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Maceral-specific evolution of molecular structure and porosity from the early oil to dry gas window in black shales 黑色页岩早期油-干气窗分子结构与孔隙度的微观特征演化
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-22 DOI: 10.1016/j.marpetgeo.2025.107609
Yingzhu Wang , Jianfa Wu , Qing Luo , Jinyou Zhang , Zhuoheng Chen , Jijin Yang
{"title":"Maceral-specific evolution of molecular structure and porosity from the early oil to dry gas window in black shales","authors":"Yingzhu Wang ,&nbsp;Jianfa Wu ,&nbsp;Qing Luo ,&nbsp;Jinyou Zhang ,&nbsp;Zhuoheng Chen ,&nbsp;Jijin Yang","doi":"10.1016/j.marpetgeo.2025.107609","DOIUrl":"10.1016/j.marpetgeo.2025.107609","url":null,"abstract":"<div><div>The chemical composition and structural evolution of organic matter (OM) controls pore development in shale reservoirs, but their intrinsic relationship during thermal maturation remains insufficiently understood. This study integrates light microscopy, scanning electron microscopy (SEM), and Raman spectroscopy to investigate microscale variations in petrological features, molecular structures, and pore characteristics across diverse maceral types in the Upper Devonian Duvernay shales, spanning a thermal maturity range of 0.5 %–3.0 % reflectance (<em>R</em><sub><em>o</em></sub>) in the West Canada Sedimentary Basin. Results show that alginite and solid bitumen undergo more pronounced compositional transformation with thermal maturation than inertinite and vitrinite, as reflected in broad ranges of Raman spectral parameters. While inertinite consistently displays the highest aromaticity, vitrinite shows a similar aromaticity with pore-filling solid bitumen after <em>R</em><sub><em>o</em></sub> &gt;1.0 %. The divergent evolutionary pathways among diverse OM macerals are attributed to the differences in biological origin and hydrocarbon generation kinetics. OM-hosted pores mainly develop in solid bitumen after the late oil window, coincident with a sharp increase in both OM aromaticity and oil expulsion. Moreover, pore-filling solid bitumen shows a higher apparent transformation ratio (15 %–25 %) and larger mean pore size (40–45 nm) than alginite-derived solid bitumen, likely due to chromatographic fractionation. Throughout the gas window, pore-filling solid bitumen accounts for &gt;90 % of the total OM-hosted porosity. Those findings advance our understanding of pore generation and evolution mechanisms across maceral types, and provide a chemical framework for predicting shale reservoir quality over a range of thermal maturities.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107609"},"PeriodicalIF":3.6,"publicationDate":"2025-09-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145154765","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Unraveling the parameters controlling diagenetic evolution in relatively shallow-buried, syn-tectonic ramp limestones (Upper Cretaceous), United Arab Emirates 阿拉伯联合酋长国上白垩统相对浅埋同构造斜坡灰岩成岩演化控制参数揭示
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-19 DOI: 10.1016/j.marpetgeo.2025.107607
Mohammad Alsuwaidi , Howri Mansurbeg , Abdullah H. Awdal , Salahadin Shahrokhi , Ali M. Al-Tameemi , Filippo Casali , Mohammed Y. Ali , Luiz Fernando De Ros , Ibrahim Q. Mohammed , Hamed Gamaleldien , Sadoon Morad
{"title":"Unraveling the parameters controlling diagenetic evolution in relatively shallow-buried, syn-tectonic ramp limestones (Upper Cretaceous), United Arab Emirates","authors":"Mohammad Alsuwaidi ,&nbsp;Howri Mansurbeg ,&nbsp;Abdullah H. Awdal ,&nbsp;Salahadin Shahrokhi ,&nbsp;Ali M. Al-Tameemi ,&nbsp;Filippo Casali ,&nbsp;Mohammed Y. Ali ,&nbsp;Luiz Fernando De Ros ,&nbsp;Ibrahim Q. Mohammed ,&nbsp;Hamed Gamaleldien ,&nbsp;Sadoon Morad","doi":"10.1016/j.marpetgeo.2025.107607","DOIUrl":"10.1016/j.marpetgeo.2025.107607","url":null,"abstract":"<div><div>This study utilizes petrographic, geochemical, and fluid-inclusion microthermometric analyses to unravel the controls on the distribution of diagenetic alterations of shallow-buried Upper Cretaceous syn-tectonic, foreland, ramp