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Study of the Transport Behavior of Multispherical Proppant in Intersecting Fracture Based on Discrete Element Method

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Energy Engineering 2025年第1期122卷 185-201页

作者： Chengyong Peng JianshuWu Mao Jiang Biao Yin Yishan Lou CNOOC Research Institute company Limited Beijing100028China School of Petroleum Engineering Yangtze UniversityWuhan430100China Hubei Key Laboratory of oil and gas Drilling and Production Engineering(Yangtze University) Wuhan430100China

To analyze the differences in the transport and distribution of different types of proppants and to address issues such as the short effective support of proppant and poor placement in hydraulically intersecting fractures,this study considered the combined impact of geological-engineering factors on *** reservoir production parameters and the discrete elementmethod,multispherical proppants were ***,a 3D fracture model,based on the specified conditions of the L block,employed coupled(Computational Fluid Dynamics)CFD-DEM(Discrete ElementMethod)for joint simulations to quantitatively analyze the transport and placement patterns of multispherical proppants in intersecting *** indicate that turbulent kinetic energy is an intrinsic factor affecting proppant ***,the efficiency of placement and migration distance of low-sphericity quartz sand constructed by the DEM in the main fracture are significantly reduced compared to spherical ceramic proppants,with a 27.7%decrease in the volume fraction of the fracture surface,subsequently affecting the placement concentration and damaging fracture *** to small-angle fractures,controlling artificial and natural fractures to expand at angles of 45°to 60°increases the effective support length by approximately 20.6%.During hydraulic fracturing of gas wells,ensuring the fracture support area and post-closure conductivity can be achieved by controlling the sphericity of proppants and adjusting the perforation direction to control the direction of artificial fractures.

关键词： Hydraulic fracturing discrete element method proppant sphericity CFD-DEM

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A Model of Hydrothermal Dolomite Reservoir Facies in Precambrian Dolomite, Central Sichuan Basin, SW China and its Geochemical Characteristics

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Acta Geologica Sinica(English Edition) 2019年第1期93卷 130-145页

作者： GU Yifan ZHOU Lu JIANG Yuqiang JIANG Chan LUO Mingsheng ZHU Xun School of Geosciences & Technology Southwest Petroleum University exploration Division PetroChina Southwest Oil & Gas Field Company Shunan Division of Petrochina Southwest oil&gas Field company exploration and Development Institute of Southwest oil&gas Field company PetroChina

Hydrothermal mineral assemblages and related hydrothermally enhanced fracturing are common in the Precambrian Dengying Formation of Central Sichuan Basin. Petrographic and geochemical analyses of core samples show that the hydrothermal dolomite reservoirs of Dengying Formation consist of four main types of pores in the reservoir facies. These include: 1) hydrothermal dissolution vug(or pore), 2) intercrystalline pore, 3) residual inter-breccia vug(or pore), and 4) enlarged dissolved-fracture. There are three different fabrics dolomite in hydrothermal dolomite reservoirs, namely, saddle dolomite, fine-medium dolomite and micritic dolomite. Micritic dolomite is the original lithology of host rock. Saddle dolomite with curved or irregular crystal faces was directly crystallized from hydrothermal fluids(average temperature 192°C). Fine-medium dolomites are the products of recrystallization of micritic dolomite, resulting in abnormal geochemical characteristics, such as slight depletion of δ^(18)O, significant enrichment of Mn-Fe and ^(87)Sr/^(86)Sr, and positive Eu anomaly. A model for the distribution of various hydrothermal dolomite reservoir facies is proposed here, which incorporates three fundamental geological controls: 1) extensional tectonics and tectono-hydrothermal events(i.e., the Xingkai Taphrogenesis of Late Sinian-Early Cambrian, and Emei Taphrogenesis of Late Permian), 2) hydrothermal fluid storage in clastic rocks with large thickness(e.g., Nanhua System of Chengjiang Formation and part of Doushantuo Formation), and 3) confining bed for hydrothermal fluids(such as, the shale in Qiongzhusi Formation). The supply of hydrothermal fluid is critical. Large basement-rooted faults and associated grid-like fracture system may function as the channels for upward migration of hydrothermal fluid flow. The intersection of the above-mentioned faults(including the conversion fault), especially transtensional sags above negative flower structures on wrench faults can s

