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Chinese Journal Of Geochemistry 2013年第2期32卷 181-190页

作者： GAO Xiaoyue LIU Luofu WANG Ying jiang zhenxue LIU Guodong SHANG Xiaoqing State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum (Beijing) Basin and Reservoir Research Center China University of Petroleum (Beijing)

The unconformity surface at the bottom of the Paleogene, located in the Sikeshu Sag of the Junggar Basin, Northwest China, is one of the most important hydrocarbon migration pathways and characterized by 3 layers of upper coarse clastic rock, lower weathering crust and leached zone. The upper coarse clastic rock displays features of higher density, lower SDT and gamma-ray logging while the weathering crust in the lower part displays opposite features. The formation water is of NaHCO 3 type but at lower mineralization degree. The QGF indices are generally between 2.19 and 3.77 and the GOI parameters vary from 1% to 5%. From the southeast to the northwest of the sag, the content of saturated hydrocarbon increases from 30.81% to 53.74% while that of non-hydrocarbon and asphaltene decreases. The Pr/nC 17 decreases from 0.65 to 0.47 while the Ph/nC 18 decreases from 0.66 to 0.27, and the content of benzo[c] carbazole declines while the benzo[a] carbazole amount and (alkyl carbazole)/(alkyl+benzo carbazole) ratio both increase. These revealed that the hydrocarbons migrated from the sag to the ramp region along the unconformity surface.

关键词：中国西北地区油气运移通道准噶尔盆地不整合面古近系凹陷底部苯并咔唑

Effect of Shale Reservoir Characteristics on Shale Oil Movability in the Lower Third Member of the Shahejie Formation, Zhanhua Sag

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Acta Geologica Sinica(English Edition) 2020年第2期94卷 352-363页

作者： NING Chuanxiang MA Zhongliang jiang zhenxue SU Siyuan LI Tingwei ZHENG Lunju WANG Guozhen LI Fengxun State Key Laboratory of Shale Oil and Gas Enrichment and Effective Development Wuxi 214126.JiangsuChina Wuxi Research Institute of Petroleum GeologySinopec Exploration and Production Research Institute Wuxi 214126JiangsuChina Unconventional Natural Gas Institute China University of PetroleumBeijing 102249China College of Earth Science.Jilin University Changchun 130012China Shandong Provincial Key Laboratory of Depositional Mineralization & Sedimentary Mineral Shandong University of Science and TechnologyQingdao 266590China Gas Hydrate Engineering Technology Center Guangzhou Marine Geological SurveyGuangzhou 510075China

To reveal the effect of shale reservoir characteristics on the movability of shale oil and its action mechanism in the lower third member of the Shahejie Formation(Es3l), samples with different features were selected and analyzed using N2 adsorption, high-pressure mercury injection capillary pressure(MICP), nuclear magnetic resonance(NMR), high-speed centrifugation, and displacement image techniques. The results show that shale pore structure characteristics control shale oil movability directly. Movable oil saturation has a positive relationship with pore volume for radius > 2 μm, as larger pores often have higher movable oil saturation, indicating that movable oil is present in relatively larger pores. The main reasons for this are as follows. The relatively smaller pores often have oil-wetting properties because of organic matter, which has an unfavorable effect on the flow of oil, while the relatively larger pores are often wetted by water, which is helpful to shale oil movability. The rich surface provided by the relatively smaller pores is beneficial to the adsorption of immovable oil. Meanwhile, the relatively larger pores create significant pore volume for movable oil. Moreover, the larger pores often have good pore connectivity. Pores and fractures are interconnected to form a complex fracture network, which provides a good permeability channel for shale oil flow. The smaller pores are mostly distributed separately;thus, they are not conducive to the flow of shale oil. The mineral composition and fabric macroscopically affect the movability of shale oil. Calcite plays an active role in shale oil movability by increasing the brittleness of shale and is more likely to form micro-cracks under the same stress background. Clay does not utilize shale oil flow because of its large specific surface area and its block effect. The bedding structure increases the large-scale storage space and improves the connectivity of pores at different scales, which is conducive t

关键词： shale oil movability shale reservoirs pore structure characteristics lower third member of the Shahejie Formation

Micron-to nano-pore characteristics in the shale of Longmaxi Formation,southeast Sichuan Basin

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Petroleum Research 2017年第2期2卷 156-168页

