for stresssensitive tight reservoir: a case study of × block in western Kuqa China Petroleum Exploration    2017, 22 (1): 61-74.   DOI: 10.3969/j.issn.1672-7703.2017.01.009 Abstract （1271）   HTML    PDF （4442KB）（444）    Knowledge map    Save The stress sensitivity observed during the production of tight reservoir in western Kuqa was studied and simulated by geomechanicsrelated theories and advanced techniques. It is indicated that the stress sensitivity is essentially the complex variation and interaction among seepage field, ground stress field and fracture status during the production. In order to determine this interaction and its effects on productivity, a numerical simulation of the gas reservoir system, mechanic system and fracture system was carried out by coupling of multi-discipline data, based on the concept of geology-engineering integration. Taking a gas well in No.1 block as an example, the available data of multiple disciplines were analyzed, and reliable 3D gas reservoir model, 3D geomechanics model, and 3D discrete fracture model were built up respectively. Then, the coupling parameters between the models (i.e., stress-permeability relationship and stress-fracture aperture relationship) were determined by physical and numerical experiments. Finally, by a coupling numerical simulation, the changes of ground stress, formation pressure and seepage field with space and time in the designed development plan were identified, and the results obtained were compared with the results of simulation without considering stress sensitivity. The study results show that the permeability and fracture conductivity of stresssensitive reservoirs dropped evidently during production. Generally, the influence of the stress sensitivity on the productivity was large during early stage, decreasing during middle stage, and finally increasing again during later stage. When there was stress sensitivity, both the stable production period and the total production ratio declined greatly. The study results also show that excessive production pressure difference may lead to too fast permeability decline, and cause permanent damage which may hinder the production. Therefore, it is very important to select reasonable production pressure difference. Reference | Related Articles | Metrics

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Fan Tanguang, Xu Xiongfei, Fan Liang, Feng Yaqin, Liu Wenhui, Liu Juntian, Wang Meiyan, Jia Guoqiang Geological characteristics and exploration prospect of shale oil in Permian Lucaogou Formation, Santanghu Basin China Petroleum Exploration    2021, 26 (4): 125-136.   DOI: 10.3969/j.issn.1672-7703.2021.04.010 Abstract （448）   HTML    PDF （7920KB）（8）    Knowledge map    Save Permian Lucaogou Formation, mainly composed of mixed fi ne-grained sediments in salinized continental lake basin, is the most important source rock in Santanghu Basin, which has favorable conditions for forming shale oil reservoir. At present, several large-scale reserve areas have been found in Malang and Tiaohu Sags. Based on the early achievements, this paper studies the existing geological data,systematically sorts out the geological conditions for forming shale oil reservoir in Lucaogou Formation, summarizes the exploration and development progress and existing problems, and discusses the exploration prospect and potential targets for the next step. The results show that: (1) The interbedded mixed fi ne-grained sediments are developed in the salinized continental lake basin; (2) High quality source rocks are widely distributed with good material basis for hydrocarbon generation; (3) “Sweet spot” reservoir is developed with good reservoir space of thick tuff and dolomite; (4) Retention hydrocarbon expulsion, near source charging, and in-situ hydrocarbon accumulation; (5) The physical properties of crude oil are complex, with high mobility shale oil developed locally; (6) The reservoir is rich in quartz, carbonate and other brittle minerals, which is conducive to reservoir fracturing. According to preliminary evaluation, the geological resources of shale oil in Lucaogou Formation are nearly 395 million tons, with great exploration potential. In recent years, a series of progress has been made in seismic prediction, logging evaluation, horizontal well drilling and completion, fracturing and other aspects through integrated and collaborative research, which has achieved good results and strengthened the confi dence of Tuha Oilfi eld Company in shale oil exploration and development.In the future, the high mature light shale oil in the western margin of Malang Sag-southern margin of Tiaohu Sag, and near source shale oil of tight sandstone in the southern margin of Malang Sag are new fi elds for shale oil exploration in Santanghu Basin. Reference | Related Articles | Metrics