limestones of the United Arab Emirates. The diagenetic alterations are linked to porewater evolution during the tectonic evolution of the basin, as well as to the depositional facies and sequence stratigraphy. Limited improvement of reservoir quality was promoted by dissolution of allochems and formation of moldic pores. Porosity reductionensued mostly from: (i) cementation by meteoric waters and by hot basinal/hydrothermal brines with wide ranges of δ<sup>18</sup>O<sub>V-PDB</sub> (−6.3 ‰ to −3.2 ‰) and precipitation temperatures (T<sub>h</sub> ≈ 65–125 °C; salinity ≈ 16–22 wt% NaCl eq), and (ii) mechanical compaction of ductile peloids formed by micritization of allochems. Micritization, notably prevalent in the transgressive lagoon and upper ramp slope packstones, as well as in the regressive shoal grainstones below marine-flooding surfaces, led to the development of abundant microporosity. Porosity was preserved in some of the grainstones by partial calcite cementation (rims, as well as scattered equant crystals and syntaxial overgrowths), which supported the framework against mechanical compaction. Dissolution of aragonitic allochems and concomitant cementation by equant calcite was prevalent in regressive shoal grainstones during repeated episodes of subaerial exposure and meteoric-water incursion as a consequence of the syn-tectonic deposition. The δ<sup>13</sup>C<sub>V-PDB</sub> (−11.6 ‰ to +13.2 ‰; mostly −2‰ to +2 ‰) suggests derivation from marine porewaters and/or dissolution of the host limestones and, in some cases, from methanogenesis of organic matter and methane oxidation. The lack of systematic differences in porosity and permeability between the limestones from the crest and the flanks of the field is attributed to the accomplishment of most diagenetic alterations before oil emplacement.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107607"},"PeriodicalIF":3.6,"publicationDate":"2025-09-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094867","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Gas-in-place (GIP) model and resource potential of the ultra-deep Lower Cambrian gas-rich shales in the southern Sichuan Basin, China 四川盆地南部下寒武统超深层富气页岩就地气(GIP)模式及资源潜力
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-18 DOI: 10.1016/j.marpetgeo.2025.107606
Haitao Gao , Peng Cheng , Wei Wu , Chao Luo , Haifeng Gai , Liang Xu , Tengfei Li , Shangli Liu , Hui Tian
{"title":"Gas-in-place (GIP) model and resource potential of the ultra-deep Lower Cambrian gas-rich shales in the southern Sichuan Basin, China","authors":"Haitao Gao ,&nbsp;Peng Cheng ,&nbsp;Wei Wu ,&nbsp;Chao Luo ,&nbsp;Haifeng Gai ,&nbsp;Liang Xu ,&nbsp;Tengfei Li ,&nbsp;Shangli Liu ,&nbsp;Hui Tian","doi":"10.1016/j.marpetgeo.2025.107606","DOIUrl":"10.1016/j.marpetgeo.2025.107606","url":null,"abstract":"<div><div>The deep and ultra-deep Lower Cambrian Qiongzhusi (DUDQ) shales have abundant gas resources. However, the strong heterogeneity of the DUDQ shale makes it complex to accurately predict the gas-in-place (GIP) content and resource potential. The first high-yield DUDQ shale well Z201 in the southern Sichuan Basin, offering a crucial opportunity to investigate their gas-bearing characteristics. This study focuses on the Qiongzhusi Formation Q1<sub>2</sub> submember (Q1<sub>2</sub>) of well Z201, analyzes their geological characteristics, and measures its adsorption parameters through high-temperatures (60−150 °C) and high-pressures (0.01−35 MPa) methane adsorption experiments, and a geological GIP model is established to predict the shale gas resources of the DUDQ shales. The maximum absolute adsorption gas content (n<sub>0</sub>) and adsorbed phase methane density (ρ<sub>ads</sub>) of the DUDQ shales range from 1.90 to 4.91 cm<sup>3</sup>/g and 0.28−0.47 g/cm<sup>3</sup>, respectively. Both n<sub>0</sub> and ρ<sub>ads</sub> are positively correlated with total organic carbon (TOC) content and geopressures, but negatively correlated with temperature. The average adsorption capacity of inorganic matter (IM) in the DUDQ shales is 1.99 