作者： Wenming Ji Yan Song zhenxue jiang Mianmo Meng Qingxin Liu Fenglin Gao State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing102249China Unconventional Natural Gas Research Institute of China University of Petroleum Beijing102249China School of Geosciences China University of PetroleumShandong266580China PetroChina Research Institute of Petroleum Exploration and Development Beijing100083China

For shale of Lower Silurian Longmaxi Formation in Chongqing,southeast Sichuan Basin,characteristics of micro-nano pores in marine shale reservoirs were well studies by means of Field-Emission Scanning Electron Microscope and Low-temperature Low-pressure Adsorption Experiment of CO_(2)and N_(2).Results showed that six types of pore were developed in the shale of Longmaxi Formation,i.e.,organic pores,intergranular pores,intragranular pores,intercrystalline pores,dissolution pores and microfractures,among which the organic pores and intragranular pores in interlayers of clay minerals were most developed,and a plenty of dissolution pores were also well developed because of high thermal evolution *** specific surface area of the shale in Longmaxi Formation ranged from 3.5 to 18.1 m^(2)/g,BJH total pore volume was from 0.00234 to 0.01338 cm^(3)/g,DA specific surface area of micropores vaired from 1.3 to 7.3 m^(2)/g,and DA pore volume ranged from 0.00052 to 0.00273 cm^(3)/*** specific surface area of micropores in the shale accounted for 23.1%-80.2%of total specific surface area with an average of 50.3%,and the pore volume of micropores accounted for 12.1%-48.5%of total pore volume with an average of 32.3%.Micropore was the main storage space in shale reservoir for methane adsorption,that because capacities of specific surface area provided by micropores were considerably greater than those provided by mesopores and *** size distribution of the shale was complex,and multiple different peaks occurred in the pore size curves,showing two or three peaks in the range from 0 to 100 nm and four peaks *** had a good linear relationship with pore structure parameters of micropores,mesopores t macropores and total pores in the shale,indicating that TOC was the most important control factor for micron-to nano-pore structure in the *** normalization of pore structure parameters to TOC,the pore structure parameters of total pores and mesopores

关键词： Marine shale Micron-to nano-pore Specific surface area Pore volume Pore structure parameter Longmaxi Formation Sichuan Basin

基于伍德合金多级压力注入实验的致密砂岩储层孔缝充注序列研究

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石油科学通报 2024年第3期9卷 383-393页

作者：刘冀蓬萧汉敏姜振学唐相路徐明帅中国石油大学(北京)油气资源与工程全国重点实验室北京102249 中国石油大学(北京)非常规油气科学技术研究院北京102249 中国石油勘探开发研究院北京100083

松辽盆地北部白垩系泉头组扶余致密砂岩储层发育微纳米级孔隙、微裂缝,且孔缝结构复杂,导致成藏期致密油气在不同类型储集空间中的充注顺序不清,增加了致密油气的勘探开发难度。本文针对致密砂岩储层中不同充注压力条件下致密油的充注... 详细信息

松辽盆地北部白垩系泉头组扶余致密砂岩储层发育微纳米级孔隙、微裂缝,且孔缝结构复杂,导致成藏期致密油气在不同类型储集空间中的充注顺序不清,增加了致密油气的勘探开发难度。本文针对致密砂岩储层中不同充注压力条件下致密油的充注特征开展定量研究,结合大视域拼接扫描电镜与矿物面扫技术,提出了一种基于孔隙-微裂缝组合的致密油充注规律微观评价方法。研究表明,区内泉头组扶余致密砂岩储层主要发育3种孔缝组合类型:粒间孔-黏土矿物收缩缝、粒间孔-脆性矿物粒间缝及黏土矿物晶间孔-收缩缝组合。通过将具有高温流变性质的伍德合金在不同压力下注入岩心,可以观察到合金在不同孔缝组合类型中的注入随注入压力提升而表现出有序性,粒间孔、缝的充注优先级明显高于黏土矿物相关孔缝,伍德合金的注入效率呈明显的先快速增大后缓慢增大最终趋于稳定的抛物线形态。依据伍德合金与原油的性质特征,将注入压力进行了等效转化,还原了地层条件下致密油的微观充注过程,据此建立了致密储层孔缝序列充注模式。在高源储压差条件下,致密油能够充注至纳米级的黏土矿物晶间孔-收缩缝中,随源储压差降低,致密油逐渐难以充注至纳米级孔缝中。当源储压差降至最低时,致密油仅能通过渗吸的方式通过宽大的孔间连通喉道进入微米级粒间孔及连通性较好的铸模孔中。本研究将流体注入与可视化技术相结合进行致密储层的储集空间多尺度评价,为致密储层微观甜点评价及高效开发提供参考。