关键词： hydrothermal dolomite reservoir facies geochemical characteristics Precambrian Dengying Formation central Sichuan Basin

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The Newly Discovered Yanchang gas Field in the Ordos Basin, Central China

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Journal of Earth Science 2017年第2期28卷 347-357页

作者： Hairen Gao Weili Wang oil and gas exploration company Yanchang Petroleum (Group) Co. LTD

The Yanchang gas field is located in the Ordos Basin of central China to the southeast of the Yishan Slope, covers an exploration area of 2.6× 10~4 km^2 and has approximately 3.5× 10^（11） m^3 of gas reserves. The gas field is dominated by lithologic gas reservoirs but also has a few structural gas reservoirs. Sand bodies were deposited in the Carboniferous Benxi Formation around offshore barrier islands and in distributary channel fillings in the delta front of the P_1s_2 and P_1s_1 divisions of the Permian Shanxi Formation. The P_2h_8 division of the Shihezi Formation contains the main reservoirs. The depths of the reservoirs are between 1 970 and 3 500 m. The Yanchang gas field can be classified as a typical tight sandstone gas reservoir filed because its porosity is lower than 10% and permeability lower than 1 mD. The discovery and development of the Yanchang gas field has led to a great increase in total natural gas reserves in the Ordos Basin. Its exploration has improved methods of locating large gas fields in deep-water depositional environments in the south part of the basin.

关键词： Yanchang gas field Ordos Basin Central China tight gas reservoir lithologic reservoir gas in coal-bearing strata

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Formation mechanism of reservoir oolitic dolomite in Lower Triassic Feixianguan formation, northeastern Sichuan Basin, southwest China

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Journal of Central South University 2014年第8期21卷 3263-3274页

作者：陈培元谭秀成刘宏马腾罗冰姜兴福于洋靳秀菊 State Key Laboratory of oil and gas Geology and exploration (Southwest Petroleum University) School of Geoscience and Technology Southwest Petroleum University Research Institute of Petroleum exploration and Development Post-doctoral Workstation of PetroChina Southwest Oil and Gas Field Company Department of exploration Industry PetroChina Southwest Oil and Gas Field Company Research Institute of Petroleum exploration and Development SINOPECZhongyuan Oilfield Company

A series of marine natural gas fields were recently discovered in oolitic dolomites of the Lower Triassic Feixianguan formation, northeastern Sichuan Basin, southwest China. The mechanism forming these reservoir dolomites is debatable, limiting the ability to characterize these reservoir successfully. Based on the investigation of the representative Dukouhe, Luojiazhai, and Puguang areas, this issue was addressed by examining the distribution, petrology, and geochemistry of the dolomites, the most comprehensive study to date was provided. Dolomitization occurred at a very early stage of diagenesis, as shown by the petrological features of the rock fabric. Vadose silt, which is composed primarily of dolomitic clasts, is found in the primary and secondary pores of the oolitic dolomite. This indicates that the overlying strata were subjected to dolomitization when the Feixianguan formation was located in the vadose zone. Therefore, it may be inferred that the dolomitization which occurred before the formation was exposed to meteoric conditions. The spatial distribution and geochemical characteristics of the dolomite indicate that dolomitization occurred as a result of seepage reflux. The degree of dolomitization decreases with increasing distance from the evaporative lagoon. Furthermore, the type and porosity of the dolomite vary in different zones of the upward-shoaling sequence, with the porosity gradually decreasing from the highest layer to the lowest layer. This reflects a close relationship between dolomitization and seawater evaporation during the formation of the dolomite. Geochemical analysis provided further evidence for the relationship between the dolomitization fluid and the coeval seawater. The 87Sr/86Sr and 813C isotopes, as well as the abundances of trace elements, Fe and Mn, indicate that seawater concentrated by evaporation acted as the dolomitization fluid. These results also show that dolomitization most likely occurred in a semi-closed diagenetic e

