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Eogenetic karst and its control on reservoirs in the Ordovician Majiagou Formation, eastern Sulige gas field, Ordos Basin, NW China

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Petroleum Exploration and Development 2020年第6期47卷 1246-1261页

作者： XIE Kang TAN Xiucheng FENG Min WANG Baobao ZHONG Shoukang YANG Mengying NIE Wancai QIAO Zhanfeng ZENG Wei State Key Laboratory of Oil and gas Reservoir Geology and Exploitation Southwest Petroleum UniversityChengdu 610500China department of Key Laboratory of Carbonate Reservoir of CNPC Southwest Petroleum UniversityChengdu 610500China Exploration and Development Research Institute of petrochina changqing oilfield company Xi’an 710018China Yihuang Natural Gas Department of PetroChina Changqing Oilfield Company Xi’an 710018China petrochina Hangzhou Research Institute of Geology Hangzhou 310023China

To further ascertain the origin of the Ordovician Majiagou Formation reservoirs in the Ordos Basin,the M54-M51 sub-members of the Ordovician Majiagou Formation in the eastern Sulige gasfield of Ordos Basin were taken as examples to analyze the vertical development characteristics of eogenetic karst and to discover the dissolution mechanism and its control on reservoirs through observation of a large number of cores and thin sections.According to detailed analysis of petrologic characteristics,the reservoir rock types include micritic dolomite,grain dolomite and microbialite which have mainly moldic pore,intergranular(dissolved)pore,and(dissolved)residual framework pore as main reservoir space respectively.The study area developed upward-shallowing sequences,with an exposure surface at the top of a single upward-shallowing sequence.The karst systems under the exposure surface had typical exposure characteristics of early dissolution and filling,indicating these reservoirs were related to the facies-controlled eogenetic karstification.With the increase of karstification intensity,the reservoirs became worse in physical properties.

关键词： porous reservoir reservoir characteristics eogenetic karst dolomite Majiagou Formation Ordovician Sulige gas field Ordos Basin

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Control of paleogeographic pattern on sedimentary differentiation of evaporite-carbonate symbiotic system:A case study of the sixth sub-member of Ordovician Majiagou Formation M5 Member in central-eastern Ordos Basin,NW China

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Petroleum Exploration and Development 2022年第4期49卷 837-850页

作者： ZHONG Shoukang TAN Xiucheng HU Guang NIE Wancai YANG Mengying ZHANG Daofeng ZHENG Jianfeng XU Jie DONG Guodong XIAO Di LU Zixing State Key Laboratory of Oil and gas Reservoir Geology and Exploitation Chengdu 610500China Southwest Petroleum University Division of Key Laboratory of Carbonate Reservoirs CNPCChengdu 610500China natural gas Project department Changqing Oilfield Company of PetroChinaXi'an 710016China Research Institute of Exploration and Development Changqing Oilfield Company of PetroChinaXi'an 710016China petrochina Hangzhou Research Insitute of Geology Hangzhou 310023China

The relationship between paleogeographic pattern and sedimentary differentiation of evaporite-carbonate symbiotic system is examined based on logging,core and thin section data,by taking the sixth sub-member of fifth member of Ordovician Majiagou Formation(M56)in the central-eastern Ordos Basin as an example.(1)Seven sub-geomorphic units(Taolimiao west low,Taolimiao underwater high,Taolimiao east low,Hengshan high,East salt low,North slope and Southwest slope)developed in the study area.(2)The“three lows”from west to east developed dolomitic restricted lagoon,evaporite evaporative lagoon and salt evaporative lagoon sedimentary facies respectively,the"two highs"developed high-energy grain beach and microbial mound,and the north and south slopes developed dolomitic flats around land.(3)The paleogeographic pattern caused natural differentiation of replenishment seawater from the northwest Qilian sea,leading to the eccentric sedimentary differentiation of dolomite,evaporite and salt rock symbiotic system from west to east,which is different from the classic“bull's eye”and“tear drop”distribution patterns.(4)As the Middle Qilian block subducted and collided into the North China Plate,the far-end compression stress transferred,giving rise to the alternate highland and lowland in near north to south direction during the sedimentary period of M56 sub-member.(5)Taolimiao underwater high and Hengshan high developed favorable zones of microbial mounds and grain shoals in south to north strike in M56 sub-member,making them favorable exploration areas with great exploration potential in the future.

