Sheng XU,Lufeng GUAN,Maoliang ZHANG,Jun ZHONG,Wei LIU,Xian'gang XIE,Congqiang LIU,Naoto TAKAHATA,Yuji SANO[1]（2022）在《Degassing of deep-sourced CO2 from Xianshuihe-Anninghe fault zones in the eastern Tibetan Plateau》文中指出A large number of gases are releasing from the medium-high temperature geothermal fields distributed along the large-scale strike-slip fault zones in the southeastern margin of the Tibetan Plateau. In this study, 11 hot spring water and the associated bubbling gas samples were collected along the Xianshuihe-Anninghe fault zones（XSH-ANHFZ） and analyzed for chemical and isotopic compositions. The O18 H O2 and DH O2 values indicate that hot spring waters are predominantly meteoric origin recharged from different altitudes. Most water samples are significantly enriched in Na+and HCO3 due to the dissolution of regional evaporites, carbonates and Na-silicates.3 He/4 He ratios of the gas samples are 0.025–2.73 times the atmospheric value. The3 He/4 He ratios are high in the Kangding region where the dense faults are distributed, and gradually decrease with increasing distance from Kangding towards both sides along the Xianshuihe fault zones（XSHFZ）. Hydrothermal fluids have dissolved inorganic carbon（DIC） concentrations from 2 to 42 mmol L-1, δ13 CDICfrom-6.9‰ to 1.3‰, C13 CO2 from-7.2‰ to-3.6‰ and ?14 C from-997‰ to-909‰. Combining regional geochemical and geological information, the CO2 sources can be attributed to deep-sourced CO2 from mantle and metamorphism of marine carbonate, and shallow-sourced CO2 from the dissolution of marine carbonate and biogenic CO2. The mass balance model shows that 11±6% of the DIC is sourced from the dissolution of shallow carbonate minerals, 9±8% formed by pyrolysis of sedimentary organic matter, 80±9% derived from deep metamorphic origin and mantle-derived CO2. Among them, the deep-sourced CO2 in Anninghe fault zones（ANHFZ） is merely metamorphic carbon, whereas ca. 12% and ca. 88% of the deep-sourced CO2 in the XSHFZ are derived from the mantle and metamorphic carbon, respectively. The average deep-sourced CO2 flux in the Kangding geothermal field is estimated to be160 t a-1. If all the hot springs in various fault zones in the southeastern margin of the Tibetan Plateau are taken into account, the regional deep-sourced CO2 flux would reach ca. 105 t a-1. These results show that the deep-sourced CO2 released from nonvolcanic areas might account for a considerable proportion of the total amount of global deep-sourced carbon degassing, which should be paid more attention to.
LI Jianzhong,TAO Xiaowan,BAI Bin,HUANG Shipeng,JIANG Qingchun,ZHAO Zhenyu,CHEN Yanyan,MA Debo,ZHANG Liping,LI Ningxi,SONG Wei[2]（2021）在《Geological conditions, reservoir evolution and favorable exploration directions of marine ultra-deep oil and gas in China》文中认为By analyzing the structural background,petroleum geological conditions,and typical regional（paleo） oil and gas reservoirs in marine ultra-deep oil and gas regions in China,this paper reveals the evolution processes of the marine ultra-deep oil and gas reservoirs and the key controlling factors of accumulation.The marine ultra-deep oil and gas resources in China are buried at depth of greater than 6000 m,and are mainly distributed in the Precambrian and Lower Paleozoic strata in the Sichuan,Tarim and Ordos cratonic basins.The development of marine ultra-deep source rocks in China is controlled by cratonic rifts and cratonic depressions with the background of global supercontinent breakup-convergence cycles.The source rocks in Sichuan Basin have the most developed strata,followed by Tarim Basin,and the development strata and scale of Ordos Basin needs to be further confirmed.The marine ultra-deep reservoir in China is dominated by carbonate rocks,and the reservoir performance is controlled by high-energy sedimentary environment in the early stage,superimposed corrosion and fracture in the later stage.The regional caprocks are dominated by gypsum salt rocks,shale,and tight carbonate rock.The ultra-deep oil and gas fields in China have generally experienced two stages of oil-reservoir forming,cracking（or partial cracking） of paleo-oil reservoirs,and late finalization of cracked gas（or highly mature to over mature oil and gas）.The oil and gas accumulation is controlled by static and dynamic geological elements jointly.Major hydrocarbon generation center,high quality and large-scale reservoir resulted from karstification of high energy facies belt,thick gypsum rock or shale caprock,and stable trapping and preservation conditions are the key factors for accumulation of ultra-deep oil and gas.We propose three favorable exploration directions,i.e.the areas around intracratonic rift and intracratonic depression,and craton margin.
