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shale oil resource evaluation with an improved understanding of free hydrocarbons:Insights from three-step hydrocarbon thermal desorption

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Geoscience Frontiers 2023年第6期14卷 464-477页

作者： Gang Yan Yao-Hui Xu Wang-Lin Xu Bin Bai Ying Bai Yun-Peng Fan Shan-Shan Li Ming Zhong Yan Liu Zhi-Yao Xu Cooperative Innovation Center of Unconventional oil and Gas Yangtze University(Ministry of Education&Hubei Province)Wuhan 430100China Hubei Key Laboratory of Petroleum Geochemistry and Environment Yangtze UniversityWuhan 430100China Research Institute of Petroleum Exploration and Development PetroChinaBeijing 100083China School of Energy and Resources China University of GeosciencesBeijing 100083China Suzhou Grand Energy Technology Co.Ltd Suzhou 215129China

The pyrolysis parameter S1,which indicates the amount of free hydrocarbons present in shale,is often underestimated due to hydrocarbon loss during sample handling and measurement processes.To remedy this issue,we strongly recommend an immediate three-step hydrocarbon thermal desorption(HTD)approach to be conducted on oil shale at the drilling site.This approach measures S_(g),S_(O),and S_(1)^(*),which refer to gaseous,light,and free hydrocarbons,respectively.The new shale oil content value,calculated from the total of these three parameters,is far more precise and reliable than traditional pyrolysis S1.Moreover,we thoroughly investigated the components and microscopic occurrence features of hydrocarbons thermally desorbed at three temperature stages using gas chromatography(GC)and X-ray microcomputed tomography(CT).For example,we selected Chang 7_(3)mud shale.Our experimental results irrefutably indicate that the ultimate shale oil content of poor resource rocks is significantly impacted by evaporative loss,with this effect being greater when the total organic carbon(TOC)is lower.Additionally,C_(1-5)and C_(1-7)hydrocarbons constitute almost all of S_(g)and S_(O),respectively.S_(g)and S_(O)are predominantly composed of C_(1-3)gaseous hydrocarbons,with a maximum proportion of 42.93%.In contrast,S_(1)^(*)contains a substantial amount of C_(16-31)hydrocarbons.A three-dimensional reconstruction model of an X-ray micro-CT scan shows that while the amount of shale organic matter greatly decreases from the frozen state to 300℃,the pore volume significantly increases,particularly between 90 and 300℃.The increased pore volume is mainly due to macropores and fractures.It is imperative to note that the shale oil triple-division boundaries must be adjusted based on more accurate oil content,although this would not affect the resource zones to which the samples already belong(ineffective,low-efficient,and enriched resources).In conclusion,we strongly advise conducting an immediate well-site analysis or utilizing preservation p

关键词： shale oil Hydrocarbon thermal desorption Resource evaluation Component Microscopic occurrence feature

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Mechanism of ultrasonic strengthening fluidity of low mature shale oil: A case study of the first member of Lucaogou Formation, western Jimusaer Sag, Northwest China

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Petroleum Science 2023年第6期20卷 3337-3347页

作者： Bo-Yang Wang Bo Liu Yun-Fei Cui Zi-Long Wang Key Laboratory of Continental shale Hydrocarbon Accumulation and Efficient Development Ministry of EducationNortheast Petroleum UniversityDaqing163318HeilongjiangChina No.203 Exploration Team Jilin Bureau of Coalfield GeologySiping136000JilinChina

The low mature shale oil resources of Lucaogou Formation in Jimusar Sag have a great potential, but the heavy oil quality limits large-scale economic development significantly. Ultrasonic is a typical representative of heavy oil viscosity reduction and anhydrous fracturing technology, and how to understand the action characteristics and mechanism of ultrasonic effect on reservoir is a critical issue to enhance shale oil production in the industrialized application of power ultrasonic. Therefore, the comparative experiments with different time of power ultrasonic loading were conducted to analyze the response mechanism of reservoir characteristics and the change of fluid mobility. The results indicate that the ultrasonic treatment is ameliorative to the pore-fracture structure, and the improvement degree is controlled by the mechanical vibration and cavitation of ultrasound. Generally, the location with weak cementation strength or relatively developed microcrack is preferred to pore expansion. After the ultrasonic treatment, the shale oil quality becomes lighter, and the transformation of shale oil from adsorbed to free, is accelerated due to enhanced fluidity. Pore-expanding effect and fluid mobility enhancement are essential aspects of the power ultrasonic loading to improve the recovery of low mature shale oil. The results of this study support the feasibility analysis of ultrasonic enhanced shale oil exploitation theoretically.