关键词：孔缝组合伍德合金多级压力注入充注序列致密储层

薄层砂岩边底水油藏空气辅助内源微生物驱油技术

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特种油气藏 2024年第2期31卷 103-111页

作者：刘晓丽李阳白雷吴丛文王红波马挺姜振学万云洋中国石油大学(北京) 北京102249 中国石油新疆油田分公司新疆克拉玛依834000 南开大学天津300071

针对边底水油藏“双高阶段”零散分布剩余油如何有效动用、低成本高效微生物驱油体系如何研发、微生物驱效果评价及配套技术攻关等难题,建立微生物驱筛选图版并评价了油藏微生物驱的适应性;利用微生物分子生态学技术全面解析了油藏微生... 详细信息

针对边底水油藏“双高阶段”零散分布剩余油如何有效动用、低成本高效微生物驱油体系如何研发、微生物驱效果评价及配套技术攻关等难题,建立微生物驱筛选图版并评价了油藏微生物驱的适应性;利用微生物分子生态学技术全面解析了油藏微生物群落结构,筛选了乳化效果好的采油功能菌株H3;通过对主要营养成分碳源、氮源、磷源的筛选,开展单因素实验和正交实验,确定了可实现原油乳化分散和抑制硫酸盐还原菌生长的复合粉激活体系;研究了底水油层“船底形”剩余油富集特征,形成了“微生物乳化+空气提效+稠化剂封堵”提高采收率驱油模式,明确了提高采收率幅度与注入菌体浓度、注入孔隙体积倍数正相关。将研究成果应用于准噶尔盆地陆梁油田薄层砂岩边底水油藏,实施“4注20采”微生物驱提高采收率矿场先导试验,注入微生物激活剂0.13倍孔隙体积,2017至2023年阶段增油5.6×104 t,采收率提高4.0个百分点,增油效果好的井主要分布在总菌浓度高、石油地质储量大、构造高部位、油层厚度大、底水薄、采出程度较高的区域。研究成果对丰富微生物驱提高采收率技术序列具有借鉴作用。

关键词：内源微生物驱边底水油藏剩余油激活体系采收率准噶尔盆地陆梁油田

Differences of Hydrocarbon Enrichment between the Upper and the Lower Structural Layers in the Tazhong Paleouplift

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Acta Geologica Sinica(English Edition) 2010年第5期84卷 1116-1127页

作者： jiang zhenxue YANG Haijun LI Zhuo PANG Xiongqi HAN Jianfa LI Dongxu HUANG Yuyan State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum （Beijing） Beijing 102249 China Basin and Reservoir Research Center China University of Petroleum Beijing 102249 China Tarim Oilfield Company CNPC Korla Xinjiang 841000 China

The Tazhong paleouplift is divided into the upper and the lower structural layers, bounded by the unconformity surface at the top of the Ordovician carbonate rock. The reservoirs in the two layers from different parts vary in number, type and reserves, but the mechanism was rarely researched before. Therefore, an explanation of the mechanism will promote petroleum exploration in Tazhong paleouplift. After studying the evolution and reservoir distribution of the Tazhong paleouplift, it is concluded that the evolution in late Caledonian, late Hercynian and Himalayan periods resulted in the upper and the lower structural layers. It is also defined that in the upper structural layer, structural and stratigraphic overlap reservoirs are developed at the top and the upper part of the paleouplift, which are dominated by oil reservoirs, while for the lower structural layer, lithological reservoirs are developed in the lower part of the paleouplift, which are dominated by gas reservoirs, and more reserves are discovered in the lower structural layer than the upper. Through a comparative analysis of accumulation conditions of the upper and the lower structural layers, the mechanism of enrichment differences is clearly explained. The reservoir and seal conditions of the lower structural layer are better than those of the upper layer, which is the reason why more reservoirs have been found in the former. The differences in the carrier system types, trap types and charging periods between the upper and the lower structural layers lead to differences in the reservoir types and distribution. An accumulation model is established for the Tazhong paleouplift. For the upper structural layer, the structural reservoirs and the stratigraphic overlap reservoirs are formed at the upper part of the paleouplift, while for the lower structural layer, the weathering crust reservoirs are formed at the top, the reef-flat reservoirs are formed on the lateral margin, the karst and inside reservoirs