LI Wei,WANG Xueke,ZHANG Benjian,CHEN Zhuxin,PEI Senqi,YU Zhichao[3]（2020）在《Large-scale gas accumulation mechanisms and reservoir-forming geological effects in sandstones of Central and Western China》文中研究表明Large-scale gas accumulation areas in large oil-gas basins in central and Western China have multiple special accumulation mechanisms and different accumulation effects. Based on the geological theory and method of natural gas reservoir formation, this study examined the regional geological and structural background, formation burial evolution, basic characteristics of gas reservoirs, and fluid geology and geochemistry of typical petroliferous basins. The results show that the geological processes such as structural pumping, mudstone water absorption, water-soluble gas degasification and fluid sequestration caused by uplift and denudation since Himalayan stage all can form large-scale gas accumulation and different geological effects of gas accumulation. For example, the large-scale structural pumping effect and fluid sequestration effect are conducive to the occurrence of regional ultra-high pressure fluid and the formation of large-scale ultra-high pressure gas field; mudstone water absorption effect in the formation with low thickness ratio of sandstone to formation is conducive to the development of regional low-pressure and water free gas reservoir; the water-soluble gas degasification effect in large-scale thick sandstone can not only form large-scale natural gas accumulation; moreover, the degasification of water-soluble gas produced by the lateral migration of formation water will produce regional and regular isotopic fractionation effect of natural gas, that is, the farther the migration distance of water-soluble gas is, the heavier the carbon isotopic composition of methane formed by the accumulation.
张骄[4]（2020）在《知识图谱在页岩气水力压裂项目管理中的应用研究》文中研究指明自从知识图谱分析技术出现以来,该技术的应用正逐渐呈现爆发的趋势,关于知识图谱应用方面的文献在近几年来也大量涌现,目前大多集中在管理、医疗、图书情报管理等传统的数据统计分析需求强烈的行业。尽管如此,随着知识管理的理念已经深入到社会中的各行各业,各类专业文献资料和行业文献数据库也得到了蓬勃发展,这为知识图谱技术在各行业的应用奠定了良好的基础。本文主要针对石油与天然气行业的页岩气水力压裂项目开展研究。由于目前页岩气水力压裂已成为我国天然气生产中亟需继续攻关的难点问题和目前研究的热点问题,大量与页岩气水力压裂相关的文献资料在几年来不断涌现,包括页岩气储层地质研究、资源评价、孔隙结构分析、页岩气在页岩页岩储层和水力裂缝中的流动机理、水平井分段压裂工艺等各分支领域。然而相关的大量文献知识并没有进行有效整合,很少有研究将知识图谱技术应用于石油行业,以至于将知识图谱应用于其中的页岩气水力压裂工程项目管理中更属于研究空白。本文的主要研究工作是从WOS和中国知网数据库中获取文献并构建页岩气水力压裂工程项目的知识图谱。首先从WOS数据库中获取相关的文献信息,借助于CiteSpace等软件工具得到15616条文献信息,并进一步处理后,通过聚类分析技术得到17个有效聚类,然后对各个聚类所代表的主题和内容进行详细分析。然后从中国知网数据库中检索获得3295条相关文献记录,并在已有的聚类基础上从高突现关键词、高中介中心性关键词以及关键词随时间的变迁等方面分析当前国内的页岩气水力压裂的研究前沿。通过以上分析,可以完整的建立页岩气水力压裂的知识图谱,并能够前瞻性地指导项目的整体运作、资源配置、时间管理和风险管理等该类项目管理的各个方面,这对于我国今后能够安全高效地开发页岩气具有重要的指导和借鉴意义。
SUN Tengjiao,LUO Xiaoping,QING Hairuo,KOU Xueling,SHENG Zhongming,XU Guosheng,ZUO Yinhui[5]（2020）在《Characteristics and Natural Gas Origin of Middle-Late Triassic Marine Source Rocks of the Western Sichuan Depression, SW China》文中进行了进一步梳理A scientific exploration well（CK1） was drilled to expand the oil/gas production in the western Sichuan depression, SW, China. Seventy-three core samples and four natural gas samples from the Middle–Late Triassic strata were analyzed to determine the paleo-depositional setting and the abundance of organic matter（OM） and to evaluate the hydrocarbon-generation process and potential. This information was then used to identify the origin of the natural gas. The OM is characterized by medium n-alkanes(n C15–n C19), low pristane/phytane and terrigenous aquatic ratios（TAR）, a carbon preference index（CPI） of ～1, regular steranes with C29 > C27 > C28, gammacerane/C30 hopane ratios of 0.15–0.32, and δDorg of-132‰ to-58‰, suggesting a marine algal/phytoplankton source with terrestrial input deposited in a reducing–transitional saline/marine sedimentary environment. Based on the TOC, HI index, and chloroform bitumen "A" the algalrich dolomites of the Leikoupo Formation are fair–good source rocks; the grey limestones of the Maantang Formation are fair source rocks; and the shales of the Xiaotangzi Formation are moderately good source rocks. In addition, maceral and carbon isotopes indicate that the kerogen of the Leikoupo and Maantang formations is type Ⅱ and that of the Xiaotangzi Formation is type Ⅱ–Ⅲ. The maturity parameters and the hopane and sterane isomerization suggest that the OM was advanced mature and produced wet–dry gases. One-dimensional modeling of the thermal-burial history suggests that hydrocarbon-generation occurred at 220–60 Ma. The gas components and C–H–He–Ar–Ne isotopes indicate that the oilassociated gases were generated in the Leikoupo and Maantang formations, and then, they mixed with gases from the Xiaotangzi Formation, which were probably contributed by the underlying Permian marine source rocks. Therefore, the deeply-buried Middle–Late Triassic marine source rocks in the western Sichuan depression and in similar basins have a great significant hydrocarbon potential.
HUANG Shipeng,DUAN Shufu,WANG Zecheng,JIANG Qingchun,JIANG Hua,SU Wang,Feng Qingfu,HUANG Tongfei,YUAN Miao,REN Mengyi,CHEN Xiaoyue[6]（2019）在《Affecting factors and application of the stable hydrogen isotopes of alkane gases》文中进行了进一步梳理To study the composition, affecting factors of the stable hydrogen isotopes of alkane gases and their application to identification of the natural gas origin and maturities, the chemical and isotopic compositions of 118 gas samples of Carboniferous-Permian in the Ordos Basin, and of Triassic in the Sichuan Basin, combined with 68 gas samples from the Sinian and Cambrian reservoirs in the Sichuan Basin, and Ordovician and Siliurian reservoirs of Tarim Basin, are analyzed comprehensively. The following conclusions are obtained:（1）Natural gases in the study area and strata of the Ordos and Sichuan basins are dominated by alkane gases, and the dryness coefficients and maturities of the Carboniferous-Permian gases in the Ordos Basin are higher than the gases in the Triassic Xujiahe Formation of the Sichuan Basin, while the hydrogen isotopes of the latter ones are much enriched in 2 H than the former.（2） The δ2 HCH4-C1/C2+3 genetic identification diagram of natural gas was drawn, and the diagrams of hydrogen isotopic differences between the heavy alkane gases and methane vs. hydrogen isotopes of alkane gases can also be used in natural gas genetic identification.（3） The δ2 HCH4-Ro formulas of coal-formed gas in different areas of the two basins are given, and the δ2 HC2 H6-δ2 HCH4 is a new index for maturity, and the(δ2 HC2 H6-δ2 HCH4)-Ro formula of the coal-formed gas can be used to calculate the maturity of the natural gas.（4） The stable hydrogen isotopes of alkane gases are affected by parent materials in source rocks, maturity, mixing and the aqueous medium conditions, among which the aqueous paleo-salinity is the key factor. To sum up, the hydrogen isotopes of alkane gases are affected by multiple factors, and they are significant to the identification of the origin, and maturity of natural gas, and the water environment during the deposition of source rocks.