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Liu He, Tao Jiaping, Meng Siwei, Li Dongxu, Cao Gang, Gao Yang Application and prospects of CO 2 enhanced oil recovery technology in shale oil reservoir China Petroleum Exploration    2022, 27 (1): 127-134.   DOI: 10.3969/j.issn.1672-7703.2022.01.012 Abstract （727）   HTML    PDF （2947KB）（70）    Knowledge map    Save The development of continental shale oil in China faces the bottleneck of low production of single well, rapid decline and low ultimate recovery. Therefore, the CO 2 enhanced oil recovery (EOR) technology is necessary to be researched in advance. The development process of CO 2 EOR technology in North America is systematically analyzed, and the applicability and prospects of this technology are discussed by combining with the conditions of domestic continental shale oil resources. The result shows that the shale oil plays in China are characterized by a significant variation on crude oil viscosity, formation pressure coefficient and mineral compositions, which have distinctly different challenges for benefit development and largely different CO 2 EOR mechanisms. As a result, a targeted application index of CO 2 EOR technology is required for various shale oil plays, as well as a technical adaptability evaluation criterion. Meanwhile, efforts should be intensified in all links of field application of CO 2 EOR technology, and clear national financial support should be sought actively. Considering the technology prospects and resource conditions, it is proposed to build a pilot demonstration area for CO 2 EOR application in Jimsar shale oil block in Junggar Basin and establish an integrated technology and policy supporting system, so as to effectively promote the development of CO 2 EOR technology, ensure the domestic energy security and support to achieve the strategic goal of carbon neturality. Reference | Related Articles | Metrics

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Yang Zhanwei, Cai Bo, Xu Yun, Liu Ju, Liu Huifeng, Wang Liwei, Gao Ying, Han Xiuling, Wang Liao, Ma Zeyuan Evaluation of the effectiveness of network fracturing in ultra-deep and extremely-thick reservoir in the Kuqa piedmont China Petroleum Exploration    2020, 25 (6): 105-111.   DOI: 10.3969/j.issn.1672-7703.2020.06.011 Abstract （718）   HTML    PDF （2242KB）（472）    Knowledge map    Save The Cretaceous Bashijiqike Formation is the main producing layer of the Keshen gas field in the Kuqa piedmont. The deepest exploration well in the field is more than 8000 m. The reservoir pressure is 150 MPa, maximum temperature is 190 C, and the thickness is 100300 m. These extreme operating conditions and the attendant well-control risks limit the testing methods that can be used for evaluation of fracturing effects following stimulation. It is therefore necessary to develop a method for obtaining a clear understanding of whether this kind of reservoir is suitable for stimulation by volume fracturing and establish how to determine whether a reservoir has been effectively fractured. This study summarizes the network fracturing technologies commonly used for the ultra-deep reservoirs in the Kuqa piedmont. The geological and engineering factors that lead to the formation of complex fracture networks are analyzed. In doing so, interconnection and extension of artificial and natural fractures and the geological and mechanical conditions affecting the formation of longitudinal and transverse fracture networks are discussed. The theoretical change in operating curves that should result from successful temporary plugging diversion is studied. Actual operating curves and theoretical curves are then compared and analyzed after a temporary plugging diversion agent has been inserted in the artificial fractures. The conclusions are mutually verified by a combination of micro-seismic monitoring and interpretation of wells after network fracturing. The results show that, for ultra-deep and extremely-thick reservoirs with well-developed natural fractures, transverse fracture networks and longitudinal multi-layer stimulation can theoretically be achieved by fracturing. However, the temporary plugging diversion technologies currently used within fractures, and temporary plugging layering at the fracture opening, are ineffective. It is therefore important to engage in research on ultra-deep temporary plugging layering and temporary plugging diversion technologies that will provide strong technical support for efficient exploration of reservoirs deeper than 8000 m and increase the likelihood of exploration breakthroughs. Reference | Related Articles | Metrics