cm<sup>3</sup>/g, which, together with high TOC content, are the main important factors contributing to the high GIP contents. With increasing burial depth, the formation temperature and pressure gradually increase. Meanwhile, the adsorbed gas content (n<sub>ads</sub>) and total gas content (n<sub>tot</sub>) initially tend to increase followed by a subsequent decrease, whereas the free gas content (n<sub>free</sub>) tends to increase. Moreover, n<sub>tot</sub> is also affected by the TOC content and effective porosity. The most promising areas for the DUDQ shale gas exploration and development are the central area of the intracratonic sag and the surrounding regions of the Weiyuan anticline, with estimated shale gas resources exceeding 2.52 × 10<sup>12</sup> m<sup>3</sup>.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107606"},"PeriodicalIF":3.6,"publicationDate":"2025-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145154198","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
The static and dynamic behaviour of large faults as seals and conduits to aqueous and petroleum fluid flow at geological time-scales: Observations from the Beryl Embayment, UK North Sea 在地质时间尺度上,作为水和石油流体流动的密封和管道的大断层的静态和动态行为:来自英国北海绿柱石勘探的观测
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-14 DOI: 10.1016/j.marpetgeo.2025.107604
Philip T.S. Rose , Rene Jonk , Rachael Crowe , John Gibson , Andrew Dickson , Andrew Lind , Daniel Helgeson
{"title":"The static and dynamic behaviour of large faults as seals and conduits to aqueous and petroleum fluid flow at geological time-scales: Observations from the Beryl Embayment, UK North Sea","authors":"Philip T.S. Rose ,&nbsp;Rene Jonk ,&nbsp;Rachael Crowe ,&nbsp;John Gibson ,&nbsp;Andrew Dickson ,&nbsp;Andrew Lind ,&nbsp;Daniel Helgeson","doi":"10.1016/j.marpetgeo.2025.107604","DOIUrl":"10.1016/j.marpetgeo.2025.107604","url":null,"abstract":"<div><div>Faults play an important role in controlling flow and retention of aqueous and petroleum fluids from overpressured basin centres (“kitchens”) to basin flanks. The Beryl Kitchen is a deep overpressured basin in the Beryl Embayment on the flanks of the Viking Graben in the UK northern North Sea and provides a data rich laboratory allowing these processes to be studied in detail. In this study we combine the results of detailed structural mapping, constrained by broadband seismic and abundant well control, with reservoir pressure data and hydrocarbon geochemistry. We use the data to demonstrate how the bounding faults of the Beryl Kitchen have acted as significant capillary seals, even with abundant porous and permeable reservoir juxtaposition across the key faults. The fault plane seals allowed the baffled escape of aqueous fluids, creating fault-bounded pressure compartments, while trapping significant hydrocarbon columns at the boundary between overpressured and normally pressured reservoirs. We demonstrate how the behaviour of some of these faults has evolved with progressive burial and increasing source rock maturity in the deepest parts of the basin. On the flanks of the Beryl Kitchen these processes have resulted in the preservation of hydrocarbon accumulations with unexpectedly tall columns and an unintuitive distribution of hydrocarbon water contacts in adjacent fault blocks. These accumulations provide valuable exploration analogues for the evaluation of the hydrocarbon potential of fault bound structures at the margins of overpressured basins.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107604"},"PeriodicalIF":3.6,"publicationDate":"2025-09-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094969","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Kinetics of thermochemical sulfate reduction based on pyrolysis gold-tube experiments on lacustrine oil: Implications for H2S prediction in Brazilian pre-salt reservoirs 基于热裂解金管实验的湖相油热化学硫酸盐还原动力学:对巴西盐下储层硫化氢预测的启示
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-13 DOI: 10.1016/j.marpetgeo.2025.107600
Igor V.A.F. Souza , Yongchun Tang , Le Lu , Alexandre A. Ferreira , Geoffrey S. Ellis , Rut A. Díaz , Luiz Felipe Carvalho Coutinho , Ana Luiza S. Albuquerque