关键词： Lower Triassic Feixianguan formation early exposure seepage reflux dolomitization Sichuan Basin northeastern Sichuan

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The Origin of Paleokarst in the Huanglong Formation of the Eastern Sichuan Basin:Evidence from δ^(13)C, δ^(18)O and ^(87)Sr/^(86)Sr

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Acta Geologica Sinica(English Edition) 2014年第6期88卷 1852-1862页

作者： CHEN Haoru ZHENG Rongcai WEN Huaguo LI Shilin LI Shuang ZHOU Gang WEN Longbin State Key Laboratory of oil and gas Reservoir Geology and Exploitation Chengdu University of Technology Chongqing gas District of Southwest oil and gas company of CNPC Petroleum exploration and Development Research Institute PetroC hina Southwest Oil and Gasfield Company

Karst rocks from the Huanglong Formation exposed at the margin of the Eastern Sichuan Basin can be divided into four types：slightly corroded, moderately corroded porous, intensely corroded brecciated and intensely corroded and replaced secondary calcic karstic rocks. The carbon, oxygen and strontium isotope compositions of the various karst rocks are analyzed systematically and compared to rocks without karst corrosion. The results indicate that（1） the Huanglong Formation in the eastern Sichuan Basin was a restricted bay supplied and controlled by freshwater in which mudmicrite and mud-dolomicrite exhibit low δ13C and δ18O values and high 87Sr/86 Sr ratios;（2） all types of karstic rocks in the paleokarst reservoirs of the Huanglong Formation in the research area are affected by atmospheric freshwater with the δ13C and δ18O values and 87Sr/86 Sr ratios in the original formation approaching those of atmospheric freshwater, which reflects ancient hydrological conditions, fluid properties, isotopic source and the fractionation effect;（3） the intensely corroded and replaced secondary limestone is affected by a variety of diagenetic fluids, often reflected by δ13C and δ18O values, while the 87Sr/86 Sr ratios exhibit the strong degree of the corrosion;（4） after comparing the 87Sr/86 Sr ratios of each type of karst rock, the diagenetic fluids are determined to be mainly atmospheric freshwater, and depending on the strength of corrosion, and the low 87Sr/86 Sr ratio fluids in the layer will participate in the karst process. The carbon, oxygen, and strontium isotopes of different karstic reservoirs can provide meaningful geochemical information for forecasting and evaluating the development and distribution rules of the Huanglong Formation at the margin of the eastern Sichuan Basin in time and space.

关键词： paleokarst reservoirs carbon and oxygen isotope strontium isotope geochemistry Huanglong Formation eastern Sichuan area

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Changing characteristics of ultralow permeability reservoirs during waterflooding operations

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Petroleum Science 2013年第2期10卷 226-232页

作者： Gao Chunning An Xiaoping Zhu Shengju Wu Pingcang National Engineering Laboratory for exploration & Development of Low Permeability oil and gas Fields exploration & Development Research Institute of Changqing oilfield company

The characteristics of ultralow permeability reservoirs changed after waterflooding. Thin- section analysis and scanning electron microscopy （SEM） of core samples from inspection wells indicated that calcite and barite were formed in ultralow permeability reservoirs during waterflooding operations. Some asphaltene precipitates on the surface of formation rock would influence the reservoir porosity, permeability, wettability, and electrical properties. In this paper, the changes of physical, electrical, and fluid properties of ultralow permeability reservoirs during waterflooding operations were analyzed. This provides important information to improve waterflooding performance in ultralow permeability reservoirs.