关键词： paleogeographic pattern sedimentary differentiation evaporite and carbonate rock favorable reservoir facies zone Ordovician Majiagou Formation Ordos Basin

Discovery and geological knowledge of the large deep coal-formed Qingyang gas Field, Ordos Basin, NW China

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Petroleum Exploration and Development 2019年第6期46卷 1111-1126页

作者： FU Jinhua WEI Xinshan LUO Shunshe ZUO Zhifeng ZHOU Hu LIU Baoxian KONG Qingfen ZHAN Sha NAN Junxiang petrochina changqing oilfield company Xi’an 710018China National Engineering Laboratory of Low Permeability Oil and gas Field Exploration and Development Xi’an 710018China Research Institute of Exploration and Development PetroChina Changqing Oilfield CompanyXi’an 710018China Hubei Cooperative Innovation Center of Unconventional Oil and gas(Yangtze University) Wuhan 430000China Exploration department PetroChina Changqing Oilfield CompanyXi’an 710018China

After 50 years of oil and gas exploration in Longdong area of southwest Ordos Basin,NW China,a deep coal-formed gas field was discovered for the first time in Qingyang area.Through observation of field outcrops and core,analysis of common,cast and cathode thin sections,Ro and other geochemistry indexes,carbon isotope,electron microscope and other supporting tests and analyses,the hydrocarbon generation,reserves formation and reservoir formation characteristics of gas reservoirs at different buried depths in Yishaan slope were examined and compared.The deep gas reservoir has an average buried depth of more than 4200 m,and the main gas-bearing formation is the Member 1 of Lower Permian Shanxi Formation,which is characterized by low porosity,low permeability,low pressure and low abundance.It is believed that hydrocarbon generation in thin seam coal source rocks with high thermal evolution can form large gas fields,high-quality sandstone reservoirs with dissolved pores,intergranular pores and intercrystalline pores can still develop in late diagenetic stage under deep burial depth and high thermal evolution,and fractures improve the permeability of reservoirs.High drying coefficient of natural gas and negative carbon isotope series are typical geochemical characteristics of deep coal-formed gas.The integrated exploration and development method has been innovated,and the economic and effective development mode of gas fields of"dissecting sand body by framework vertical wells,centralized development by horizontal wells"has been formed.The discovery and successful exploration of the large gas field has provided geological basis and technical support for the construction of natural gas fields of 100 billion cubic meter scale in the southwest of the basin,and has important guidance for exploration of coal-derived gas with deep buried depth and high thermal evolution widely distributed in China.

关键词： Ordos Basin Upper Paleozoic Lower Permian coal-formed gas deep formation high thermal evolution Qingyang large gas field

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gas accumulation conditions and key technologies for exploration & development of Sulige gasfield

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Petroleum Research 2018年第2期3卷 91-109页

作者： Jinhua Fu Liyong Fan Xinshe Liu Daojun Huang petrochina changqing oilfield company Shaanxi710018China Research Institute of Petroleum Exploration and Development PetroChina Changqing Oilfield CompanyShaanxi710018China Exploration department PetroChina Changqing Oilfield CompanyShaanxi710018China National Engineering Laboratory of Low Permeability Oil and gas Field Exploration and Development Shaanxi710018China