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Zhang Yiming, Zhang Ruifeng, Wang Shaochun, Liu Xiheng, Li Yongjun, Liu Jing, Wang Huilai, Wang Jian, Wu Chenlin, Dan Weining Practice and understanding of great discovery in oil and gas exploration in Linhe depression of Hetao Basin China Petroleum Exploration    2018, 23 (5): 1-11.   DOI: 10.3969/j.issn.1672-7703.2018.05.001 Abstract （1972）   HTML    PDF （3361KB）（732）    Knowledge map    Save The Linhe depression of Hetao Basin is a Meso-Cenozoic strike-slip pull basin. The early stage wells were mainly concentrated in the slope zone, which had oil and gas shows but no substantial breakthroughs. Recently, new and old data including gravity, magnetic, electric, seismic, drilling and geology data were used to investigate the basin property, structural characteristics, resource potential and reservoir-cap combination. It is understood that the depression is a strike-slip pull depression, which is zoning east-west and blocking north-south. Two major source rocks in the Lower Cretaceous and Oligocene respectively are confirmed. Three sets of source-reservoir-cap are identified. Indepth comprehensive analyses of the trap-source relationship and the oil and gas accumulation models showed that the Jilantai buried hill is favorable for oil and gas accumulation for its adjacency to the northern deep sag hydrocarbon generation area with Langshan piedmont fault as the main channel for oil and gas migration providing good lateral oil supply conditions. The Jilantai buried hill and its periclinal fault structural belt were selected to deploy Well JHZK2, Well JHZK7 and Well Jihua 2x. All of the three wells have obtained industrial oil flow, which was a great discovery of Linhe depression and demonstrated a broad exploration prospects. With the attention of PetroChina Company and the support of Changqing Oilfield Company as the basis, the innovative geological understanding and scientific deployment and decision-making as prerequisites, the thought-transform and key point-selecting as the key and the selection of economically applicable technologies as the guarantee, the Linhe Depression successfully achieved rapid exploration. Reference | Related Articles | Metrics

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Zhi Dongming, Li Jianzhong, Yang Fan, Kang Jilun, Zhang Wei, Ma Qiang, Tao Linben Geological characteristics and exploration and development practice of the Permian full oil and gas system in Jimsar Sag, Junggar Basin China Petroleum Exploration    2023, 28 (4): 14-23.   DOI: 10.3969/j.issn.1672-7703.2023.04.002 Abstract （179）   HTML    PDF （12410KB）（9）    Knowledge map    Save Based on the study of source rock, sediment source system, tectonic evolution and dynamic matching relationship between hydrocarbon source and reservoir, the Permian oil and gas bearing system in Jimsar Sag is analyzed in detail. The study results indicate that the Permian in Jimsar Sag has favorable geological conditions for forming full oil and gas system. On the plane, shale oil, tight oil, conventional glutenite oil reservoirs are distributed in sequence from the central to the marginal sag, and tight oil, shale oil, conventional glutenite oil reservoirs are distributed upward around the high-quality source rock in Lucaogou Formation, showing the overall hydrocarbon accumulation characteristics of “full oil and gas system”. Guided by this understanding, breakthroughs have been made in the exploration of three types of oil reservoirs, basically forming a pattern of oil bearing in the whole sag and orderly co-occurrence and superposition of multi-layer and multi type oil reservoirs. By applying the large platform and multi-layer stereoscopic development mode, the exploration idea and technology for maximizing the benefit resource utilization are gradually mature in practice. The detailed analysis of geological characteristics, hydrocarbon accumulation pattern, and exploration and development practice of the Permian full oil and gas system in Jimsar Sag is of great significance for enriching the exploration theory of the full oil and gas system and guiding the exploration and development in similar oil rich sags. Reference | Related Articles | Metrics

