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阿拉斯加北坡盆地成藏组合划分与资源潜力评价

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现代地质 2024年第2期38卷 322-334页

作者：李刚孟秋含张凯逊白国平胡靖靖邱海华陈君中国石油大学(北京)地球科学学院北京102249 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 中国地质大学(北京)能源学院北京100083 中海油研究总院有限责任公司北京100028 中国地质科学院地质力学研究所北京100081

位于北极地区的阿拉斯加北坡盆地(North Slope Basin, Alaska)是全球最具有勘探潜力的盆地之一。对该盆地进行科学研究,有助于提升对北极地区含油气远景的认知,对于我国在该地区能源战略的制定具有基础性意义。本文基于埃信华迈(IHS Mar... 详细信息

位于北极地区的阿拉斯加北坡盆地(North Slope Basin, Alaska)是全球最具有勘探潜力的盆地之一。对该盆地进行科学研究,有助于提升对北极地区含油气远景的认知,对于我国在该地区能源战略的制定具有基础性意义。本文基于埃信华迈(IHS Markit)最新数据资料,在盆地油气地质特征分析的基础上,进行含油气系统和成藏组合划分与研究。以成藏组合为评价单元,对盆地待发现油气资源量进行评估,并优选出有利勘探区带。结果表明,阿拉斯加北坡盆地已发现油气藏主要分布于巴罗(Barrow)穹隆,该构造单元内的油气储量占盆地总储量的77.3%;油气主要储于白垩系和三叠系储集层,两者分别储集了盆地内44.0%和45.8%的油气储量。盆地内主要发育中生界复合含油气系统、新生界含油气系统和石炭系含油气系统。中生界复合含油气系统可划分出古近系—新近系、白垩系、侏罗系、三叠系和石炭系5个成藏组合。盆地平均待发现可采资源量为36943.8 MMbbl(百万桶,1桶=158.98 L)石油、79711.6 Bcf(十亿立方英尺,1英尺=30.48 cm)天然气和262.1 MMbbl凝析油,合计50491.2 MMboe(百万桶油当量),其中石油占73.1%,天然气占26.3%,凝析油占0.6%。根据本文的研究,优选出2个Ⅰ类有利区带和4个Ⅱ类有利区带。

关键词：阿拉斯加成藏要素成藏组合资源评价有利区带

环印度洋地区被动陆缘盆地构造沉积演化及其对成藏要素的控制作用

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沉积与特提斯地质 2024年第1期44卷 71-85页

作者：李刚贺昱搏白国平邱海华王宁尹宇寒中国石油大学(北京)地球科学学院北京102249 北京大学能源研究院北京100871 油气资源与探测国家重点实验室北京102249 中国石油塔里木油田分公司新疆库尔勒841000

环印度洋周缘被动陆缘盆地油气资源潜力巨大,是当前世界油气勘探的热点地区之一。本文基于IHS商业数据库和前人研究成果等资料,厘定了环印度洋地区被动陆缘盆地构造演化史,分析了构造演化对盆地充填结构和成藏要素的影响,并利用蒙特卡... 详细信息

环印度洋周缘被动陆缘盆地油气资源潜力巨大,是当前世界油气勘探的热点地区之一。本文基于IHS商业数据库和前人研究成果等资料,厘定了环印度洋地区被动陆缘盆地构造演化史,分析了构造演化对盆地充填结构和成藏要素的影响,并利用蒙特卡洛模拟法评估了盆地油气资源潜力,优选了有利勘探区带。研究结果表明,环印度洋地区被动陆缘盆地经历了3期构造演化阶段,依次为裂前期、同裂谷期和被动陆缘期。根据盆地演化的主导阶段,研究区内被动陆缘盆地可分为拉张边缘裂前发育型、拉张边缘断坳叠置型、拉张边缘坳陷发育型和转换边缘断坳叠置型。盆地内烃源岩主要发育于裂前期—被动陆缘早期,不同地区的主力烃源岩层系不同;储集岩主要发育于裂前期—被动陆缘晚期;区域盖层则主要发育于被动陆缘期。资源评价结果显示,研究区内重点被动陆缘盆地待发现石油、天然气和凝析油可采资源量(均值)分别为4.49×10^(8) t,15.86×10^(12) m^(3)和5.23×10^(8) t,折合成油当量137.69×10^(8) t。澳大利亚西北陆架北卡那封盆地裂前中—上三叠统区带、东非地区鲁伍马盆地北部和坦桑尼亚盆地南部中白垩统—新近系三角洲-深水扇区带是最有潜力的勘探区带。

