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co.trolling factors for oil production in co.tinental shales:A case study of Cretaceous Qingshankou Formation in Songliao Basin

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Petroleum research 2023年第2期8卷 183-191页

作者： Bo Zhou Yuxiang Xiao Zhengdong Lei Rui Wang Shuiqing Hu Xiulin Hou PetroChina research institute of Petroleum exploration&development Beijing100083China Exploration and Development Research Institute of Daqing Oilfield Co. Ltd.Daqing163712China

co.tinental shale oil is widely distributed in the Cretaceous Qingshankou Formation of the Songliao Basin in Northeast China.In the Qijia-Gulong sag and the Changling sag in the Songliao Basin,breakthroughs of shale oil exploration and development have been made in the first and seco.d members of the Qingshankou Formation,and several wells represented byWell GYYP1 have achieved high and stable shale oil production.However,some horizontal wells in shale oil development pilot test(Well groups A and D)were characterized by low shale oil production,high flowback rate and rapid production decline.Therefore,co.trolling factors of the shale oil production were investigated.The results show that shale oil enrichment area and optimal sweet spots are fundamental for high shale oil production,improving horizontal length and drilling ratio of sweet spots is a technical guarantee for enhancing shale oil production of single well,and artificial fracture network(incl.scale,co.plexity,and co.pling with preexisting geological bodies)created by fracturing is a direct factor for co.trolling the shale oil production.For subsequent exploration and development of the shale oil,the heterogeneity of sweet spot distribution should be carefully co.sidered,the shale oil enrichment areas and optimal sweet spots also need be optimized,and the wellbore trajectory co.trol and fine geological modeling techniques should be figured out.Moreover,the fracturing techniques suitable for the shale with high clay mineral co.tent and weak brittleness should be developed,and the personalized and differentiated staged fracturing also needs to be performed,to effectively enhance single-well shale oil production and estimated ultimate reco.ery.

关键词： co.tinental shale Shale oil production Heterogeneity Drilling ratio of sweet spot Fracture network Qingshankou formation Songliao Basin

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Calculation of oil saturation in clay-rich shale reservoirs:A case study of Qing 1 Member of Cretaceous Qingshankou Formation in Gulong Sag,Songliao Basin,NE China

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Petroleum exploration and development 2022年第6期49卷 1351-1363页

作者： LI Chaoliu YAN Weilin WU Hongliang TIAN Han ZHENG Jiandong YU Jun FENG Zhou XU Hongjun research institute of Petroleum exploration and development PetroChinaBeijing 100083China Exploration and Development Research Institute of Daqing Oilfield Co.Ltd. Daqing 163712China

The targeted reservoir,which is referred as the first member of Cretaceous Qingshankou Formation in Gulong Sag,Songliao Basin,NE China,is characterized by the enrichment of clay and lamellation fractures.Aiming at the technical challenge of determining oil saturation of such reservoir,nano-pores were accurately described and located through focused ion beam scanning electron microsco.y and quantitative evaluation of minerals by scanning electron microsco.y based on Simandoux model,to co.struct a 4D digital co.e frame.Electrical parameters of the shale reservoir were determined by finite element simulation,and the oil saturation calculation method suitable for shale was proposed.co.parison between the results from this method with that from real co.e test and 2D nuclear magnetic log shows that the absolute errors meet the requirements of the current reserve specification in China for clay-rich shale reservoir.co.parison analysis of multiple wells shows that the oil saturation values calculated by this method of several points vertically in single wells and multiple wells on the plane are in agreement with the test results of co.e samples and the regional deposition pattern,proving the accuracy and applicability of the method model.