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Liu Tao, Shi Shanzhi, Zheng Zijun, Ji Yongjun, Wang Lei Application of geology-engineering integration for developing tight oil in glutenite reservoir by horizontal wells in Mahu sag China Petroleum Exploration    2018, 23 (2): 90-103.   DOI: 10.3969/j.issn.1672-7703.2018.02.012 Abstract （1303）   HTML    PDF （4461KB）（483）    Knowledge map    Save Tight glutenite reservoirs in Block Madong 2 at the eastern slope of the Mahu sag in the Junggar Basin are buried deeply, poor in physical properties, and very sensitive to water and pressure; and the glutenite is hard to grade, strongly heterogeneous and brittle, so that it is difficult to get economic exploitation. With experiences from adjacent regions, and integrating geologic cognitions with engineering techniques, the engineering design of the first horizontal evaluation well (Madong 1) in this block was optimized, and the advanced technology was introduced to guarantee application effect. Specifically, many core experiments and fine well logging interpretation were conducted to identify the lithologies and physical properties of the glutenites; fine seismic acquisition, processing and interpretation were carried out and the method of classifying glutenite reservoirs was established to optimize target layers and well trajectories; advanced geosteering tools and real-time model-updating technique were used to increase drill-in rate and drilling efficiency; and well test and numerical stimulation were performed to study factors affecting post-fracturing production of glutenite reservoirs and optimize engineering techniques. Base on multidisciplinary cooperation, Well Madong 1 obtained average oil production of 53.9 t/d through a 3-mm choke at stable water cut. Such production increase is much higher than a vertical well in the block. Reference | Related Articles | Metrics

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Zhou Lihong, Chen Changwei, Sun Tong, Song Shunyao, Dong Xiaowei, Wu Xuesong, Yang Peng, Wang Shuai, Duan Runmei, Liu Huifang, Li Xiaojing, Guo Qiuxia A major discovery in the second member of the Paleogene Kongdian Formation in Well Cangtan1 in Cangdong deep subsag area in Bohai Bay Basin and its exploration significance China Petroleum Exploration    2024, 29 (2): 16-29.   DOI: 10.3969/j.issn.1672-7703.2024.02.002 Abstract （105）         Knowledge map    Save Recently, the high-yield oil flow was obtained in the second member of the Paleogene Kongdian Formation (Kong 2 member) in a risk exploration well Cangtan 1 drilled by PetroChina, indicating a major breakthrough in the exploration of deep lithologic oil and gas reservoirs in Cangdong Sag in Bohai Bay Basin. Based on the understanding of Well Cangtan 1, favorable conditions for hydrocarbon accumulation in Cangdong deep subsag area are systematically analyzed to evaluate the exploration prospects and identify the favorable exploration orientation. The study results show that, during the deposition period of Kong 2 member, Cangdong deep subsag area was a subsidence center controlled by Cangdong Fault, providing accommodation for the development of semi deep-deep lake facies source rock. During the lake expansion period, source rock was widely deposited in the deep subsag area, with Type Ⅱ organic matter, high TOC, and mature-highly mature thermal evolution stage (average R o of 1.3%). The deep subsag area was located at the edge of the lake basin, developing a complete provenance-channel-accumulation system between the basin and mountains, and forming multiple large-scale fan delta reservoirs in the lake basin, which provided favorable conditions for the formation of large-scale lithologic oil and gas reservoirs. The source rock was characterized by early oil generation and expulsion, and continuous oil charging, and the associated acidic fluids and hydrocarbon generation pressurization promoted the development of secondary pores such as intergranular and intragranular dissolution pores. The mature stage of source rock well matched with the development of reservoir, and conventional sandstone oil reservoir and shale oil reservoir were contiguously developed in the deep subsag area. The comprehensive analysis indicates that Kong 2 member in Cangdong deep subsag area has good exploration prospects, and multiple fan delta sand bodies developed in the basin margin have the advantage of near-source hydrocarbon accumulation, which shows a major replacement field for the large-scale reserve increase. Reference | Related Articles | Metrics