关键词： Ultrasonic shale oil Reservoir properties Mobility Recovery

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Spontaneous imbibition characteristics of shale oil reservoir under the influence of osmosis

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International Journal of Coal Science & Technology 2022年第5期9卷 48-58页

作者： Yuliang Su Qinghao Sun Wendong Wang Xincheng Guo Jilong Xu Guanqun Li Xiugang Pu Wenzhong Han Zhannan Shi Key Laboratory of Unconventional oil&Gas Development China University of Petroleum(East China)Ministry of EducationQingdao 266580China School of Petroleum Engineering China University of Petroleum(East China)Qingdao 266580China PetroChina Dagang oilfield Company Tianjin 300280China

The spontaneous imbibition(SI)process in shale oil reservoirs is not only infuenced by capillary force,but also by the osmotic pressure between the fracturing fuid and formation water in the nanopores media.In this study,experimental methods are used to investigate the mechanisms of osmosis in the SI,taking into account the presence of initial formation water in shale oil reservoirs.To investigate the efect of osmosis,SI experiments were performed on the fne-grained felsic shale of the Qikou sag of Dagang oilfeld.Low-feld NMR testers and high-precision electronic balances are utilized for the measuring of oil–water migration.The results show that,when Sw≠0,high-salinity fuid SI can be divided into four stages:initial imbibition stage,drainage stage,secondary imbibition stage and stationary stage;when Sw=0,there is no drainage stage of high-salinity fuid SI;when Sw≠0 or Sw=0,low-salinity fuid SI can be called the“osmosis-enhanced SI”;and we have found that“newly formed pores or microfractures”as well as reducing salinity can promote SI.This article presents a systematic study of SI of shale oil reservoirs under the infuence of osmosis,which provide useful information for reservoir numerical simulation and development program design.

关键词： shale oil Spontaneous imbibition Osmosis Water saturation Capillarity

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The key parameter of shale oil resource evaluation: oil content

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Petroleum Science 2022年第4期19卷 1443-1459页

作者： Min Wang Ming Li Jin-Bu Li Liang Xu Jin-Xu Zhang State Key Laboratory of shale oil and Gas Enrichment Mechanisms and Effective Development Beijing102206China SINOPEC Key Laboratory of Petroleum Accumulation Mechanisms WuxiJiangsu 214126China Shandong Provincial Key Laboratory of Deep oil and Gas QingdaoShandong 266580China School of Geoscience China University of Petroleum(East China)QingdaoShandong 266580China

The United States has become the world's largest oil producer of shale oil. China has abundant shale oil resources, but its resource potential has not yet been exploited. The core of the evaluation is the selection of parameters and their reliability. By combining the parameters of the shale oil resource evaluation, we investigated the key parameters in the evaluation model and reviewed the research results. The adsorption and retention of heavy hydrocarbons, loss of light hydrocarbons, and original oil saturation are key in the evaluation of shale oil resources. The adsorption and retention of heavy hydrocarbons can be determined by the pyrolysis, FID curve, and hydrocarbon generation kinetics of shale before and after extraction. The loss of light hydrocarbons mainly occurs in coring(change in temperature and pressure),sample treatment, which can be evaluated using the GC spectrum, rock pyrolysis, crude oil volume coefficient, mass balance, component hydrocarbon generation kinetics, and other methods. The original oil saturation evaluation includes indirect, direct, logging, and simulation methods. The most reliable parameters can be obtained by using the sealed or pressure-maintained coring immediately after thawing(without crushing), and the recovery of light hydrocarbon loss is critical for the resource evaluation of medium to high mature shale. Therefore, the experimental determination of shale oil content and the study of the influencing factors of the parameters should be strengthened.