关键词： shale oil digital co.e well log interpretation oil saturation Qingshankou Formation Gulong Sag Songliao Basin

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Reservoir-forming co.ditions and key exploration & development techniques for Xushen gas field in Northeast China

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Petroleum research 2019年第2期4卷 125-147页

作者： Fenglan Wang Yongzhuo Wang Xuemin Zhou Changhai Yin Ping Shu Baojun Cao Yingkang Zhu exploration and development research institute Daqing Oilfield Co.Ltd.Daqing163712China

exploration and development of volcanic gas reservoirs is a world-class problem,and less experience can be learned at home and abroad.Through study of reservoir-forming co.ditions of Xushen gas field,four sets of hydrocarbon source rocks,mainly mudstone and co.l seam of Shahezi Formation,are identified in this gas field;its cap rocks are mudstone in Member 2 of Denglouku Formation,and Member 1 and Member 2 of Quantou Formation.By simulating reservoir-forming history,four filling periods of the Xushen gas field are determined,and the most favorable exploration targets are crater areas with structural highs,large thickness and good physical properties.On the basis of diagenetic mechanism study,the criteria of sequence series,lithology identification and reservoir types of gas reservoirs have been established;the volcanic rock bodies have been carefully depicted and the distribution laws of effective reservoirs of gas pools have been figured out.Based on evaluating reservoir-permeability characteristics of reservoirs,the gas well productivity characteristics(mainly type II,III and IV wells)have been identified,and the optimum design technology for volcanic gas reservoir development has been developed.The gas reservoirs in all blocks of Xushen gas field are classified into three types:singlebody gas reservoir model,disco.nected multi-body gas reservoir model and interco.nected multi-body gas reservoir model.Stimulation technologies,including multi-layer fracturing of vertical well,staged fracturing of open-hole horizontal well and volume fracturing,have been developed.Acco.ding to gas well production performance,pressure change,well-co.trolled reserves and spatial distribution of volcanic bodies,co.bined with numerical simulation and prediction of gas reservoirs,the evaluation method of residual potential of volcanic gas reservoirs has been formed.Key technologies for effective exploration and development of co.plex volcanic gas reservoirs have been established and perfected,and bring good development effect.The rese

关键词： Xushen gas field Reservoireforming co.ditions Volcanic rock development Productivity Optimum design

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Practice and development suggestions of hydraulic fracturing technology in the Gulong shale oil reservoirs of Songliao Basin, NE China

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Petroleum exploration and development 2023年第3期50卷 688-698页

作者： LIU He HUANG Youquan CAI Meng MENG Siwei TAO Jiaping PetroChina research institute of Petroleum exploration&development Beijing 100083China PetroChina daqing oilfield co. Ltd.Daqing 163002China

This paper reviews the multiple rounds of upgrades of the hydraulic fracturing technology used in the Gulong shale oil reservoirs and gives suggestions about stimulation technology development in relation to the production performance of Gulong shale oil wells.Under the co.trol of high-density bedding fractures,fracturing in the Gulong shale results in a co.plex fracture morphology,yet with highly suppressed fracture height and length.Hydraulic fracturing fails to generate artificial fractures with sufficient lengths and heights,which is a main restraint on the effective stimulation in the Gulong shale oil reservoirs.In this regard,the fracturing design shall follow the strategy of"co.trolling near-wellbore co.plex fractures and maximizing the extension of main fractures"Increasing the proportions of guar gum fracturing fluids,reducing perforation clusters within one fracturing stage,raising pump rates and appropriately exploiting stress interference are co.ducive to fracture propagation and lead to a co.siderably expanded stimulated reservoir volume(SRV).The upgraded main hydraulic fracturing technology is much more applicable to the Gulong shale oil reservoirs.It accelerates the oil production with a low flowback rate and lifts oil cut during the initial production of well groups,which both help to improve well production.It is suggested to optimize the hydraulic fracturing technology in six aspects,namely,suppressing propagation of near-wellbore microfractures,improving the pumping scheme of co.(2),managing the perforating density,enhancing multi-proppant co.bination,reviewing well pattern/spacing,and discreetly applying fiber-assisted injection,so as to improve the SRv,the distal fracture co.plexity and the long-term fracture co.ductivity.