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Zhang Ying, Zhang Haitao Main controlling factors of hydrocarbon accumulation in Chang 8 1 Reservoir in Honghe Oilfield, Ordos Basin China Petroleum Exploration    2016, 21 (6): 73-80.   Abstract （869）   HTML    PDF （2229KB）（453）    Knowledge map    Save Based on core, wireline logging, mud logging, organic geochemical and production testing data, the main controlling factors of hydrocarbon accumulaiton in the Chang 81 reservoir of Yanchang Formation in the Honghe Oilfield were analyzed from the aspects of source rock, reservoir, cap rock and source-reservoir assemblage. The results show that lithologic oil reservoirs are dominant in the study area. The principal source rock is acted by the Zhangjiatan shale at the bottom of Chang 7 formation, where Type I organic matter is predominant with TOC of about 15%. This widely distributed source rock provides both material basis and migration dynamics for the formation of oil reservoirs. The Chang 8 1 reservoir in the study area is of low porosity and ultra-low permeability, and its physical properties are controlled jointly by sedimentation, diagenesis and micro-fracture reworking, which affect its oil-bearing potential accordingly. The thick mudstones in the mid-upper part of Chang 7 formation act as the physical and overpressure sealing cap rocks, providing good preservation conditions. The Zhangjiatan shale at the bottom of Chang 7 formation is in extensively direct contact with the Chang 8 1 reservoir, thus hydrocarbons are supplied in the shape of plane, which is the key to the hydrocarbon accumulation in the Chang 81 reservoir. Reference | Related Articles | Metrics

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Du Jinhu, He Haiqing, Pi Xuejun, Guo Xujie, Zhou Haimin, Zou Caineng, Zhang Yijie and Fang Xiang CNPC Obtained Strategic Discoveries and Successful Experience in Venture Exploration China Petroleum Exploration    2011, 16 (1): 1-9.   Abstract （712）   HTML       Knowledge map    Save Based on strategic and prospective exploration frontiers and targets, CNPC has established special investments and implemented venture exploration since 2005. After five years of discovery and practice, CNPC has made remarkable discoveries and breakthroughs in venture exploration for oil and gas in new areas and new frontiers, expanding the frontier of oil and gas exploration, deepening geologic understandings, and promoting technological progress. Meanwhile, CNPC has developed a series of effective and scientific organization and management systems and a number of effective methods in practice. CNPC's venture exploration in the past five years has played an important role in advancing its sustainable and effective development in domestic oil and gas exploration and maximizing oil and gas reserves. Related Articles | Metrics

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Gao Gang,Gang Wenzhe,Liang Hao and Jiao Lixin Weathering Effects on Source Rock Geochemical Characteristics: Taking Carboniferous –Lower Permian Source Rock in Turpan-Hami Basin for Instance    Abstract （445）   HTML       Knowledge map    Save Based on drilling of Carboniferous-Lower Permian and comparison of the organic geochemical characteristics of outcrop limestone and mudstone in Turpan-Hami Basin, this paper elaborates the influence of weathering effects on organic characteristics of source rock. The analysis indicates that organic abundance of mudstone is generally higher than that of limestone. So far as hydrocarbon source rock is concerned, mudstone is better than limestone thanks to the different sedimentary environment and material sources. The conserving conditions for samples of fi eld outcrops are apparently poorer than those samples of source rock in the deep layers of the basin. If the samples from the same strata and the same lithology become different, at the drilling and outcropping, this phenomenon is related to weathering effects. Weathering effects can exert infl uence on total components of dissoluble organic matters and hydrocarbon content of middle and lower molecules, causing more serious damage on dissoluble organic matters than solid dissoluble organic matters. As compared to limestone, mudstone can more strongly resist weathering effects. Related Articles | Metrics