YANG Jihai,HUANG Baojia[7]（2019）在《Origin and migration model of natural gas in L gas field, eastern slope of Yinggehai Sag, China》文中认为Based on the chemical and stable carbon isotopic composition of natural gas and light hydrocarbons, along with regional geological data, the genetic type, origin and migration of natural gases in the L lithologic gas field, the eastern slope of Yinggehai Sag were investigated. The results show that these gases have a considerable variation in chemical composition, with 33.6%–91.5% hydrocarbon, 0.5%–62.2% CO2, and dryness coefficients ranging from 0.94 to 0.99. The alkane gases are characterized by d13 C1 values of –40.71‰––27.40‰, d13 C2 values of –27.27‰––20.26‰, and the isoparaffin contents accounting for 55%–73% of the total C5–C7 light hydrocarbons. These data indicate that the natural gases belong to the coal-type gas and are mainly derived from the Miocene terrigenous organic-rich source rocks. When the CO2 contents are greater than 10%, the d13 CCO2 values are –9.04‰ to – 0.95‰ and the associated helium has a 3 He/4 He value of 7.78×10–8, suggesting that the CO2 here is crustal origin and inorganic and mainly sourced from the thermal decomposition of calcareous mudstone and carbonate in deep strata. The gas migrated in three ways, i.e., migration of gas from the Miocene source rock to the reservoirs nearby; vertical migration of highly mature gas from deeper Meishan and Sanya Formations source rock through concealed faults; and lateral migration along permeable sandbodies. The relatively large pressure difference between the "source" and "reservoir" is the key driving force for the vertical and lateral migration of gas. Short-distance migration and effective "source-reservoir" match control the gas distribution.
Muhammad Kashif[8]（2019）在《渤海湾盆地南堡凹陷2、3号构造带沙一段深层优质砂岩储层特征及成因》文中研究指明渤海湾盆地南堡凹陷沙一段深层砂岩主要为湖泊与辫状河三角洲砂体,优质储层与泥岩互层发育。通过扫描电镜、阴极发光、碳氧同位素、包裹体测温、X衍射、激光共聚焦、岩石薄片及压汞等不同的手段和技术评估了储层特征。沙一段深层砂岩除了次生孔隙,还发育较多原生孔隙,储集性能较好。强非均质性是制约油气勘探和开发的重要原因。本论文系统研究了沙一段深层砂岩非均质性在岩石学、组构和孔隙等方面特征。综合利用岩心描述、测井及地震解释技术刻画了研究区砂岩储层的构造及层序地层格架;依据岩心观察数据分析了岩相类型并解释了沉积成因;通过薄片观察、XRD、SEM、CLSM及CL等多种分析手段综合运用,分析了砂岩结构、构造以及原生、次生矿物。本论文旨在对储层特征进行评价,系统分析成岩作用对储层性能的影响。统计数据、薄片分析和激光扫描共聚焦显微数据使储层特征的评价更为可靠。研究区Es1砂岩主要沉积在浅湖、半深湖及辫状河三角洲环境中。除了泥岩、粉砂岩和细砂岩在不同层的连续沉积之外,沉积的非均质性及不同成岩过程还受到粒级和分选的控制。压实作用、胶结作用、成分成熟度、长石溶蚀作用、岩石不稳定组分及裂缝发育共同控制了成岩作用的多样性,导致了储层质量的差异性。粘土矿物阻塞孔隙,降低储层质量;绿泥石作为颗粒包壳局部发育,保存了原生孔隙;而高岭石、伊利石及伊蒙混层则作为胶结物阻塞孔隙,降低了储层物性。通过高压压汞数据研究了储层孔隙大小分布及Es1砂岩的非均质性。孔隙度和渗透率是储层的重要特征,代表了为储层流体提供的储集空间和运移通道。而孔隙大小分布建立了一种孔喉连通性及其对储层质量的影响之间的联系。综合利用数据和结论评价了储层储集空间类型及大小。孔喉相关数据主要来自高压压汞,最大孔喉半斤介于0.006至?63μm,平均孔喉半径介于0.073μm至15.492μm之间。压汞数据表明了中孔和小孔的分布特征,与粒间孔主导,而强胶结砂岩表现出高晶间微孔的特征相匹配。裂缝和溶蚀作用增加了深层砂岩的孔隙度。通过扫描电镜、激光扫描共聚焦显微镜和铸体薄片对次生孔隙进行了评价。有效断裂可以作为油气运移通道。强烈的长石溶蚀作用产生次生孔隙,说明了酸性成岩环境对次生孔隙的影响。断层及裂缝延伸至深部地层,为大气淡水在重力作用下的运移提供了有利条件,导致了Es?地层水的稀释和岩石的溶蚀。由于温度、压力以及浓度的差异性,深部流体同样会通过断层和裂缝运移至浅层,形成了地下流体的循环对流体系。这些地下流体在深部长石的溶蚀和碳酸盐矿物的转化方面起到了重要作用。有机质热解形成了大量的CO2和有机酸。酸性流体对次生孔隙的产生至关重要,明显提升了深部储层物性。因此,研究区储层次生孔隙的主要成因是有机酸及CO2溶蚀作用。辫状河相及心滩砂体孔隙度高于曲流河相及湖泊相（区域I）。辫状河道储层孔隙度高,其次为曲流河相及河道亚相,泛滥平原储层物性最差（区域II）。在区域III,流体超压数据表明,浅层形成的流体超压有效抑制了压实作用,随着埋深的增加,颗粒接触关系逐由点接触渐演变为点-线及线-线或者缝合接触。因此浅层形成的超压有助于深部优质储层的形成。此外,油气充注抑制了碳酸盐胶结,早期油气充注同样对优质储层的形成意义重大。
Quanyou LIU,Dongya ZHU,Qingqiang MENG,Jiayi LIU,Xiaoqi WU,Bing ZHOU,Qi FU,Zhijun JIN[9]（2019）在《The scientific connotation of oil and gas formations under deep fluids and organic-inorganic interaction》文中研究指明As a relatively stable craton block in the earth system, the petroliferous basin is influenced by the evolution of the earth system from the early development environment of source rocks, hydrocarbon formation, and reservoir dissolution to hydrocarbon accumulation or destruction. As a link between the internal and external factors of the basin, deep fluids run through the whole process of hydrocarbon formation and accumulation through organic-inorganic interaction. The nutrients carried by deep fluids promote the bloom of hydrocarbon-generating organisms and extra addition of carbon and hydrogen source, which are beneficial to the development of high-quality source rock and enhancement of the hydrocarbon generation potential. The energy carried by the deep fluid