关键词：环印度洋被动陆缘盆地构造演化成藏要素资源评价

Diagenesis and Fluid Flow History in Sandstones of the Upper Permian Black Jack Formation, Gunnedah Basin, Eastern Australia

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Acta Geologica Sinica(English Edition) 2007年第3期81卷 433-441页

作者： bai guoping John B. KEENE Key Laboratory for Hydrocarbon Accumulation of Education Ministry China University of Petroleum Beijing 102249 China School of Geosciences University of Sydney NSW 2006 Australia

The fluid flow history during diagenesis of sandstones in the Upper Permian Black Jack Formation of the Gunnedah Basin has been investigated through integrated petrographic observations, fluid inclusion investigations and stable isotope analyses. The early precipitation of mixed-layer illite/smectite, siderite, calcite, ankerite and kaolin proceeded at the presence of Late Permian connate meteoric waters at temperatures of up to 60℃. These evolved connate pore waters were also parental to quartz, which formed at temperatures of up to 87℃. The phase of maximum burial was characterized by development of filamentous illite and late calcite at temperatures of up to -90℃. Subsequent uplifting and cooling led to deep meteoric influx from surface, which in turn resulted in dissolution of labile grains and carbonate cements, and formation of second generation of kaolin. Dawsonite was the last diagenetic mineral precipitated and its formation is genetically related to deep-seated mamagtic sourced CO2.

关键词： diagenesis fluid flow history Gunnedah Basin fluid inclusion stable isotope

白垩纪特提斯域原型盆地与岩相古地理及其控油气作用

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石油与天然气地质 2024年第3期45卷 658-672页

作者：黄彤飞张光亚罗贝维喻志骅张磊何治亮白国平尹继全祝厚勤殷进垠姚健欢中国石油勘探开发研究院北京100083 北京大学能源研究院北京100871 中国石油油气和新能源分公司北京100007 中国石油天然气集团有限公司综合管理部北京100007

研究特提斯域在白垩纪的古构造格局、原型盆地及岩相古地理特征,对于深化特提斯域油气富集规律认识具有重要作用。在聚焦早白垩世(125 Ma±)和晚白垩世(90 Ma±)特提斯域原型盆地和岩相古地理发育特征的基础上,重点讨论了白垩纪构造、... 详细信息

研究特提斯域在白垩纪的古构造格局、原型盆地及岩相古地理特征,对于深化特提斯域油气富集规律认识具有重要作用。在聚焦早白垩世(125 Ma±)和晚白垩世(90 Ma±)特提斯域原型盆地和岩相古地理发育特征的基础上,重点讨论了白垩纪构造、沉积演化对特提斯域油气成藏条件及富集的控制作用。研究结果表明:①早白垩世(125 Ma±),新特提洋处于快速张开阶段,在特提斯域近劳亚大陆一侧的欧洲—北非段、中东—中亚段主要发育被动陆缘盆地、裂谷盆地和弧后盆地,在中国西部—印度段主要发育被动陆缘盆地和弧后盆地,中国东部—东南亚段主要发育克拉通内盆地。在特提斯域近冈瓦纳大陆一侧广泛发育被动陆缘盆地。②晚白垩世(90 Ma±),新特提洋处于萎缩早期阶段,特提斯域近冈瓦纳大陆一侧被动陆缘盆地及近劳亚大陆一侧裂谷盆地与弧后盆地继承发展。③特提斯域北缘与南缘在早、晚白垩世均广泛发育厚层以砂岩+泥岩+碳酸盐岩为主的岩相组合,纵向上形成多套有利生-储-盖组合,在冈瓦纳大陆北缘的北非、中东及澳大利亚板块北部地区,油气成藏条件更为优越。④中东波斯湾地区白垩纪在相对稳定的板块构造背景下发育了被动陆缘原型盆地及滨浅海-半深海沉积,加之阿拉伯板块持续位于低纬度环境,由此形成和保存了白垩系富有机质烃源岩和多套优质储-盖组合,为大规模油气富集提供了优越的成藏条件。

关键词：油气富集岩相古地理古构造格局白垩纪原型盆地特提斯域

Prototypes,modifications,and hydrocarbon enrichment variations in basins influenced by Tethyan evolution:A comparative analysis of the Persian Gulf Basin and the Sichuan Basin