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Shou Jianfeng, Zhu Guohua, ZhangHuiliang, ChenZiliao, SiChunsong, WangXin and WangShaoyi China Petroleum Exploration    2004, 9 (5): 31-39,2.   Abstract （160）   HTML       Knowledge map    Save Related Articles | Metrics

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Wu Jin, Liu Zhanguo, Zhu Chao, Gong Qingshun, Xia Zhiyuan, Song Guangyong, Wang Bo Characteristics of deep tight sandstone reservoirs and their controlling factors in the Middle-Lower Jurassic in the Yiqikelike area, Kuqa depression China Petroleum Exploration    2020, 25 (6): 58-67.   DOI: 10.3969/j.issn.1672-7703.2020.06.006 Abstract （620）   HTML    PDF （2267KB）（873）    Knowledge map    Save Deep tight sandstone reservoirs in the Middle-Lower Jurassic in the Yiqikelike area, Kuqa depression in the Tarim Basin, are characterized by complex diagenesis, strong heterogeneity, and poor understandings of reservoir characteristics and genesis. This paper analyzes the diagenetic evolution stages of these reservoirs and the factors controlling their physical properties in detail, using analysis methods such as casting thin section, Scanning Electron Microscope (SEM), physical property analysis, X-ray diffraction, and CT scanning. The results of previous research are combined, including regional stratigraphic burial history, paleo-geothermal history, Ro evolution history, and sedimentary facies. The results show that: (1) The reservoirs in the Middle-Lower Jurassic are characterized by low compositional maturity, high content of plastic litho-clast, and medium textural maturity. (2) The burial depth of the reservoirs is mainly 4,0005,000 m. The reservoir spaces are dominated by secondary dissolution pores and fractures, with average porosity of 7.21% and average permeability of 9.15 mD, which represents a low porosity and low permeability reservoirs. However, some reservoirs have high permeability due to the development of tectonic fractures. (3) The diagenetic evolution of the reservoirs can be divided into two stages. The first stage occurred before the Neogene and had two prominent features. One was burial compaction during initial sedimentation, which led to porosity reduction. The other is dissolution by humic acid during long-term shallow burial, which led to porosity increment. The second stage occurred after the Neogene. Diagenesis in this stage also had two particular features. One was lateral compaction of reservoirs during rapid burial, which led to porosity reduction. The other was cementation by large amounts of illite, generated at the same time, which also decreased porosity. Permeability of the reservoirs was improved by the development of large numbers of fractures. (4) The main factors controlling the physical properties of high-quality reservoirs are the hydrodynamic conditions during sedimentation, late diagenesis, and the tectonic compression. Sandstones developed in the sedimentary microfacies of coarse sand-braided river channels, and underwater distributary channels are rich in rigid grains such as quartz which have strong compression resistance, providing the sedimentary basis for the formation of high-quality reservoirs. The development of fractures has greatly improved reservoir permeability in the study area and is the main controlling factor for the development of high-quality reservoirs. Reference | Related Articles | Metrics