关键词： co.tinental shale oil Songliao Basin Gulong shale oil horizontal well hydraulic fracturing reservoir stimulation stimulated reservoir volume

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Evolution features of in-situ permeability of low-maturity shale with the increasing temperature,Cretaceous Nenjiang Formation,northern Songliao Basin,NE China

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Petroleum exploration and development 2022年第3期49卷 516-529页

作者： HE Wenyuan MENG Qi'an LIN Tiefeng WANG Rui LIU Xin MA Shengming LI Xin YANG Fan SUN Guoxin daqing oilfield co.Ltd. PetroChinaDaqing 163712China Exploration and Development Research Institute of Daqing Oilfield Co.Ltd. Daqing 163712China Heilongjiang Provincial Key Laboratory of Shale Oil&Tight Oil Accumulation Daqing 163712China

Temperature-triaxial pressure permeability testing at the axial pressure of 8 MPa and co.fining pressure of 10 MPa,closed shale system pyrolysis experiment by electrical heating and scanning electron microsco.y analysis are used to study the evolution mechanism of in-situ permeability in the direction parallel to bedding of low-maturity shale from Member 2(K_(2)n_(2))of Cretaceous Nenjiang Formation in northern Songliao Basin with mainly Type I kerogen under the effect of temperature.With the increasing temperature,the in-situ permeability presents a peak-valley-peak tendency.The lowest value of in-situ permeability occurs at 375℃.Under the same temperature,the in-situ permeability decreases with the increase of pore pressure.The in-situ permeability evolution of low-maturity shale can be divided into 5 stages:(1)From 25℃to 300℃,thermal cracking and dehydration of clay minerals improve the permeability.However,the value of permeability is less than 0.01×10^(-3)μm^(2).(2)From 300℃to 350℃,organic matter pyrolysis and hydrocarbon expulsion result in mineral intergranular pores and micron pore-fractures,these pores and fractures form an interco.nected pore network at limited scale,improving the permeability.But the liquid hydrocarbon,with high co.tent of visco.s asphaltene,is more difficult to move under stress and more likely to retain in pores,causing slow rise of the permeability.(3)From 350℃to 375℃,pores are formed by organic matter pyrolysis,but the adsorption swelling of liquid hydrocarbon and additional expansion thermal stress co.strained by surrounding stress co.press the pore-fracture space,making liquid hydrocarbon difficult to expel and permeability reduce rapidly.(4)From 375℃to 450℃,the interco.nected pore network between different mineral particles after organic matter co.version,enlarged pores and transformation of clay minerals promote the permeability to increase co.stantly even under stress co.straints.(5)From 450℃to 500℃,the stable pore system and crossed fracture system in different bedding direct

关键词： Songliao Basin Cretaceous Nenjiang Formation low-maturity shale in-situ co.version pore-fracture structure in-situ permeability shale oil

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Calculating the formation period of fault lateral sealing and its application

Energy Geoscience

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Energy Geoscience 2022年第1期3卷 17-22页

作者： Fu Guang Fan Zili Fu Hongjun Zhang Yutianyi Qiao Hongliang School of Earth Sciences of Northeast Petroleum University HeilongjiangDaqing163318China Exploration and Development Research Institute of Daqing Oilfield Co. Ltd.HeilongjiangDaqing163712China TMSG co.pany Daqing Oilfield Co.Ltd.HeilongjiangDaqing163712China Northeast Petroleum University HeilongjiangDaqing163318China

The study aims to find out the formation period of fault traps near faults in petroliferous basins,based on an analysis of the formation period of fault lateral sealing and related influential factors.A method to calculate the formation period of fault lateral sealing(i.***.the time when displacement pressure of fault rock is equal to that of reservoir rock in fault wall with hydrocarbon migration)is established by co.paring the relationship between displacement pressure and time for fault rock and reservoir rock.This method is then applied to the study on reservoirs in the 1^(st),2^(nd),and 3^(rd) members of Dongying Formation(E_(3)d^(1),E_(3)d^(2) and E_(3)d^(3))in terms of formation period of lateral sealing of F3 fault crossing the three reservoirs in the No.5 structure of Nanpu Sag in Bohai Bay Basin.The results indicate that the formation period of the lateral sealing in the studied reservoirs can date from 7.1 Ma,7.4 Ma and 9.2 Ma respectively,all prior to the hydrocarbon accumulation period(about 2.58 Ma).Hence,it can be co.cluded that these reservoirs are favorable for the accumulation and preservation of hydrocarbons generated from the underlying source rock E_(3)s^(3),and the method proposed is feasible in calculating the formation period of fault lateral sealing.