关键词： the upper and the lower structural layers enrichment difference accumulation model,Tazhong paleouplift

Hydrocarbon Accumulation in Lacustrine Turbidite in the Rift Basin, Bohai Bay

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Petroleum Science 2006年第1期3卷 12-26页

作者： Chen Dongxia Pang Xiongqi Li Pilong jiang zhenxue Key Laboratory for Petroleum Formation Mechanisms of the Chinese Ministry of Education China University of Petroleum Beijing 102249 China Geological Survey of Canada 3303-33 Street NW Calgary Alberta T2L2A7 Canada SINOPEC Shengli Oilfield Co. Shandong 257000 China

Three types of turbidites are identified in the studied area, including proximal turbidite along the northern steep slope （alluvial fans, fan delta, and subaqueous fans via short-distance transportation）, distal turbidites along the southern gentle slope （stacked sliding of delta and fan delta front）, and fluxoturbidite in the central depression. Detailed studies of several case histories and the relationship between sedimentary facies and faults suggest a significant role of tectonic setting and faults in the development of turbidite, which created source areas, effected slope topography, controlled the climate and paleo-environment, and formed enough slope angle and slope break for sedimentary instabilities and massive block movement to form turbidite. According to statistics, 0.86%, with an average value of 40.3%, of the trap volumes in the 69 identified Tertiary lacustrine turbidites in the Jiyang Superdepression in the Bohai Bay Basin are filled with oil. The porosity and permeability of turbidite sands vary widely. The productive reservoirs are generally those from the braided channels of both distal and proximal turbidite, and from the main channel of proximal turbidite, with a low carbonate content and the porosity and permeability higher than 12% and 1 mD respectively. Most of the lithologic oil pools in the Jiyang Superdepression are enveloped by the effective source rocks, and the percentage of the trap volume generally increases with the hydrocarbon expulsion intensity of source rocks. This is in contrast with structural-lithologic traps （i.e. proximal turbidite along the steep slope and distal turbidite along the gentle slope）, in which, graben-boundary faults play an important role in oil migration, as the turbidites are not in direct contact with effective hydrocarbon source rocks.

关键词： Rift basin Jiyang Superdepression lacustrine turbidite oil-bearing property controlling factors

Dynamic Field Division of Hydrocarbon Migration,Accumulation and Hydrocarbon Enrichment Rules in Sedimentary Basins

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Acta Geologica Sinica(English Edition) 2012年第6期86卷 1559-1592页

作者： PANG Xiongqi LIU Keyu MA Zhongzhen jiang zhenxue XIANG Caifu HUO Zhipeng PANG Hong CHEN Junqing State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Basin and Reservoir Research Center School of Natural Resources and Information TechnologyChina University of Petroleum PetroChina Research Institute of Petroleum Exploration & Development CSIRO Earth Science and Resource Engineering

Hydrocarbon distribution rules in the deep and shallow parts of sedimentary basins are considerably different, particularly in the following four aspects. First, the critical porosity for hydrocarbon migration is much lower in the deep parts of basins： at a depth of 7000 m, hydrocarbons can accumulate only in rocks with porosity less than 5%. However, in the shallow parts of basins （i.e., depths of around 1000 m）, hydrocarbon can accumulate in rocks only when porosity is over 20%. Second, hydrocarbon reservoirs tend to exhibit negative pressures after hydrocarbon accumulation at depth, with a pressure coefficient less than 0.7. However, hydrocarbon reservoirs at shallow depths tend to exhibit high pressure after hydrocarbon accumulation. Third, deep reservoirs tend to exhibit characteristics of oil （-gas）-water inversion, indicating that the oil （gas） accumulated under the water. However, the oil （gas） tends to accumulate over water in shallow reservoirs. Fourth, continuous unconventional tight hydrocarbon reservoirs are distributed widely in deep reservoirs, where the buoyancy force is not the primary dynamic force and the caprock is not involved during the process of hydrocarbon accumulation. Conversely, the majority of hydrocarbons in shallow regions accumulate in traps with complex structures. The results of this study indicate that two dynamic boundary conditions are primarily responsible for the above phenomena： a lower limit to the buoyancy force and the lower limit of hydrocarbon accumulation overall, corresponding to about 10%-12% porosity and irreducible water saturation of 100%, respectively. These two dynamic boundary conditions were used to divide sedimentary basins into three different dynamic fields of hydrocarbon accumulation： the free fluid dynamic field, limit fluid dynamic field, and restrain fluid dynamic field. The free fluid dynamic field is located between the surface and the lower limit of the buoyancy force, such that hydrocarbons in this fi