关键词： shale oil oil content oil saturation Light hydrocarbon recovery Resource evaluation

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Molecular insight into the oil displacement mechanism of CO_(2) flooding in the nanopores of shale oil reservoir

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Petroleum Science 2023年第6期20卷 3516-3529页

作者： Xiao-Hu Dong Wen-Jing Xu Hui-Qing Liu Zhang-Xing Chen Ning Lu State Key Laboratory of Petroleum Resources and Engineering China University of PetroleumBeijing102249China MOE Key Laboratory of Petroleum Engineering China University of PetroleumBeijing102249China Department of Chemical and Petroleum Engineering University of CalgaryCalgaryAlbertaT2N 1N4Canada

With the increasing demand for petroleum,shale oil with considerable reserves has become an important part of global oil resources.The shale oil reservoir has a large number of nanopores and a complicated mineral composition,and the effect of nanopore confinement and pore type usually makes the effective development of shale oil challenging.For a shale oil reservoir,CO_(2) flooding can effectively reduce the oil viscosity and improve the reservoir properties,which can thus improve the recovery performance.In this study,the method of non-equilibrium molecular dynamics(NEMD)simulation is used to simulate the CO_(2) flooding process in the nanoscale pores of shale oil reservoir.The performance difference between the organic kerogen slit nanopore and four types of inorganic nanopores is discussed.Thus,the effects of nanopore type and displacement velocity on the nanoscale displacement behavior of CO_(2) are analyzed.Results indicate that the CO_(2) flooding process of different inorganic pores is different.In comparison,the displacement efficiency of light oil components is higher,and the transport distance is longer.The intermolecular interaction can significantly affect the CO_(2) displacement behavior in nanopores.The CO_(2) displacement efficiency is shown as montmorillonite,feldspar>quartz>calcite>kerogen.On the other hand,it is found that a lower displacement velocity can benefit the miscibility process between alkane and CO_(2),which is conducive to the overall displacement process of CO_(2).The displacement efficiency can significantly decrease with the increase in displacement velocity.But once the displacement velocity is very high,the strong driving force can promote the alkane to move forward,and the displacement efficiency will recover slightly.This study further reveals the microscopic oil displacement mechanism of CO_(2) in shale nanopores,which is of great significance for the effective development of shale oil reservoirs by using the method of CO_(2) injection.

关键词： Displacement behavior Nanopores NEMD simulation shale oil CO_(2) Kerogen

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Development characteristics and controlling factors of fractures in lacustrine shale and their geological significance for evaluating shale oil sweet spots in the third member of the Shahejie Formation in the Qikou Sag, Bohai Bay Basin

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PETROLEUM SCIENCE 2024年第2期21卷 791-805页

作者： Zeng, Xu Yang, Tao Feng, Jian-Wei Bian, Cong-Sheng Guan, Ming Liu, Wei Guo, Bing -Cheng Dong, Jin China Natl Petr Corp Res Inst Petr Explorat & Dev Beijing 100083 Peoples R China China Univ Petr Coll Geosci Beijing 102249 Peoples R China China Univ Petr Key Lab Petr Resources & Prospecting Beijing 102249 Peoples R China China Univ Petr Sch Earth Sci Qingdao 266400 Shandong Peoples R China

Natural fractures are critical for shale oil and gas enrichment and development. Due to the extremely high heterogeneity of shale, the factors controlling the formation of internal fractures, especially horizontal fractures, remain controversial. In this study, we integrate thin section analysis and microcomputed tomography (CT) data from several lacustrine shale samples from the third member (Es 3 ) of the Shahejie Formation, Qikou Sag, Bohai Bay Basin, to assess the fractures in detail. The goal is to reveal the development characteristics, controlling factors, and geological signi ficance for evaluating sweet spots in a shale oil play. The fractures in the Es 3 contain high -angle structural and horizontal bed-parallel fractures that are mostly shear and extensional. Various factors in fluence fracture development, including lithofacies, mineral composition, organic matter content, and the number of laminae. Structural fractures occur predominantly in siltstone, whereas bed-parallel fractures are abundant in laminated shale and layered mudstone. A higher quartz content results in higher shale brittleness, causing fractures, whereas the transformation between clay minerals contributes to the development of bedparallel fractures. Excess pore pressure due to hydrocarbon generation and expulsion during thermal advance can cause the formation of bed-parallel fractures. The density of the bed-parallel and structural fractures increases with the lamina density, and the bed-parallel fractures are more sensitive to the number of laminae. The fractures are critical storage spaces and flow conduits and are indicative of sweet spots. The laminated shale in the Es 3 with a high organic matter content contains natural fractures and is an organic-rich, liquid-rich, self-sourced shale play. Conversely, the siltstone, massive mudstone, and argillaceous carbonate lithofacies contain lower amounts of organic matter and do not have bed-parallel fractures. However, good reservoirs can form in these areas when structural fractures