Up to now,the Sulige area in Ordos Basin has the favorable exploration area of 55×10^(3) km^(2),the total reserve of natural gas of nearly 6×10^(12) m^(3) and the proven reserve(including basic proven reserve)of 4.77×10^(12) m^(3),where the annual production of natural gas reaches 23×10^(9) m^(3),and the Sulige gasfield is the largest onshore natural gas field in China.The pay zone of the Sulige gasfield mainly is Member 8 of Shihezi Formation and Member 1 of Shanxi Formation of Permian which belong to the typical tight sandstone gas reservoir.The coal measure strata in Carboniferous Benxi Formation,Permian Taiyuan Formation and Shanxi Formation provide abundant gas sources for the Gulige gas reservoirs.An open-flow sedimentary model of lacustrine delta is developed,the gentle bottom,sand supply from multisource,strong hydrodynamic force and multi-period superposition control the distribution of largearea reservoir sand body.Lithology of the reservoir is the sandstone of the fluvial-delta facies,the physical property is poor and the heterogeneity is strong,the average porosity ranges from 4%to 12%and the average permeability varies from 0.01 to 1 mD.The gas reservoir is characterized by wide hydrocarbon generation,pervasive hydrocarbon charging,short-range migration and massive accumulation.The pressure coefficient of the gas reservoir ranges from 0.62 to 0.90,indicating the low-pressure gas reservoir,and the single-well yield is low.Full digital seismic technique in the desert area,nonlongitudinal seismic technique in the loess plateau,accurate logging evaluation technique,tight sand reservoir stimulation technology and horizontal well development technology are key technologies for exploration and development of Sulige gasfield.

关键词： Sulige gasfield Upper paleozoic Tight gas Accumulation condition Key technology

Optimization of the seismic processing phase-shift plus finite-difference migration operator based on a hybrid genetic and simulated annealing algorithm

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Petroleum Science 2013年第2期10卷 190-194页

作者： Luo Renze Huang Yuanyi Liang Xianghao Luo Jun Cao Ying State Key Laboratory of Oil and gas Reservoir Geology and Exploitation Southwest Petroleum University Geophysics Development department of BGP Exploration and Exploitation department of Tarim oilfield company PetroChina changqing oilfield company PetroChina

Although the phase-shift seismic processing method has characteristics of high accuracy, good stability, high efficiency, and high-dip imaging, it is not able to adapt to strong lateral velocity variation. To overcome this defect, a finite-difference method in the frequency-space domain is introduced in the migration process, because it can adapt to strong lateral velocity variation and the coefficient is optimized by a hybrid genetic and simulated annealing algorithm. The two measures improve the precision of the approximation dispersion equation. Thus, the imaging effect is improved for areas of high-dip structure and strong lateral velocity variation. The migration imaging of a 2-D SEG/EAGE salt dome model proves that a better imaging effect in these areas is achieved by optimized phase-shift migration operator plus a finite-difference method based on a hybrid genetic and simulated annealing algorithm. The method proposed in this paper is better than conventional methods in imaging of areas of high-dip angle and strong lateral velocity variation.

关键词： Migration operator phase-shift plus finite-difference hybrid algorithm genetic andsimulated annealing algorithm optimization coefficient

A novel hybrid thermodynamic model for pore size distribution characterisation for shale

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Petroleum Science 2022年第3期19卷 963-978页

作者： Ze-Zhang Song Abide Abula Jun-Yi Zhao Guang-Di Liu Ming-Rui Li Dai-Lin Yang Yun-Long Wang State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing102249China College of Geosciences China University of PetroleumBeijing102249China The Exploration department of the changqing oilfield company PetroChinaXi'anShaanxi710021China Research Institute of Petroleum Exploration and Development Southwest Oil and Gas Field CompanyPetroChinaChengduSichuan 610041China