关键词： petroliferous basins dynamic force of hydrocarbon accumulation dynamic fields ofhydrocarbon accumulation hydrocarbon accumulation mechanism hydrocarbon distribution rule

Formation and Accumulation of Hydrocarbons in the Central Uplift,Dongying Depression

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Petroleum Science 2006年第3期3卷 12-22页

作者： Li Sumei Qiu Guiqiang Gao Yongjin jiang zhenxue Key Laboratory for Hydrocarbon Accumulation Ministry of Education China University of Petroleum Beijing 102249 China Basin and Reservoir Research Center China University of Petroleum Beijing 102249 China Shengli Oilfield Company SINOPEC Dongying Shandong 257015 China

A large number of crude oil and rock samples from various oil pools of the Central Uplift in Dongying Depression were investigated to reveal the origin and accumulation of hydrocarbons. The results showed that the composition and areal distribution of hydrocarbons vary with the location of the oil pools. An increasing trend of gammacerane/C30-hopane and steranes/hopanes but a decreasing trend of prystane/phytane （Pr/Ph） and 18（H）-/17（H）- trisnorhopane （Ts/Tm） ratios were observed from southwest to northeast. This indicates a variation of source rocks and hydrocarbon properties. An increasing trend of water salinity with much more input of algae-rich microorganisms in the deposition environment of the source rock was observed from southwest to northeast. However, the thermal maturity of the source rocks showed a decreasing trend in the same direction. Oil-to-oil and oil-to-source rock correlations showed that most oils were sourced from Es3 and Es4 members with a burial depth of more than 3,000-3,150 m and 2,700 m respectively. The oils in the Shinan and Ying 11 sand bodies, which were generally mixed with the Es4 sourced oils, came mostly from Es3 mudstones. It is quite significant that the Es4 derived oils migrated vertically for hundreds of meters and accumulated in an overlying lithologic pool of the Es3^m, i.e., Ying 11 synclinal lithologic pool, which suggests that the mechanisms of migration and accumulation for subtle oil pools in the Dongying Depression are more complex than that of the previously expected.

关键词： Dongying Depression Central Uplift source rock oil-gas genesis subtle oil pool

In-situ Fluid Phase Variation along the Thermal Maturation Gradient in Shale Petroleum Systems and Its Impact on Well Production Performance

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Journal of Earth Science 2023年第4期34卷 985-1001页

作者： Qianyou Wang Wei Yang Yaohua Li zhenxue jiang Ming Wen Rusi Zuo Xin Wang Zixin Xue Yaohua Wang State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249China Department of Earth Ocean and Ecological SciencesUniversity of LiverpoolLiverpool L693GPUK Unconventional Oil and Gas Sciences and Technology Institute China University of PetroleumBeijing 102249China Oil and Gas Survey China Geological SurveyBeijing 100083China Now at the Lyell Centre Heriot-Watt UniversityEdinburgh EH144APUK State Key Laboratory of Marine Geology Tongji UniversityShanghai 200092China College of Geosciences China University of PetroleumBeijing 102249China Key Laboratory of Metallogenic Prediction of Nonferrous Metals and Geological Environment Monitoring Central South UniversityChangsha 410083China

In-situ fluid phase behavior is important in determining hydrocarbon contents and the multiphase flow through shale *** gas-to-oil ratio(GOR) has been recognized as a critical indicator of fluid ***,little is known about the impact of fluid phase variation across the thermal maturity on shale oil/gas production(e.g.,estimated ultimate recovery,EUR).According to the specific gravity ratio of oil/gas,the producing GOR was converted and normalized into a mass fraction of gas in total hydrocarbons(MGOR) to compare North American shale oil/gas plays with Chinese shale oil and hybrid gas-condensate plays.A correlation between MGOR,the fluid phases,and production data was established to identify five phase stages of *** systematically with the different production zones,which shows promise in rapidly indicating the well production performance and high production stages of shale oil/gas *** hybrid shale gas condensate index,Tmax,and total gas contents were integrated to present the fluid types and maturity of shale gas-condensates,which indicates fluid phase and production variation across thermal *** results offer a unique perspective on the shale oil reservoir producibility based on the impact of GOR on fluid phases and EUR from the dominant global oil/gas plays.

关键词： shale oil shale gas gas condensate fluid phase thermal maturity sweet spots GOR EUR.