关键词： Fault Lateral sealing Formation period Depth of co.paction and diagenesis

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Seismic Imaging of the Sedimentary System of the Upper Cretaceous Nenjiang Formation in the Northern Songliao Basin

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Journal of Earth Science 2019年第4期30卷 788-798页

作者： Wuling Mo Chaodong Wu Nan Su Shun Zhang Mingzhen Wang School of Earth and Space Sciences Peking UniversityBeijing 100871China PetroChina exploration and development research institute Langfang 257000China Exploration and Development Research Institute of Daqing Oilfield Co. Ltd. Daqing 163712China

This paper studied seismic imaging of the sedimentary system of the Nenjiang Formation in the Northern Songliao Basin based on seismic sedimentology. An accurate and detailed depiction and explanation is provided for underground geological bodies within a relative geological period using the stratal slice technology,based on three-order sequence co.relations of well logging and seismic data for the purpose of obtaining high-resolution pictures of the sedimentary system. research results have revealed that the sedimentary system of the Upper Cretaceous Nenjiang Formation in the Northern Songliao Basin includes meandering streams,anastomosing streams,lake deltas,and sediment gravity flow channels. Based on seismic imaging analysis,the genesis and seismic geomorphology of the sedimentary system of the Nenjiang Formation are explored in order to understand the spatial distribution of typical sedimentary bodies and the evolution of streams in the Nenjiang Formation. Acco.ding to the research results,the sedimentation of the Nenjiang Formation was subject to the delta system in the east and northeast of the formation. The provenance in the northeastern part played a dominant role during the deposition of the Nenjiang Formation for some time;after the earlier maximum flooding in the seco.d and third members of the Nenjiang Formation,the northeastern system began to decline and was gradually replaced by the eastern system. Stratal slices have revealed that a well-developed gravity flow channel system was developed in the first member of the Nenjiang Formation,and massive slip blocks occurred in the seco.d and third members of the formation. The research results indicated that the large gravity flow channel system in the first member of the Nenjiang Formation was formed by streams that emptied directly into the lake;and the slip blocks in the seco.d and third members were the results of gravity sliding of sediments along steep slopes at the delta front.

关键词： seismic sedimentology stratal slice sedimentary system Nenjiang Formation Songliao Basin

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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 co.pany 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 co.e 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 co.tent of felsic and dolostone,widespread organic matter,and low clay co.tent.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 co.trolling 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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Petroleum Retention,Intraformational Migration and Segmented Accumulation within the Organic-rich Shale in the Cretaceous Qingshankou Formation of the Gulong Sag,Songliao Basin,Northeast China

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地质学报:英文版 2023年第5期97卷 1568-1586页

作者： HUANGFU Yuhui ZHANG Jinyou ZHANG Shuichang WANG Xiaomei HE Kun GUAN Ping ZHANG Huanxu ZHANG Bin WANG Huajian School of Earth and Space Sciences Peking UniversityBeijing 100871China research institute of Petroleum exploration and development PetroChinaBeijing 100083China Exploration and Development Research Institute of Daqing Oilfield Co. Ltd.DaqingHeilongjiang 163712China Key Laboratory of Petroleum Geochemistry CNPCBeijing 100083China Grand Energy and Technology co. Ltd.SuzhouJiangsu 215000China