Scholars often see the gas adsorption technique as a straight-to-interpret technique and adopt the pore size distribution(PSD)given by the gas adsorption technique directly to interpret pore-structure-related issues.The oversimplification of interpreting shale PSD based on monogeometric thermodynamic models leads to apparent bias to the realistic pore network.This work aims at establishing a novel thermodynamic model for shale PSD interpretation.We simplified the pore space into two geometric types—cylinder-shaped and slit-shaped.Firstly,Low-temperature Nitrogen Adsorption data were analyzed utilizing two monogeometric models(cylindrical and slit)to generate PSD_(cyl).and PSD_(slit);Secondly,pore geometric segmentation was carried out using Watershed by flooding on typical SEM images to obtain the ratio of slit-shaped(∅_(s))and cylinder-shaped pores(∅_(c)).Combining the results of the two,we proposed a novel hybrid model.We performed pyrolysis,XRD,FE-SEM observation,quantitative comparison with the results obtained by the DFT model,and fractal analysis to discuss the validity of the obtained PSD_(Hybrid).The results showed that:the hybrid model proposed in this work could better reflect the real geometry of pore space and provide a more realistic PSD;compared with thermodynamic monogeometric models,PSD obtained from the hybrid model are closer to that from the DFT model,with an improvement in the deviation from the DFT model from 5.06%to 68.88%.The proposed hybrid model has essential application prospects for better interpretation of shale pore space.It is also worth noting that we suggest applying the proposed hybrid model for PSD analysis in the range of 5-100 nm.

关键词： Pore size distribution Monogeometric thermodynamic model The hybrid model Pore structure Shale

Geochronological Records of Oil-gas Accumulations in the Permian Reservoirs of the Northeastern Ordos Basin

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Acta Geologica Sinica(English Edition) 2013年第6期87卷 1701-1711页

作者： CHEN Gang YANG Fu LI Shuheng ZHANG Huiruo HU Yanxu LEI Panpan State Key Laboratory of Continental Dynamics Department of Geology Northwest University changqing oilfield company PetroChina Company Limited CNPC

Geochronology of oil-gas accumulation （OGA） is a challenging subject of petroleum geology in multi-cycle superimposed basins.By K-Ar dating of authigenic illite （AI） and fluid inclusion （FI） analysis combined with apatite fission track （AFT） thermal modeling,a case study of constraining the OGA times of the Permian reservoirs in northeast Ordos basin （NOB） has been conducted in this paper.AI dating of the Permian oil-gas-bearing sandstone core-samples shows a wide time domain of 178-108 Ma.The distribution of the AI ages presents 2-stage primary OGA processes in the Permian reservoirs,which developed in the time domains of 175-155 Ma and 145-115 Ma with 2-peak ages of 165 Ma and 130 Ma,respectively.The FI temperature peaks of the samples and their projected ages on the AFT thermal path not only present two groups with a low and a high peak temperatures in ranges of 90-78℃ and 125-118℃,respectively corresponding to 2-stage primary OGA processes of 162-153 Ma and 140-128 Ma in the Permian reservoirs,but also appear a medium temperature group with the peak of 98℃ in agreement with a secondary OGA process of c.～30 Ma in the Upper Permian reservoirs.The integrated analysis of the AI and FI ages and the tectono-thermal evolution reveals that the Permian reservoirs in the NOB experienced at least 2-stage primary OGA processes of 165-153 Ma and 140-128 Ma in agreement with the subsidence thermal process of the Mid-Early Jurassic and the tectono-thermal event of the Early Cretaceous.Then,the Upper Permian reservoirs further experienced at least 1-stage secondary OGA process of c.～30 Ma in coincidence with a critical tectonic conversion between the slow and the rapid uplift processes from the Late Cretaceous to Neogene.