promotes the early maturation of the source rock and facilitates the hydrocarbon generation by activation and hydrogenation in high-mature hydrocarbon sources. The dissolution alteration of carbonate rocks and clastic reservoirs by CO2-rich deep fluids improves the deep reservoir space, thus extending the oil and gas reservoir space into greater depth. The extraction of deeply retained crude oil by deep supercritical CO2 and the displacement of CH4 in shale have both improved the hydrocarbon fluidity in deep and tight reservoirs. Simultaneously, the energy and material carried by deep fluids（C, H, and catalytic substances） not only induce inorganic CH4 formation by Fischer-Tropsch（F-T） synthesis and "hydrothermal petroleum" generation from organic matter by thermal activity but also cause the hydrothermal alteration of crude oil from organic sources. Therefore, from the perspective of the interaction of the earth’s sphere, deep fluids not only input a significant amount of exogenous C and H into sedimentary basins but also improve the reservoir space for oil and gas, as well as their enrichment and accumulation efficiencies.
ZOU Caineng,TAO Shizhen,HAN Wenxue,ZHAO Zhenyu,MA Weijiao,LI Changwei,BAI Bin,GAO Xiaohui[10]（2018）在《Geological and Geochemical Characteristics and Exploration Prospect of Coal-Derived Tight Sandstone Gas in China: Case Study of the Ordos, Sichuan, and Tarim Basins》文中进行了进一步梳理This work extensively investigated global tight sandstone gas, and geologically and geochemically analyzed the tight sandstone gas in China’s Ordos, Sichuan, and Tarim basins. We compared typical tight sandstone gas in China with that in North America. We proposed six conditions for the formation of China’s tight sandstone gas, and illustrated the geological characteristics of tight sandstone gas. In China, gas-bearing tight sandstones were mainly deposited in continental lake deltas and marine-terrigenous facies basin environments, associated with coal-measure strata, and were mostly buried deeper than 2000 m under a formation pressure of 20–30 MPa, with pressure coefficients varying from overpressure to negative pressure. In other countries, tight gas bearing sandstones were dominantly deposited in marine to marine-terrigenous facies environments, occurred in coal-measure strata, and were mostly buried shallower than 2000 m in low-pressure systems. We systematically analyzed tight sandstone gas in the Ordos, Sichuan, and Tarim basins in terms of chemical compositions, geochemical characteristics of carbon isotopes, origins, and sources. Tight sandstone gas in China usually has a hydrocarbon content of >95%, with CH4 content >90%, and a generally higher dry coefficient. In the three above-mentioned large tight sandstone gas regions, δ13 C1 and δ13 C2 mainly ranges from-42‰ to-28‰ and from-28‰ to-21‰, respectively. Type III coal-measure source rocks that closely coexist with tight reservoirs are developed extensively in these gas regions. The organic petrology of source rocks and the carbon isotope compositions of gas indicate that tight sandstone gas in China is dominantly coal-derived gas generated by coal-measure strata. Our analysis of carbon isotope series shows that local isotope reversals are mainly caused by the mixing of gases of different maturities and that were generated at different stages. With increasing maturity, the reversal tendency becomes more apparent. Moreover, natural gas with medium-low maturity（e.g., Xujiahe Formation natural gas in the Sichuan Basin） presents an apparent reversal at a low-maturity stage, a normal series at a medium-maturity stage, and a reversal tendency again at a high-maturity stage. Finally, we proposed four conditions for preferred tight sandstone gas "sweep spots," and illustrated the recoverable reserves, proven reserves, production, and exploration prospects of tight sandstone gas. The geological and geochemical characteristics, origins, sources, and exploration potential of tight sandstone gas in China from our research will be instructive for the future evaluation, prediction, and exploration of tight sandstone gas in China and abroad.