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Science China Earth Sciences 2023年第12期66卷 2871-2897页

作者： Zhiliang HE Zhijun JIN Shuangjian LI guoping bai Xueyan LV Jinrui GUO Jian GAO Jinyin YIN Yingqiang LI Dingye ZHENG China Petroleum&Chemical Corporation Beijing 100728China Institute of Energy Peking UniversityBejing 100871China SINOPEC Petroleum Exploration and Production Research Institute Beijing 102206China SINOPEC Key Laboratory of Geology and Resources in Deep Stratum Beijing 102206China

The hydrocarbon accumulation modes and differences in the Tethyan realm serve as a hot research topic in the petroleum geology community at home and *** the Persian Gulf Basin in the Middle East and the Sichuan Basin in China,situated on the southern and northern sides of the Tethyan realm,respectively,record the whole geological process of the opening and closure of the Prototethys,the Paleotethys,and the Neotethys sequentially,exhibiting anomalous hydrocarbon *** on the analysis of the plate tectonic evolution in the Tethyan realm,this study dissects the structures and hydrocarbon accumulation conditions of both *** by a systematic comparative analysis of the factors controlling hydrocarbon enrichment in the process of plate breakup and convergence in the Tethyan realm,this study proposes petroleum exploration targets in the *** results are as follows:(1)Since the Meso-Neoproterozoic,the Persian Gulf Basin and the Sichuan Basin have undergone similar tectonic evolution in the early stage but different in the late *** the influence of the formation and evolution of the Prototethys,Paleotethys,and Neotethys oceans,both basins experienced multi-stage development and modification,forming two major extension-convergence ***,both basins are characterized by the vertical orderly superimposition of various basin prototypes in the order of rift-intracratonic basin(passive continental margin)-foreland.(2)The fact that the Tethyan realm was long located at medium-low latitudes and the local anoxic environment formed in the process of plate breakup and convergence played a vital role in the formation of extensive source *** source rocks are predominantly distributed in underfilled rifts and deep depressions that were connected to the ocean in the unidirectional continental breakup process;basin-slopes and intra-shelf basins on passive continental margins;basinal lows within intracratonic basins,and underfill

关键词： Tethyan realm Unidirectional breakup and convergence Basin prototype Structural modification Hydrocarbon enrichment Exploration target Persian Gulf Basin Sichuan Basin

Main Controls on Hydrocarbon Accumulation in the Paleozoic in Central Saudi Arabia

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Petroleum Science 2007年第2期4卷 10-17页

作者： bai guoping (Key Laboratory for Hydrocarbon Accumulation under Ministry of Education, China University of Petroleum, Beijing 102249, China) China Univ Petr Key Lab Hydrocarbon Accumulat Minist Educ Beijing 102249 Peoples R China

Sandi Arabia is renown for its rich oil and gas Mesozoic. However, the discovery of Paleozoic fields in resources with the bulk of the reserves reservo/red in the the late 1980s has encouraged further exploration in the Paleozoic. This paper reviews the salient features of the Paleozoic petroleum geology in central Saudi Arabia and discusses the main factors controlling hydrocarbon accumulation in the Paleozoic. The Lower Silurian Qusaiba hot shale is the principal source rock for the hydrocarbons discovered in the Ordovician to Permian reservoirs. Of them, the Permo- Carboniferous Unayzah and Upper Ordovician Sarah Formations have the best exploration potential. The key factors controlling hydrocarbon accumulation in the Unayzah Formation are migration pathways and reservoir petrophysics. The key factors controlling hydrocarbon accumulation in the Sarah Formation are reservoir petrophysics and the development of structural traps.

关键词： Paleozoic oil and gas accumulations central Saudi Arabia main controls Qusaiba hot shale Unayzah play,Sarah play

Tectonic Evolution of the Junggar Foreland Basin in the Late Carboniferous-Permian

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Acta Geologica Sinica(English Edition) 2001年第4期75卷 398-408页

作者： CHEN Shuping, ZHANG Yiwei, TANG Liangjie and bai guoping Basin and Reservoir Research Centre, University of Petroleum, Changping, Beijing 102249 Univ Petr Basin & Reservoir Res Ctr Beijing 102249 Peoples R China