In this study,organic geochemical and petrological analyses were co.ducted on 111 shale samples from a well to understand the retention,intraformational migration and segmented accumulation(shale oil enrichment in different intervals is unco.nected)features of shale oil within the organic-rich shale in the Qingshankou Formation of the Gulong Sag.Our study shows that retained petroleum characteristics in the investigated succession are mainly influenced by three factors:organic richness,intraformational migration and segmented accumulation.Organic matter richness primarily co.trols the amount of retained petroleum,especially the‘live’co.ponent indicated by the S_(2)value rather than the total organic carbon(TOC)figure alone.The negative expulsion efficiencies determined by mass-balance calculations of hydrocarbons reveal that petroleum from adjacent organic-rich intervals migrates into the interval of about 2386-2408 m,which is characterized by high free hydrocarbon(S_(1)),OSI and saturated hydrocarbons co.tent,along with a greater difference inδ^(13)C values between polar co.pounds(including resins and asphaltenes)and saturated hydrocarbons.The depth-dependent heterogeneity of carbon isotope ratios(δ^(13)C)of mud methane gas,δ^(13)C of extracts gross co.position(SARA),δ^(13)C of kerogen and SARA co.tent of extracts suggest that the studied succession can be subdivided into four intervals.The shale oil sealing enrichment character in each interval is further co.roborated by the distinctδ^(13)C values of mud methane gas in different intervals.Due to the migration of petroleum into the 2386-2408 m interval,the S_(1),OSI and saturated hydrocarbons co.tent of the interval show higher relative values.The maturity of organic matter in the 2471-2500 m interval is at the highest with the smaller size molecular co.ponents of the retained petroleum.Thus,favorable‘sweet spots’may be found in the 2386-2408 m interval and the 2471-2500 m interval,acco.ding to the experiment results in this study.

关键词： shale oil oil retention intraformational migration segmented accumulation Gulong Sag

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In-situ hydrocarbon formation and accumulation mechanisms of micro- and nano-scale pore-fracture in Gulong shale, Songliao Basin, NE China

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Petroleum exploration and development 2023年第6期50卷 1269-1281页

作者： WANG Xiaojun CUI Baowen FENG Zihui SHAO Hongmei HUO Qiuli ZHANG Bin GAO Bo ZENG Huasen National Key Laboratory of co.tinental Shale Oil Daqing 163002China PetroChina daqing oilfield co. Ltd.Daqing 163002China PetroChina daqing oilfield exploration and development research institute Daqing 163712China PetroChina research institute of Petroleum exploration&development Beijing 100083China

By co.ducting experimental analyses, including thermal pyrolysis, micro-/nano-CT, argon-ion polishing field emission scanning electron microsco.y (FE-SEM), co.focal laser scanning microsco.y (CLSM), and two-dimensional nuclear magnetic resonance (2D NMR), the Gulong shale oil in the Songliao Basin was investigated with respect to formation model, pore structure and accumulation mechanism. First, in the Gulong shale, there are a large number of pico.algae, nano-algae and dinoflagellates, which were formed in brackish water environment and co.stituted the hydrogen-rich oil source materials of shale. Seco.d, most of the oil-generating materials of the Qingshankou Formation shale exist in the form of organo-clay co.plex. During organic matter thermal evolution, clay minerals had double effects of suppression and catalytic hydrogenation, which expanded shale oil window and increased light hydrocarbon yield. Third, the formation of storage space in the Gulong Shale was related to dissolution and hydrocarbon generation. With the diagenesis, micro-/nano-pores increased, pore diameter decreased and more bedding fractures appeared, which jointly gave rise to the unique reservoir with dual media (i.e. nano-scale pores and micro-scale bedding fractures) in the Gulong shale. Fourth, the micro-/nano-scale oil storage unit in the Gulong shale exhibits independent oil/gas occurrence phase, and shows that all-size pores co.tain oils, which occur in co.densate state in micropores or in oil-gas two phase (or liquid) state in macropores/mesopores. The understanding about Gulong shale oil formation and accumulation mechanism has theoretical and practical significance for advancing co.tinental shale oil exploration in China.

关键词： micro- nano-scale oil storage unit hydrocarbon occurrence phase organo-clay co.plex in-situ hydrocarbon accumulation Gulong shale oil Cretaceous Qingshankou Formation Songliao Basin

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