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Liang Shijun, Luo Quansheng, Kang Jilun, Li Fulei, Ma Qiang, Wang Xuechun, Peng Yazhong, Zhang Wei Breakthrough and significance of risk exploration in Well Satan 1 in Jinan Sag, Junggar Basin China Petroleum Exploration    2021, 26 (4): 72-83.   DOI: 10.3969/j.issn.1672-7703.2021.04.006 Abstract （602）   HTML    PDF （13747KB）（12）    Knowledge map    Save Recently, Well Satan 1, a risk exploration well of PetroChina, obtained high yield oil flow of the Permian Jingjingzigou Formation during the well test, achieving a major breakthrough in the exploration of lithologic reservoir in Jinan Sag in the footwall of Fukang fault zone , Junggar Basin. Based on the drilling results of Well Satan 1, hydrocarbon accumulation conditions in the east segment of Fukang fault zone are systematically studied and summarized, exploration prospects evaluated, and exploration targets put forward in Jinan Sag. The study shows that Jinan Sag is separated from Jimsar Sag by a bulge, and it is an independent hydrocarbon rich sag with great exploration prospect. The thick mature source rocks are deposited, laying the material basis for large-scale hydrocarbon accumulation. Controlled by ancient landform, two sets of largescale reservoirs of Middle and Upper Permian are developed in the slope and sag area, with similar distribution pattern and large thickness,possessing the reservoir conditions for forming large-scale lithologic-stratigraphic oil and gas reservoirs. The comprehensive analysis indicates that there are mainly two types of oil reservoirs in Jinan Sag: One is shale oil and gas reservoir of self-generation and self-storage type of Lucogou Formation. Among them, shale oil is mainly accumulated in relatively stable area, and distributed extensively and continuously in the foot wall of Fukang fault zone; The shale gas is mainly accumulated in the upper wall of Fukang fault zone, where was deeply buried in the early stage and uplifted strongly in the late stage. It is characterized by structural gas reservoir at present due to the high-maturity source rocks and affected by the damage and adjustment in the late stage. The other type is conventional sandstone oil reservoir of lower-generation upperstorage or upper-generation lower-storage types configurated by source rock of Lucaogou Formation and reservoirs of the Jurassic Badaowan Formation, Triassic Jiucaiyuan Formation, and Permian Wutonggou and Jingjingzigou Formations. The Yanshanian faults play a decisive role on the accumulation of oil reservoir, with the pattern of “fault communication, lateral adjustment, lithologic reservoir dominant and fault cutting”. Well Satan 1 opens the prelude of stereoscopic exploration in the east segment of Fukang fault zone, and replacement field of multilayer system with hundred-million-ton-level, which is a major breakthrough for benefit exploration and large-scale reserve increase in the eastern Junggar Basin. Reference | Related Articles | Metrics

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Tao Shizhen, Zou caineng and Yuan Xuanjun Application of Fluid Inclusion in Oil-gas Exploration China Petroleum Exploration    2006, 11 (4): 46-51,1.   Abstract （281）   HTML       Knowledge map    Save Based on matrix mineral, diagenetic sequence and fluid inclusions, are tested homotemprature, salinity and fluorescence of inclusions which coexist with hydrocarbon inclusions. The depth and geological age of oil inpouring are ascertained by combining with paleotemperature grad and sedimentary burial history. Inclusion analysis indicates that Fuxin uplift and Changling sag separate away aftermajor reservoir-forming stage of Fuyu oil layer, i.e. oil inpouring and reservoir-forming take place before Fuxin uplift upheaved in great force. The reservoir-forming of Fuyu oil layer includes two stages, i.e.the later Nenjiang period and later Mingshui period in Cretaceous. Inclusion study demonstrates oil reservoir being featured by up-source and down-storage, local-storage and verticalmigration. It is clarified that the source of Fuyu oil layer might originate anciently from Changling sag. Synchronously, it is pointed out that the "sweet point" controlled by source rock, overpressure, fault and sandbody are advantageous regions for oil exploration in the future Related Articles | Metrics

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Ye Deliao Petroleum Resources and Exploration Potential in Southeast Asia China Petroleum Exploration    2005, 10 (1): 55-60,64,3.   Abstract （229）   HTML       Knowledge map    Save Southeast Asia is one of the important oil and gas producing regions in the world. There are more than 100 sedimentary basins in this region. Currently, oil and gas are found in 47 basins. The ultimate oil and natural gas reserves in Southeast Asia are 233.7 × 108t and 26.5 × 1012m3, accounting for 7.5 percent and 8.1 percent of the world's total respectively. The nations with great petroleum exploration potential include Indonesia, Thailand, Myanmar and Brunei Related Articles | Metrics