关键词： Ultralow permeability waterflooding reservoir change waterflooding characteristics

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Defining stratigraphic oil and gas plays by modifying structural plays:A case study from the Xihu Sag,east China Sea Shelf Basin

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Energy Geoscience 2021年第1期2卷 41-51页

作者： Feng Ding Chunyu Xie Xinghai Zhou Cen Jiang Kun Li Lifeng Wan Pei Zhang Huawei Niu Shanghai Offshore oil and gas exploration and Production company SINOPECShanghai200120China

The study focuses on an area of relatively mature oil and gas exploration located in the western slope of the Xihu Sag,East China Sea Shelf *** stratigraphic oil and gas plays are introduced to replenish the shrinking prospect inventory in the *** reservoirs of these plays are traditional pay intervals of the Eocene Pinghu Formation and Baoshi Formation composed of tide-dominated delta front,tidal flat and delta front sand bar *** investigating conventional seismic data,seismic inversion volumes,and well log data,multiple tidal-influenced delta front channels,beach sand packages have been mapped out in different reservoir sand intervals of the Pinghu Formation and Baoshi *** recognize four types of stratigraphic terminations:channel flank pinch-outs,axial pinch-outs of sand-fills,channel mouth sand bar pinch-outs,and onlap pinch-outs for the Baoshi *** the depositional facies and relatively low sand-shale ratio of the reservoir formations favor the occurrence of stratigraphic *** closure mechanism of all these plays are similar to the traditional structure plays in the area:fault blocks or fault-bounded rollover anticlines,except that one or more closing faults are replaced by these stratigraphic *** small-sized closures should exist but the relatively large ones are centered around a major intra-slope rise,raising the exploration potential in this maturely explored *** new exploration drilling campaign has so far tested the play of delta front channel facies,with three out of four wells commercially *** play concepts open up a novel approach to identify new traps in the study area and many other rift basins with similar settings in eastern China.

关键词： East China Sea Xihu Sag Stratigraphic play Pinghu Formation

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Basin-Scale Sand Deposition in the Upper Triassic Xujiahe Formation of the Sichuan Basin, Southwest China: Sedimentary Framework and Conceptual Model

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Journal of Earth Science 2013年第1期24卷 89-103页

作者：谭秀成夏青松陈景山李凌刘宏罗冰夏吉文杨家静 State Key Laboratory of oil and gas Geology and Exploitation Southwest Petroleum University School of Resource and Environment Southwest Petroleum University Research Institute of exploration and Development PetroChina Southwest Oil and Gas Field Company Branch of Shunan gas Field PetroChina Southwest Oil and Gas Field Company

The Upper Triassic Xujiahe （须家河） Formation in the Sichuan （四川） Basin, Southwest China is distinctive for the basin-scale sand deposition. This relatively rare sedimentary phenomenon has not been well interpreted. Here we addressed this issue by discussing sedimentary framework and conceptual model. Analysis of sedimentary setting implied that the basin received transgression during the deposition. It had multiple provenance supplies and river networks, as being surrounded by old- lands in multiple directions including the north, east and south. Thus, the basin was generally charac-terized by coastal and widely open and shallow lacustrine deposition during the Late Triassic Xujiahe period. This is similar to the modern well-known Poyang （鄱阳） Lake. Therefore, we investigated the framework and conceptual model of the Sichuan Basin during the Xujiahe period with an analogue to the Poyang Lake. Results show that the conceptual model of the deposition can be divided into transgressive and regressive stages. The first, third and fifth mem- bers of the formation are in transgressive stage and the deposits are dominated by shore and shallow lacustrine mud. In contrast, the deposition is mainly of braided river channel sand deposits during the regressive stage, mainly including the second, fourth and sixth members of the formation. The sand deposited in almost the entire basin because of the lateral migration and forward moving of the cross networks of the braided rivers. The multiple alternations of short and rapid transgression and relatively long regression are beneficial to the basin-scale sand deposition. Thus, the main channel of the braided river and its extensional areas are favorable for the development of hydrocarbon reservoir. This provides practical significance to the reservoir evaluation and exploration. In addition, the results also justify the relatively distinctive sedimentary phenomenon in the study area and may also have im- plications for understanding the

关键词： basin-scale sand deposition coastal and widely open lake sedimentary framework sedimentary conceptual model channel of braided river Upper Triassic Xujiahe Formation Sichuan Basin.