{"title":"Kinetics of thermochemical sulfate reduction based on pyrolysis gold-tube experiments on lacustrine oil: Implications for H2S prediction in Brazilian pre-salt reservoirs","authors":"Igor V.A.F. Souza ,&nbsp;Yongchun Tang ,&nbsp;Le Lu ,&nbsp;Alexandre A. Ferreira ,&nbsp;Geoffrey S. Ellis ,&nbsp;Rut A. Díaz ,&nbsp;Luiz Felipe Carvalho Coutinho ,&nbsp;Ana Luiza S. Albuquerque","doi":"10.1016/j.marpetgeo.2025.107600","DOIUrl":"10.1016/j.marpetgeo.2025.107600","url":null,"abstract":"<div><div>The Pre-salt section in the Santos Basin area is one of the largest oil discoveries in the world during the last 20 years. The reservoir fluid in this area contains non-hydrocarbon gases (CO<sub>2</sub> and H<sub>2</sub>S) that can negatively impact the economic prospects of the field. Previous studies have indicated that the main H<sub>2</sub>S generation process in Pre-salt reservoirs is thermochemical sulfate reduction (TSR). However, a more comprehensive understanding of these occurrences is required, particularly considering the reservoir temperatures (less than 120 °C) and the variations in δ<sup>34</sup>S H<sub>2</sub>S values. Moreover, there is currently no published research addressing the kinetic behavior of TSR in lacustrine oils. To better understand the origin of these non-hydrocarbon gases, TSR experiments with gold tubes were carried out to obtain information about the fluid changes, kinetic behavior, identification of fluid proxies, and to create a fluid composition model to predict H<sub>2</sub>S in exploratory areas. With increasing extent of TSR reaction, the experimentally generated gases show the following patterns: i) Large generation of non-hydrocarbon gases with CO<sub>2</sub> being predominant; ii) The progressive increase in gas dryness (C<sub>1</sub>/ΣC<sub>1-5</sub>) ultimately reaching 99.9 % by the end of the experiments; iii) The carbon isotopic composition (δ<sup>13</sup>C) trending toward heavier values for C<sub>1</sub>-C<sub>3</sub> and CO<sub>2</sub>; and iv) The sulfur isotopic composition of H<sub>2</sub>S approaches the δ<sup>34</sup>S of sulfate. Additionally, the TSR process reduced the liquid mass by as much as 50 %, mainly focused on the gasoline range fraction (C<sub>6</sub>-C<sub>14</sub>), indicating the suitability for hydrocarbon oxidation. A large amount of residual hydrocarbons was observed at the end of each experiment, reaching 33 % of the original mass under the most extensive TSR conditions. The parameters for the TSR kinetics were: i) pre-exponential factor (<em>Af</em>) of 4.8x10<sup>13</sup> s<sup>−1</sup>, ii) unimodal activation energy (<em>Ea</em>) in 53 kcal/mol, iii) total potential of 767 mg H<sub>2</sub>S/g oil. These kinetic parameters were tested in one geological scenario derived from the regional petroleum system model and compared with previous kinetic models from the literature. Two types of TSR reactions (with and without initiators/catalysts) were identified by the model predictions. The model generated with the kinetic parameters proposed by this work predicted a gas composition the closest to that observed in the modeled well. The developed kinetic model can be an important tool for better H<sub>2</sub>S prediction in exploratory areas of the Pre-salt Santos Basin.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107600"},"PeriodicalIF":3.6,"publicationDate":"2025-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094968","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Where the salt sheet ends - submarine allochthonous salt advance and hindrance, The Elda Salt Sheet, Eastern Prebetics (Southern Iberia) 盐片的终点-海底异域盐的推进和阻碍,埃尔达盐片,东部先锋队(南部伊比利亚)
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-13 DOI: 10.1016/j.marpetgeo.2025.107598
David Paul Canova , Gabriel Cofrade , Eduard Roca , Marco De Matteis , Oriol Ferrer