A comprehensive study has been carried out to subdivide and correlate the Upper Carboniferous and Permian sedimentary successions in the Junggar basin based on outcrops and drilling and geophysical data. The study results, combined with geological analyses of the basin's periphery and the basement, as well as studies of the sedimentary rocks within the basin, the unconformities, tectonic geometry, kinematics and geodynamics, lead to the conclusion that the Junggar basin was characterized by the development of foreland basin systems during the Late Carboniferous and Permian. During that period, three foreland basin systems were developed: (1) the northwest foreland basin system, which trended nearly north-south from Mahu to the Chepaizi Palaeo-mountain during its early stage of development and thus it was also referred to as the west foreland basin system; (2) the Karamaili foreland basin system in the east and (3) the Northern Tianshan foreland basin system in the south. These systems are different in size, development stage and time of formation. The first two are developed earlier than the third, but they are smaller in size. All the structures in the Junggar basin have resulted from the integration and superposition of structural elements in the above three systems. In general, the development of the Junggar basin can be divided into four stages. Stage I was marked by the creation and evolution of the marginal western foreland and the peripheral Karamaili foreland basin systems during the Late Carboniferous-early Early Permian (C3P1ja). Stage II was characterized by the development of complicated foreland basin systems during the middle-late Early Permian (P1jb-P1f) when the three foreland basin systems took their shapes. Stage III was the integration stage of peripheral foreland basin systems during the Middle Permian (P2) in which steady and slow tectonic subsidence prevailed. Stage IV coincided with the shrinking of foreland basin development during the Late P

关键词： Junggar basin foreland basin system tectonic evolution

Mesozoic lithofacies palaeogeography and petroleum prospectivity in North Carnarvon Basin,Australia

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Journal of Palaeogeography 2013年第1期2卷 81-92页

作者： Tao Chongzhi bai guoping Liu Junlan Deng Chao Lu Xiaoxin Liu Houwu Wang Dapeng State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum (Beijing) Basin and Reservoir Research Center China University of Petroleum(Beijing) Basin and Reservoir Research Center China University of Petroleum (Beijing) SinoChem Petroleum Exploration&Production Co. Ltd. Wireline Logging Company of GWDC

The North Carnarvon Basin, which lies in the North West Shelf of Australia, is highly rich in gas resources. As a typical passive marginal basin, it experienced the pre-rifting, early rifting, main rifting, late rifting, post-rifting sagging and passive margin stages. The basin was mainly filled with thick Mesozoic-Cenozoic sediments, of which the Mesozoic hosts the principal source, reservoir and seal intervals. Mesozoic palaeogeography has an important control on the oil and gas distribution. Triassic gas-prone source rocks of deltaic origin deter-mine the high endowment of natural gases in the North Carnarvon Basin. The more restricted distribution of oil accumulations is controlled by oil source rocks in the Upper Jurassic Dingo Claystone. The Muderong Shale deposited in the Early Cretaceous marine transgression provides the effective regional seal for the underlying oil and gas reservoirs.

关键词： North Carnarvon Basin Mesozoic lithofacies palaeogeography hydrocar-bon distribution passive margin basin

Fluid Flow History in Lower Triassic Bulgo　Sandstone,Central Sydney Basin,Australia

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Journal of Earth Science 2000年第1期19卷 49-57页

作者： bai guoping John B Keene Department of Geology and Geophysics, University of Sydney, Sydney, Australia 2006

The fluid flow history during diagenesis of the Lower Triassic Bulgo sandstone has been investigated through integrated analyses of petrography, stable isotope and fluid inclusion. Combined application of these techniques was intended to constrain the temperature, timing, chemistry and source of pore fluids during diagenetic cementation events in the Lower Triassic Bulgo sandstone. The diagenesis proceeded in two different flow regimes: early dynamic fluid flow regime and late slow static fluid flow regime. The former was characterized by a slight increase of δ( 18 O) of pore waters form estimated -15×10 -3 to -14×10 -3 with the temperature increasing from ～10 ℃ to ～75 ℃. During early diagenesis, early clays and pore filling carbonates precipitated from the pore waters. The late slow flow/static fluid regime was characterized by a rapid 18 Oenrichment process. δ( 18 O) of pore waters increased from -14×10 -3 to -5×10 -3 with the temperature increasing from 75 ℃ to 110 ℃. During the late diagenesis, kaolin (generation Ⅱ), quartz and illite crystallized. Oil migrated to the sandstones of the Bulgo sandstone during quartz cementation.

关键词： diagenesis fluid inclusion isotope fluid flow Sydney basin.