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Hou Qijun, He Haiqing, Li Jianzhong, Yang Tao Recent progress and prospect of oil and gas exploration by PetroChina Company Limited China Petroleum Exploration    2018, 23 (1): 1-13.   DOI: 10.3969/j.issn.1672-7703.2018.01.001 Abstract （3265）   HTML    PDF （3448KB）（912）    Knowledge map    Save In recent two years, PetroChina Company Limited (hereinafter referred to as PetroChina for short) has made 12 important exploration progresses in domestic oil and gas exploration in clastic rocks, marine carbonate rocks, foreland thrust belts, lacustrine carbonate rocks, mature fields and unconventional oil and gas fields. Based on comprehensive analysis of PetroChina own oil and gas resources, remaining oil and gas resources and their exploration degree, and the influence of geological understanding and exploration technology on oil and gas exploration, this paper concludes that the prospect of domestic oil and gas exploration is still promising, but also faces many challenges, such as complex underground conditions, deeper burial depths and poorer quality of remaining resources. In the future, on the assumption of long-term low oil prices, PetroChina will adhere to the strategies of resources and innovation, follow the principle of efficient exploration, focus on "four types of exploration" and strengthen "three fields of innovation", so as to make new discoveries and breakthroughs in oil and gas exploration for sustainable and steady development. Reference | Related Articles | Metrics

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Fu Jinhua, Fan Liyong, Liu Xinshe, Hu Xinyou, Li Jihong, Ji Haikun New progresses, prospects and countermeasures of natural gas exploration in the Ordos Basin China Petroleum Exploration    2019, 24 (4): 418-430.   DOI: 10.3969/j.issn.1672-7703.2019.04.002 Abstract （1417）   HTML    PDF （3519KB）（827）    Knowledge map    Save The Ordos Basin has always been one of the key oil & gas exploration and development areas in China. And in the Ordos Basin, some important oil and gas fields have been discovered. As the exploration continues, the exploration objects turn to the areas with complex hydrocarbon accumulation conditions, e.g. tight zones, deep zones and basin peripheries, and the difficulty in searching for new large-scale monoblock reserves increases. The Changqing Oilfield Company’s new cognitions and progresses in the fields of tight sandstone gas and marine carbonate gas in recent years were summarized systematically, and the main geological characteristics and control factors of different types of gas reservoirs in the Ordos Basin were analyzed. Then, based on the distribution situations of oil and gas resources and the basic characteristics of newly discovered gas reservoirs, the “two-step” development strategy of Changqing Oilfield Company was put forward scientifically. In addition, the future exploration replacement fields of carbonate gas, tight sandstone gas and unconventional natural gas (tight sandstone gas excluded) were pointed out. Finally, in view of the problems in the process of exploration and development, the corresponding countermeasures were formulated systematically by combining with production practice closely. In this way, the geologic researches are strengthened, the working concept is transformed actively, the technical researches were reinforced and the exploration-development integration and the geology-engineering integration are promoted so as to realize the large-scale efficient exploration and development of natural gas and provide the experience and reference for the exploration and development of similar basins. Reference | Related Articles | Metrics

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Sun Yu, Liao Yuan and Wang Zhenyun Fine Geology and Remaining Oil Distribution Study in Saertu Oilfield China Petroleum Exploration    2011, 16 (2): 39-43,86.   Abstract （274）   HTML       Knowledge map    Save With fine reservoir description of Pu I Formation of Beiyiquduandong in the Saertu Oilfield, this paper, through three-level research on the sedimentary microfacies, single sand body, and the internal point bar-level configuration, performs an in-depth analysis of the reservoir layer by layer, summarizes a set of effective and practical meandering river fine geologic research methods and processes, and rebuilds the reservoir cognition system. On this basis, this paper establishes a geological model, and conducts remaining oil research after polymer flooding. It is found that after flooding, remaining oil is mainly distributed at top of channel sand body, the imperfect injection-production part and the branching line; the distribution is dominated by rhythmic type, interbed-controlled type and the thin and poor reservoir type. Related Articles | Metrics