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| Introduction |
| 1. Geological setting |
| 2. Basic oil and gas geological conditions |
| 2.1. Source rocks |
| 2.2. Reservoirs |
| 2.3. Caprocks |
| 3. Hydrocarbon accumulation and evolution in different structural environments of cratons |
| 3.1. Basic characteristics of oil and gas fields |
| 3.2. Hydrocarbon accumulation and evolution in the periphery of intracratonic rifts |
| 3.2.1. Oil and gas sources |
| 3.2.2. Hydrocarbon charging |
| 3.2.3. Stages of hydrocarbon accumulation and evolution |
| 3.3. Hydrocarbon accumulation and evolution in the periphery of intracratonic depressions |
| 3.3.1. Oil and gas sources |
| 3.3.2. Oil and gas charging |
| 3.3.3. Stages of hydrocarbon accumulation and evolution |
| 3.4. Evolution of potential oil and gas accumulations in craton periphery rifts |
| 4. Major controlling factors of hydrocarbon accumulation |
| 4.1. Major hydrocarbon generation center |
| 4.2. High-quality large-scale reservoir-caprock assemblage |
| 4.3. Stable trap conditions |
| 5. Favorable exploration directions |
| 5.1. Periphery of the intracratonic rift |
| 5.2. Periphery of intracratonic depression |
| 5.3. Craton margin |
| 6. Conclusions |
| Introduction |
| 1. Pumping and the geological effects of natural gas accumulation |
| 2. Water absorption and the geological effect of natural gas accumulation |
| 3. Degasification and the geological effect of natural gas accumulation |
| 3.1. Water-soluble gas depressurization-induced |
| 3.2. Water-soluble gas concentration-induced degasification and accumulation,and reservoir-forming effect |
| 4. Sequestration and the geological effect of natural gas reservoir formation |
| 4.1. Geological characteristics of sequestration |
| 4.2. Natural gas reservoir formation caused by seques-tration |
| 5. Conclusions |
| 学位论文数据集 |
| 摘要 |
| Abstract |
| 第一章 绪论 |
| 1.1 论文研究背景与意义 |
| 1.1.1 研究背景 |
| 1.1.2 研究目的 |
| 1.1.3 研究意义 |
| 1.2 论文研究内容及思路 |
| 1.2.1 主要研究内容 |
| 1.2.2 研究思路 |
| 1.2.3 研究方法 |
| 1.2.4 技术路线 |
| 1.3 论文的创新点 |
| 第二章 相关理论简述 |
| 2.1 页岩气开发 |
| 2.1.1 页岩气 |
| 2.1.2 全球页岩气开发简况 |
| 2.2 水力压裂技术 |
| 2.2.1 水力压裂技术的起源与发展 |
| 2.2.2 水力压裂技术在页岩气行业中的应用现状 |
| 2.3 知识图谱 |
| 2.3.1 知识图谱的概念 |
| 2.3.2 知识图谱的现有研究技术 |
| 2.3.3 石油行业知识图谱 |
| 2.4 项目管理 |
| 2.5 知识图谱与项目管理 |
| 第三章 知识图谱构建 |
| 3.1 WOS数据获取与处理 |
| 3.2 WOS结果分析 |
| 3.2.1 提取研究热点术语 |
| 3.2.2 聚类信息分析 |
| 3.3 中国知网数据获取与处理 |
| 3.4 中国知网结果分析 |
| 3.4.1 高突现性关键词分析 |
| 3.4.2 高中介中心性关键词分析 |
| 3.4.3 关键词的变迁分析 |
| 3.5 页岩气水力压裂知识图谱构建 |
| 第四章 知识图谱在页岩气水力压裂项目管理中的应用 |
| 4.1 页岩气水力压裂项目整合管理 |
| 4.1.1 制定页岩气水力压裂项目章程 |
| 4.1.2 制定页岩气水力压裂项目管理计划 |
| 4.1.3 指导与管理页岩气水力压裂项目工作 |
| 4.1.4 管理页岩气水力压裂项目知识 |
| 4.1.5 监控页岩气水力压裂项目工作 |
| 4.1.6 实施页岩气水力压裂整体变更控制 |
| 4.1.7 结束页岩气水力压裂项目或阶段 |
| 4.2 页岩气水力压裂项目范围管理 |
| 4.3 页岩气水力压裂项目时间管理 |
| 4.3.1 定义、排列页岩气水力压裂项目活动 |
| 4.3.2 制定、控制页岩气水力压裂项目进度计划 |
| 4.4 页岩气水力压裂项目资源管理 |
| 4.5 页岩气水力压裂项目风险管理 |
| 4.6 小结 |
| 第五章 总结与展望 |
| 5.1 论文总结 |
| 5.2 论文的创新之处 |
| 5.3 论文的不足与未来展望 |
| 参考文献 |
| 附录 |
| 致谢 |
| 作者和导师简介 |
| 专业学位硕士研究生学位论文答辩委员会决议书 |
| Introduction |
| 1. Geological setting and characteristics of the gas field |
| 1.1. Geological setting |
| 1.2. Geological features of the L lithological gas field |
| 2. Geochemical characteristics and genetic type of natural gas |