关键词： Fractures Development characteristics Controlling factors shale oil Sweet spot MISSISSIPPIAN BARNETT shale MECHANICAL-PROPERTIES NATURAL FRACTURES ROCKS DEFORMATION ACCUMULATION SANDSTONES RESERVOIRS MIGRATION SYSTEMS

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Morphological classification and three-dimensional pore structure reconstruction of shale oil reservoirs: A case from the second member of Paleogene Kongdian Formation in the Cangdong Sag, Bohai Bay Basin, East China

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Petroleum Exploration and Development 2022年第5期49卷 1085-1097页

作者： FAN Yuchen LIU Keyu PU Xiugang ZHAO Jianhua China University of Petroleum(East China) Qingdao 266580China Laboratory for Marine Mineral Resources Qingdao National Laboratory for Marine Science and TechnologyQingdao 266071China PetroChina Dagang oilfield Company Tianjin 300280China

This study combines large volume three-dimensional reconstruction via focused ion beam scanning electron microscopy(FIB-SEM) with conventional scanning electron microscope(SEM) observation, automatic mineral identification and characterization system(AMICS) and large-area splicing of SEM images to characterize and classify the microscopic storage space distribution patterns and 3D pore structures of shales in the second member of the Paleogene Kongdian Formation(Kong 2) in the Cangdong Sag of the Bohai Bay Basin. It is shown that:(1) The Kong 2 Member can be divided into seven types according to the distribution patterns of reservoir spaces: felsic shale with intergranular micron pores, felsic shale with intergranular fissures, felsic shale with intergranular pores, hybrid shale with intergranular pores and fissures, hybrid shale with intergranular pores, clay-bearing dolomitic shale with intergranular pores, and clay-free dolomitic shale with intergranular pores.(2) The reservoir of the intergranular fracture type has better storage capacity than that of intergranular pore type. For reservoirs with storage space of intergranular pore type, the dolomitic shale reservoir has the best storage capacity, the hybrid shale comes second, followed by the felsic shale.(3) The felsic shale with intergranular fissures has the best storage capacity and percolation structure, making it the first target in shale oil exploration.(4) The large volume FIB-SEM 3D reconstruction method is able to characterize a large shale volume while maintaining relatively high spatial resolution, and has been demonstrated an effective method in characterizing the 3D storage space in strongly heterogeneous continental shales.

关键词： shale oil pore structure LV-FIB-SEM 3D reconstruction Paleogene Kongdian Formation Cangdong Sag Bohai Bay Basin

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Experimental evaluation of the salt dissolution in inter-salt shale oil reservoirs

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Petroleum Exploration and Development 2020年第4期47卷 803-809页

作者： YANG Zhengming LI Ruishan LI Haibo LUO Yutian CHEN Ting GAO Tiening ZHANG Yapu Institute of Porous Flow&Fluid Mechanics PetroChina Research Institute of Petroleum Exploration&DevelopmentBeijing 100083China University of Chinese Academy of Sciences Beijing 100493China Research Institute of Exploration and Development Jianghan Oilfield CompanyWuhan 430223China

By using salt dissolution experiment,imbibition experiment and high temperature and high pressure nuclear magnetic resonance(NMR)on-line test,the evaluation methods for salt dissolution of inter salt shale oil-bearing cores were established,and the effects of salt dissolution on spontaneous imbibition and permeability were analyzed.The intensity of salt dissolution is quantitatively evaluated by comparing the signal quantity and distribution characteristics of T2 spectrum(transverse relaxation time)measured at different times.In salt dissolution experiment,salt in the core is gradually dissolved as the injected water is continuously immersed in the core.The spontaneous imbibition experiment of inter-salt shale oil-bearing core can be divided into three stages:strong imbibition and weak salt dissolution,strong salt dissolution promoting imbibition,and weak salt dissolution and weak imbibition.The salt dissolution in spontaneous imbibition is very obvious,and the salt dissolution contributes more than 60%of recovery.The micro-pore structure in different cross sections or different parts of inter-salt shale oil-bearing core isn’t uniform,and the pore volume,porosity and permeability increase after salt dissolution.