关键词： northeast Ordos basin （NOB） Permian sandstone reservoirs oil-gas accumulation （OGA） geochronology

Effect of fracture fluid flowback on shale microfractures using CT scanning

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Journal of Rock Mechanics and Geotechnical Engineering 2024年第2期16卷 426-436页

作者： Jiale He Zhihong Zhao Yiran Geng Yuping Chen Jianchun Guo Cong Lu Shouyi Wang Xueliang Han Jun Zhang State Key Laboratory of Oil and gas Reservoir Geology and Exploitation Southwest Petroleum UniversityChengdu610500China Key Laboratory of Thermo-Fluid Science and Engineering of Ministry of Education School of Energy and Power EngineeringXi’an Jiaotong UniversityXi’an710049China Drilling Test Engineering department of Longdong Oil and gas Development company Changqing OilfieldPetroChina Company LimitedQingyang745000China Tight Oil and gas Exploration and Development Project department PetroChina Southwest Oil and Gas Field CompanyChengdu610056China No.11 Oil Production Plant Changqing Oilfield CompanyPetroChina Company LimitedQingyang745000China

The field data of shale fracturing demonstrate that the flowback performance of fracturing fluid is different from that of conventional reservoirs,where the flowback rate of shale fracturing fluid is lower than that of conventional reservoirs.At the early stage of flowback,there is no single-phase flow of the liquid phase in shale,but rather a gas-water two-phase flow,such that the single-phase flow model for tight oil and gas reservoirs is not applicable.In this study,pores and microfractures are extracted based on the experimental results of computed tomography(CT)scanning,and a spatial model of microfractures is established.Then,the influence of rough microfracture surfaces on the flow is corrected using the modified cubic law,which was modified by introducing the average deviation of the microfracture height as a roughness factor to consider the influence of microfracture surface roughness.The flow in the fracture network is simulated using the modified cubic law and the lattice Boltzmann method(LBM).The results obtained demonstrate that most of the fracturing fluid is retained in the shale microfractures,which explains the low fracturing fluid flowback rate in shale hydraulic fracturing.

关键词： Shale Flowback of fracturing fluid Microfracture Lattice Boltzmann method(LBM)

Fluid Inclusion Analysis for Constraining the Hydrocarbon Accumulation Periods of the Permian Reservoirs in Northeast Ordos Basin

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Journal of Earth Science 2013年第4期24卷 589-598页

作者：陈刚李书恒章辉若杨甫丁超雷盼盼胡延旭 State Key Laboratory of Continental Dynamics and department of Geology Northwest University changqing oilfield company PetroChina Company LimitedCNPC department of Geology Northwest University

Geochronology of hydrocarbon accumulation and reconstruction is an important and challenging subject of petroleum geology in multi-cycle superimposed basin. By fluid inclusion （FI） analysis combined with the apatite fission track （AFT） modeling thermal path of the FI host rock, a case study of constraining the hydrocarbon accumulation and reconstruction periods of the Permian reservoirs in Northeast Ordos Basin （OB） has been conducted. The FI homogenization temperatures of the oil-gas-bearing sandstone core-samples from the Lower to Upper Permian reservoirs statistically present two groups with a low and a high temperature peaks in ranges of 90-78 and 125-118 ℃, re- spectively, corresponding to 2-stage primary hydrocarbon accumulations of the Early-Middle Mesozoic. Besides, there exists another group with a medium-high peak temperature of 98 ℃ in the Upper Per- mian reservoirs, corresponding to the hydrocarbon reconstruction and destruction of the Late Meso- zoic to Cenozoic. According to the projected ages of the FI peak temperatures on the AFT thermal path of the FI host rocks, it is further induced that there experienced 3-stage hydrocarbon accumulations in the Permian reservoirs during the Mesozoic to Cenozoic. These are：（1） all the various primary hydro- carbon Permian reservoirs together developed 2-stage accumulations of 162-153 and 140-128 Ma in agreement with the multi-cycle subsidence burial heating process of the basin; （2） the Upper Per- mian reservoirs further experienced 1-stage secondary hydrocarbon accumulation and re- construction at ca. 30 Ma in coincidence with a critical tectonic conversion of the slow to rapid uplifting process from the Late Cretaceous to Neogene.

关键词： Northeast Ordos Basin Permian reservoir fluid inclusion apatite fission track geochronology hydrocarbon accumulation.