{"title":"Where the salt sheet ends - submarine allochthonous salt advance and hindrance, The Elda Salt Sheet, Eastern Prebetics (Southern Iberia)","authors":"David Paul Canova ,&nbsp;Gabriel Cofrade ,&nbsp;Eduard Roca ,&nbsp;Marco De Matteis ,&nbsp;Oriol Ferrer","doi":"10.1016/j.marpetgeo.2025.107598","DOIUrl":"10.1016/j.marpetgeo.2025.107598","url":null,"abstract":"<div><div>The Eastern Prebetics are part of the External Zone of the Betic Fold-and-Thrust Belt in SE Iberia where a significant amount of salt structures crops out including: diapirs, allochthonous sheets, welds, primary and secondary minibasins, and rafts. Our study focuses on the subsalt, syn-contractional, early to middle Miocene (Aquitanian-Langhian) stratigraphy of the Elda Salt Sheet, aiming to document the sub seismic scale deformation and salt-sediment interactions during allochthonous salt advance. Stratigraphic sections, halokinetic fold analysis, geologic field mapping and foraminiferal dating are used to characterize the subsalt sediments exposed in contact with the northwestern edge of the outcropping Elda Salt Sheet.</div><div>Based on the subsalt sedimentary and structural relationships we show that the Elda Salt Sheet advanced at least 8 km towards the north during the syn-orogenic Aquitanian – Langhian times before being buried during the latest Langhian - Serravallian times. This overall northward advance can be defined by six main phases. All the phases occur in submarine conditions in a carbonate ramp with water depths ranging from 10's to 100's of meters and are: (1) the extrusion of a salt sheet in an inner – outer carbonate ramp environment coeval to the onset of regional Oligocene-Miocene shortening corroborated by an Aquitanian aged flat and stranded intrasalt stringers along the subsalt flat; (2) Burdigalian-early Langhian burial of the salt sheet toe in an outer shelf – basinal environment where pinned inflation, and subsequent breakout of a confined salt sheet is evidenced by a hectometric halokinetic fold ramp and rafts of Burdigalian stratigraphy above the salt sheet. (3) early-middle Langhian rapid lateral advance of the salt sheet along a base salt flat which occurred in a deepwater basinal environment; (4) middle-late Langhian hindrance of the salt advance, development of subsalt decametric thick and decametric spaced halokinetic fold ramps in a basinal – outer shelf environment; (5) late Langhian salt sheet burial by shallow water carbonates and deepwater basinal marlstones; and (6) subsidence of secondary minibasins. These stages reflect a detailed history of a salt sheet lineage. This field-based study documents for the first time the structural and stratigraphic architecture of a subaqueous salt sheet lineage in a contractional setting.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107598"},"PeriodicalIF":3.6,"publicationDate":"2025-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094866","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Corrigendum to “Trace and rare earth element signatures in microcrystalline aragonite as indicators of oil vs. methane seepage” [Mar. Pet. Geol. 182 (2025), 107534] “微晶文石中痕量和稀土元素特征作为石油与甲烷渗漏指标”的勘误表[3 . Pet]。地球物理学报,2002,23(5):534 - 534。
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-13 DOI: 10.1016/j.marpetgeo.2025.107603
Yuedong Sun , Shanggui Gong , Jörn Peckmann , Fang Chen , Yao Guan , Dong Feng
{"title":"Corrigendum to “Trace and rare earth element signatures in microcrystalline aragonite as indicators of oil vs. methane seepage” [Mar. Pet. Geol. 182 (2025), 107534]","authors":"Yuedong Sun ,&nbsp;Shanggui Gong ,&nbsp;Jörn Peckmann ,&nbsp;Fang Chen ,&nbsp;Yao Guan ,&nbsp;Dong Feng","doi":"10.1016/j.marpetgeo.2025.107603","DOIUrl":"10.1016/j.marpetgeo.2025.107603","url":null,"abstract":"","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107603"},"PeriodicalIF":3.6,"publicationDate":"2025-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145264999","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Damage-integrated fracture prediction model for multi-stage fracture in deep carbonates: Application to the A Oilfield, Northern Tarim Basin 深层碳酸盐岩多段裂缝损伤综合裂缝预测模型——以塔北A油田为例
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-12 DOI: 10.1016/j.marpetgeo.2025.107599