| 2.1. Chemical composition of natural gas |
| 2.2. Carbon isotope characteristics and genetic type of gas |
| 2.2.1. Carbon isotope composition and genetic type of hydrocarbon gas |
| 2.2.2. Isotopic compositions and origin of carbon dioxide |
| 2.3. Light hydrocarbon composition and genetic type of alkane gas |
| 3. The source rock and gas-source correlation |
| 3.1. The source rocks |
| 3.2. Correlation of gas-gas and gas-source rock |
| 4. Discussion on considerable variation in chemical and carbon isotopic compositions of gases |
| 4.1. Variation of gas composition |
| 4.2. Cause of the considerable variation of carbon isotope composition of alkane gas |
| 5. Gas migration model |
| 5.1. Abundant gas supply |
| 5.2. Large pressure difference between source and reservoir providing key driving force |
| 5.3. Multi-charging ways through hidden faults and per-meable sandbody carriers |
| 6. Conclusions |
| 摘要 |
| Abstract |
| Key Findings |
| Chapter 1 Introduction |
| 1.1 Introduction |
| 1.2 Motivation |
| 1.3 Database and Methods |
| 1.3.1 Sampling |
| 1.3.2 Research Methods |
| 1.4 Objectives |
| Chapter 2 Geological and Geographical Overview |
| 2.1 Bohai Bay Basin |
| 2.1.1 Huanghua Depression |
| 2.1.2 Nanpu Sag |
| 2.2 Stratigraphic Framework of the Area |
| 2.2.1 The Lower Tertiary System |
| 2.2.2 The Upper Tertiary System |
| 2.2.3 Shahejie Formation(Es) |
| Chapter 3 Sedimentary Facies and Depositional Architectures |
| 3.1 Background Knowledge |
| 3.2 Results |
| 3.2.1 Sedimentary Facies Characteristics |
| 3.2.2.Facies Indicators |
| 3.2.3.Petrographic Features of Lithofacies |
| 3.3 Discussion |
| Chapter 4 Diagenesis of Sandstone Reservoirs |
| 4.1 Background Knowledge |
| 4.2.Results |
| 4.2.1.Sandstone Composition |
| 4.2.2 Diagenesis |
| 4.2.3 Diagenetic Mineralogy |
| 4.2.4 Fluid Inclusion |
| 4.2.5 Isotopic Composition |
| 4.3 Discussion |
| 4.3.1 Source of Carbonate Cement |
| 4.3.2 Source of Quartz Cement |
| 4.3.3 Paragenetic Sequence of Diagenesis |
| Chapter 5 Characteristics of Sandstone Reservoir |
| 5.1 Background Knowledge |
| 5.2 Results |
| 5.2.1.Reservoir Porosity and Permeability |
| 5.2.2 Reservoir Properties |
| 5.2.3 Pore Size Distribution(PSD) |
| 5.2.4 Pore Throat Characteristics |
| 5.2.5 Reservoir Types |
| 5.3 Discussion |
| 5.3.1 Relationship between Pore Structure Parameter and Physical Property |
| 5.3.2 Mineral Composition Association with Pore Structure |
| Chapter 6 Genetic Mechanism of the High Quality Reservoir |
| 6.1 Background Knowledge |
| 6.2 Results |
| 6.2.1 Diagenetic Setting and Dissolution |
| 6.2.2 Grain Support |
| 6.2.3 Tectonism |
| 6.2.4 Porosity Improvement by Feldspar Dissolution |
| 6.2.5 Dissolution of Carbonate Minerals |
| 6.3 Porosity Preservation Geological Process |
| 6.3.1 Sedimentary Facies |
| 6.3.2 Fluid Overpressure |
| 6.3.3 Hydrocarbon Emplacement |
| 6.4 Discussion |
| 6.4.1 The Depositional Impact on Reservoir Formation |
| 6.4.2 The Impact of Compaction and Cementation on Reservoir Formation |
| 6.4.3 The Influence of Replacement on Reservoir Formation |
| 6.4.4 Tectogenesis Fractures Impact on Reservoir Formation |
| 6.4.5 Impact of Dissolution on Reservoir Formation |