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Evaluation of Well Spacing for Primary Development of Fractured Horizontal Wells in Tight Sandstone gas Reservoirs

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Fluid Dynamics & Materials Processing 2024年第5期20卷 1015-1030页

作者： Fang Li Juan Wu Haiyong Yi Lihong Wu Lingyun Du Yuan Zeng exploration and Development Research Institute PetroChina Southwest Oil&Gas Field CompanyChengdu610041China oil and gas Resources Department PetroChina Southwest Oil&Gas Field CompanyChengdu610000China

Methods for horizontal well spacing calculation in tight gas reservoirs are still adversely affected by the complexity of related control factors,such as strong reservoir heterogeneity and seepage *** this study,the stress sensitivity and threshold pressure gradient of various types of reservoirs are quantitatively evaluated through reservoir seepage *** the basis of these experiments,a numerical simulation model(based on the special seepage mechanism)and an inverse dynamic reserve algorithm(with different equivalent drainage areas)were *** well spacing ranges of Classes I,II,and III wells in the Q gas field are determined to be 802–1,000,600–662,and 285–400 m,respectively,with their average ranges as 901,631,and 342.5 m,*** considering both the pairs of parallel well groups and series well groups as examples,the reliability of the calculation results is *** is shown that the combination of the two models can reduce errors and provide accurate results.

关键词： Well spacing for primary development tight gas reservoir fractured horizontal well threshold pressure gradient stress sensitivity

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gas accumulation conditions and key technologies for exploration & development of Sinian and Cambrian gas reservoirs in Anyue gasfield

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Petroleum Research 2018年第3期3卷 221-238页

作者： Yueming Yang Yu Yang Guang Yang Jiarong Song LongWen Chuanguang Deng Maolong Xia Qi Ran Guobin Duan Bing Luo Bing Xie PetroChina Southwest oil&gas Field company Sichuan610051China Research Institute of exploration and Development PetroChina Southwest Oil&Gas Field CompanySichuan610051China exploration Division PetroChina Southwest Oil&Gas Field CompanySichuan610051China Chongqing Shale gas exploration and Development Co. Ltd.Chongqing400023China

exploration of the Sinian-Lower Paleozoic formations in the Sichuan Basin starts from the 1950s,and is tortuous and *** summarize the exploration experiences is of great significance of reference for exploration of oil and gas in deep carbonate rocks of the Sichuan *** accumulation in the Anyue oversize gasfield is chiefly controlled by the Deyang-Anyue intra-platform rift and central Sichuan *** intra-platform rift controls the scale hydrocarbon generation center and effective hydrocarbon *** Anyue gasfield is characterized by near-source hydrocarbon *** marginal zone of intra-platform rift and high part of the paleouplift control the scale distribution of favorable facies belts of reservoir development,and overlapped by paleokarstic reformation,the reservoirs are widely *** intra-platform rift and paleouplift jointly control formation of the scale traps and hydrocarbon *** reservoir features and major controlling factors for hydrocarbon accumulation have some differences in the main play strata,such as Longwangmiao Formation,and Member 4 and Member 2 of Dengying *** gas reservoir in the Longwangmiao Formation is a lithologic gas reservoir under the tectonic setting,and the inherited paleouplift is a key for reservoir formation and hydrocarbon *** gas reservoir in the Member 4 of Dengying Formation is mainly controlled by large structural-stratigraphic composite traps,and the gas reservoir in the Member 2 of Dengying Formation is the structural *** of the large gasfields in the Dengying Formation is controlled by the intra-platform rift,near-source hydrocarbon-reservoir configuration controlled by the ancient erosion plane and stratigraphic sealing in the updip *** exploration and development of the Anyue gasfield,four series of technologies are developed,namely,reservoir seismic fine description technology,well logging fine evaluation technology of gas

关键词： Anyue gasfield Dengying Formation Longwangmiao Formation gas reservoir feature Enrichment regularity exploration and development technology

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