He Du , Huilin Xing , Jianwei Feng , Shouyu Xu
{"title":"Damage-integrated fracture prediction model for multi-stage fracture in deep carbonates: Application to the A Oilfield, Northern Tarim Basin","authors":"He Du ,&nbsp;Huilin Xing ,&nbsp;Jianwei Feng ,&nbsp;Shouyu Xu","doi":"10.1016/j.marpetgeo.2025.107599","DOIUrl":"10.1016/j.marpetgeo.2025.107599","url":null,"abstract":"<div><div>The deeply buried Ordovician carbonates in the Tarim Basin exhibit complex fracture superposition due to polyphase tectonics, challenging prediction due to sparse well data and deep reservoir heterogeneity. This study presents an innovative fracture prediction framework for deep carbonates by integrating damage deformation mechanisms. A confining pressure-dependent fracture predictive model was established via triaxial tests, acoustic emission monitoring, and modified Mohr–Coulomb criteria, explicitly incorporating damage deformation effects on fracture parameters. Through failure tests and numerical simulation on pre-fractured rock samples, a multi-stage fracture superposition algorithm was established to account for fracture accumulation from distinct tectonic events, applied to the A Oilfield in the Northern Tarim Basin for practical validation. By commencing with detailed fault interpretation in the A Oilfield, we reconstructed tectonic evolution characteristics and identified three major fracture-forming periods through integrated analysis. By integrating rock mechanics experiments, logging data, and seismic data, geomechanical models corresponding to different tectonic phases were constructed were constructed and utilized in stress field simulations, enabling dynamic integration of multi-stage stress field simulations and fracture parameter superposition analysis. The model predicts fracture linear density (0.1–1.5 m<sup>-1</sup>) and aperture (0.5–2.75 mm) with 80 % consistency with FMI interpretations, outperforming traditional brittle models. For the A Oilfield, the results of fracture prediction directly guide the identification of high-potential exploration zones, as well as the evaluation of effective reservoirs. This study provides a mechanistic approach for deep carbonate fracture prediction, aiming to address the limitations of traditional models that overlook confining pressure effects and damage deformation. This approach not only enhances reservoir description accuracy in the A Oilfield but also offers a practical reference for similar deep carbonate basins worldwide.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107599"},"PeriodicalIF":3.6,"publicationDate":"2025-09-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094967","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Enhancing reservoir parameter prediction workflows via advanced core data augmentation 通过先进的岩心数据增强增强油藏参数预测工作流程
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-11 DOI: 10.1016/j.marpetgeo.2025.107605
Xin Luo , Xinghua Ci , Jianmeng Sun , Chengyu Dan , Peng Chi , Ruikang Cui
{"title":"Enhancing reservoir parameter prediction workflows via advanced core data augmentation","authors":"Xin Luo ,&nbsp;Xinghua Ci ,&nbsp;Jianmeng Sun ,&nbsp;Chengyu Dan ,&nbsp;Peng Chi ,&nbsp;Ruikang Cui","doi":"10.1016/j.marpetgeo.2025.107605","DOIUrl":"10.1016/j.marpetgeo.2025.107605","url":null,"abstract":"<div><div>Machine learning models that rely on core data as dataset labels have become a mainstream method for predicting reservoir parameters. However, the high costs and insufficient spatial sampling density associated with core data acquisition often result in weak nonlinear representation, poor generalization ability, and overfitting in these models. To address limited core data challenges, we propose a reliability analysis-driven workflow that optimally selects multiple core data augmentation (CDA) methods to enhance reservoir parameter prediction. This workflow achieves two primary advancements: Firstly, it mitigates data scarcity by treating core data as a minority class and applying diverse tabular data augmentation techniques