| 6.4.6 Impact of Reservoir Pore space on Reservoir Formation |
| 6.4.7 Diagenetic Control on Reservoir |
| Summary and Conclusion |
| References |
| Research Achievements |
| 1-Research Papers |
| 2-Conferences/Symposiums(oral/poster presentations) |
| Acknowledgements |
| Author's CV |
| 1. Introduction |
| 2. Influence of deep fluids on the formation of organic-rich matter |
| 2.1 The genetic problems of deep CO2and CH4 |
| 2.2 Nutrients carried by deep fluid raise the blooming/breeding of hydrocarbon-generating organisms |
| 2.3 The advantages of a reducing environment to the preservation of organic matters |
| 2.4“Earlymaturation”of source rocks as supported by the energy carried by deep fluids |
| 3. Hydrocarbon regeneration from sources (source rocks and reservoir bitumen) under the activity of hydrogen-rich fluids |
| 3.1 Hydrocarbon generation potential of source rocks enhancement of H-rich fluid |
| 3.2 Activation and hydrocarbon regeneration (catalytic |
| 3.3 F-T synthesis promotion of methane by rnergy and materials varried by feep fluids |
| 4. The dissolution alteration of reservoirs and caprocks by deep fluids |
| 4.1 The dissolution alteration of carbonate rocks by deep fluids |
| 4.2 The dissolution alternation of deep fluid to the clastic rock |
| 4.3 The enhancement of the sealing capacity of mud-stone caprock by deep fluid |
| 4.4 Early diagenesis promotes the formation of mi-crobialite |
| 5. The dynamic effect of deep fluid on the mi-gration and accumulation of deep oil and gas |
| 5.1 Supercritical CO2extraction of deep crude oil |
| 5.2 The displacement of shale gas by supercritical CO2 |
| 5.3 Changes in the physicochemical properties of crude oil (hydrothermal petroleum) brought by energy carried by deep fluids |
| 5.4 The enrichment of gas such as H2and He as pro-moted by deep fluids |
| 6. Conclusion |
| 1 Introduction |
| 2 Overview of Coal-Derived Tight Sandstone Gas in China |
| 3 Forming Conditions and GeologicalCharacteristics of Coal-derived Tight Sandstone Gas in China |
| 3.1 Differences of tight sandstones gas between China and other countries |
| 3.2 Tight sandstone gas formation conditions |
| 3.3 Geological characteristics of tight sandstone gas |
| 3.3.1 Tight sandstone gas properties |
| 3.3.2 Tight sandstone gas pressure system |
| 3.3.3 Tight sandstone gas geological characteristics |
| 4 Geochemical Characteristics of Coal-Derived Tight Sandstone Gas in China |
| 4.1 Analysis method |
| 4.2 Geochemical characteristics of coal-derived tight sandstone gas |
| 4.2.1 Chemical composition of coal-derived tight sandstone gas |
| 4.2.2 Carbon isotope composition of coal-derived tight sandstone gas |
| 4.2.3 Change of carbon isotope series in tight sandstone alkane gas |
| 4.3 Origin and source of coal-derived tight sandstone gas |
| 5 Discussions:“Sweet Spot”Selection andExploration Potential of Coal-derived Tight Sandstone Gas in China |
| 5.1 Selection principle of“sweet spot”in tight sandstone gas |
| 5.2 Technically recoverable resources of tight sandstone gas |
| 5.3 Proven reserves of tight sandstone gas |
| 5.4 Production of tight sandstone gas |
| 5.5 Development prospect of tight sandstone gas |
| 6 Conclusions |