关键词： shale oil salt dissolution imbibition physical simulation nuclear magnetic resonance

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Hydraulic fracture geometry and proppant distribution in thin interbedded shale oil reservoirs

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Petroleum Exploration and Development 2022年第5期49卷 1185-1194页

作者： ZOU Yushi SHI Shanzhi ZHANG Shicheng LI Jianmin WANG Fei WANG Junchao ZHANG Xiaohuan State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China Engineering Technology Research Institute PetroChina Xinjiang Oilfield CompanyKaramay 834000China

Small-scale true triaxial sand fracturing experiments are conducted on thin interbedded shale samples made from cores of Permian Lucaogou Formation shale oil reservoir in Jimsar sag, Junggar Basin, NW China. Combined with high-precision CT scanning digital core model reconstruction technology, hydraulic fracture geometry and proppant distribution in thin interbedded shale oil reservoirs are studied. The research shows that: In thin interbedded shale oil reservoir, the interlayer difference of rock mechanics and the interlayer interface near the wellbore cannot restrain the growth of fracture height effectively, but has a significant impact on the fracture width distribution in the fracture height direction. Hydraulic fractures in these reservoirs tend to penetrate into the adjacent layer in “step-like” form, but have a smaller width at the interface deflection, which hinders the transport of proppant in vertical direction, resulting in a poor effect of layer-crossing growth. In shale layers with dense laminae, hydraulic fractures tend to form “丰” or “井” shapes. If the perforated interval is large in rock strength and high in breakdown pressure, the main fracture is fully developed initially, large in width, and supported by enough sand. In contrast, if the perforated interval is low in strength and rich in laminae, the fracturing fluid filtration loss is large, the breakdown pressure is low, the main fracture will not open wide initially, and likely to have sand plugging. Proppant is mainly concentrated in the main hydraulic fractures with large width near the perforated layer, activated laminae, branch fractures and fractures in adjacent layers contain only a small amount of(or zero) proppant. The proppant is placed in a limited range on the whole. The limit width of fracture that proppant can enter is about 2.7 times the proppant particle size.

关键词： shale oil thin interbedded reservoir rock mechanics lithologic interface hydraulic fracturing fracture shape proppant distribution

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Characteristics and genesis of tuffaceous shale oil lithofacies:A case study of Lucaogou Formation in Santanghu Basin

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Petroleum Research 2024年第1期9卷 37-47页

作者： Dongsheng Xiao Xiong fei Xu Jilun Kang Yiting Zhang PetroChina Tuha oilfield Company Exploration and Development Research Institute China

Lucaogou Formation in the Santanghu Basin is a special lacustrine fine-grained sedimentary deposits rich in volcanic debris and carbonate,with abundant shale oil resources.However,understanding of shale oil characteristics and genesis remains unclear.Lithofacies,sedimentary environment,and formation mechanisms of tuffaceous shale oil are investigated based on core and thin section observations,X-ray diffraction,field emission SEM and geochemical analysis.Results show that three mixed lithofacies types are developed in Lucaogou Formation:blocky tuff,laminated tuffaceous dolomite,and laminated dolomitic tuff.These lithofacies types are characterized by high content of felsic and dolostone,widespread organic matter,and low clay content.Formation of tuffaceous shale oil sweet spots is primarily influenced by four factors:inputting of volcanic ash as a high-quality source rocks and reservoirs provides good material basis;devitrification of volcanic glass,calcitization,and dissolution are crucial for formation of reservoirs;expulsion of source rocks with high-abundance organic matter expulsion facilitates migration and accumulation of hydrocarbon in adjacent reservoirs;fracture development improves reservoir permeability to form highly productive sweet spots.By analyzing characteristics and genesis of tuffaceous shale oil,the main controlling factors of reservoir physical property and oil saturation are clarified,which is of great significance for selection of shale oil exploration zones.

关键词： shale oil Tuffaceous Formation mechanism Lucaogou formation Santanghu basin

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