to generate and rigorously evaluate reliable synthetic data. This effectively expands the useable core dataset. Secondly, leveraging this augmented data, the workflow integrates machine learning with pre-trained language models (PLMs) to develop and apply multiple combinations of augmentation-prediction models for both lithology classification and physical property parameter prediction. Field data applications demonstrate that the combination of Tabular Denoising Diffusion Probabilistic Model (TabDDPM) and Tabular Prior Data Fitting Network (TabPFN) in CDA achieves outstanding performance in evaluation metrics and case studies for lithology classification and petrophysical parameter prediction. This study provides a reproducible framework for enhancing small-sample reservoir parameter prediction in oil and gas exploration, proving that synthetic data augmentation can effectively mitigate data scarcity and open new pathways for geophysical data analysis.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107605"},"PeriodicalIF":3.6,"publicationDate":"2025-09-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145094966","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
Oil cracking with different water contents: New insights into the influence of water on the phase evolution and thermal stability of deep crude oil 不同含水率的原油裂解:水对深层原油相演化和热稳定性影响的新认识
IF 3.6 2区 地球科学
Marine and Petroleum Geology Pub Date : 2025-09-10 DOI: 10.1016/j.marpetgeo.2025.107602
Aizimaiti Maimaiti , Qi Wang , Fang Hao , Jinqiang Tian , Xianzhang Yang , Haizu Zhang , Subi Abudouaini , Fuyun Cong
{"title":"Oil cracking with different water contents: New insights into the influence of water on the phase evolution and thermal stability of deep crude oil","authors":"Aizimaiti Maimaiti ,&nbsp;Qi Wang ,&nbsp;Fang Hao ,&nbsp;Jinqiang Tian ,&nbsp;Xianzhang Yang ,&nbsp;Haizu Zhang ,&nbsp;Subi Abudouaini ,&nbsp;Fuyun Cong","doi":"10.1016/j.marpetgeo.2025.107602","DOIUrl":"10.1016/j.marpetgeo.2025.107602","url":null,"abstract":"<div><div>Water is widely distributed under geological conditions and has an significant influence on the process of oil cracking into gas. However, the mechanism of reservoir water content on the thermal stability and phase evolution of deep oil and gas reservoirs still needs further study. In this study, gold-tube pyrolysis experiments were conducted using oil, oil–water (3:2), and oil–water (1:4) mixtures, at constant heating rates of 2 °C/h and 20 °C/h. The experimental results show that water has little effect on the yield of C<sub>1-5</sub> hydrocarbons, but increases the yields of the non-hydrocarbon gases H<sub>2</sub> and CO<sub>2</sub>. The hydrogen isotopic composition of methane, ethane, and propane generated during pyrolysis experiments with added water became increasingly enriched in deuterium with increasing water content and maturity. Our results demonstrate that disproportionation and hydrogen isotope exchange between water and crude oil significantly affect both the evolution of product yields and the hydrogen isotopic signatures of generated hydrocarbons. Extrapolation of kinetic parameters at a constant heating rate of 2 °C/Ma based on the thermal history of the Tabei area in the Tarim Basin indicates that water reduces the thermal stability of crude oil, which ultimately leads to a decrease in the depth threshold for liquid hydrocarbon preservation by about 1000 m. The PVT phase simulation results show that the effect of water on the cracking behavior of crude oil is strongest at the stage of EasyRo = 1.33 %–2.19 %. At EasyRo = 1.47 %, the presence of water leads to a decrease in the cricondentherm of the crude oil by about 33.8 °C and an increase in the cricondenbar by about 2.46 MPa.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107602"},"PeriodicalIF":3.6,"publicationDate":"2025-09-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145060253","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":2,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 0
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