Marine and Petroleum Geology最新文献

{"title":"The role of reservoir compartmentalization in the failure of reservoirs of structurally complex accommodation zones: an example from The Morgan Accommodation Zone, Gulf of Suez, Egypt","authors":"Zakaria Hassan ,&nbsp;Mohamed S. Hammed ,&nbsp;Ahmed E. Radwan ,&nbsp;Selim S. Selim ,&nbsp;Shaimaa Abdelhaleem","doi":"10.1016/j.marpetgeo.2025.107610","DOIUrl":"10.1016/j.marpetgeo.2025.107610","url":null,"abstract":"<div><div>Compartmentalization of hydrocarbon reservoirs represents a global challenge in assessing and developing proven fields due to the necessity for a detailed survey of the field structures, burial history, and pressure system. The geological complexity arising from overlapping fault segments, kinematically linked fracture networks, and heterogeneous stratigraphic juxtapositions within accommodation zones between Gulf of Suez rift segments results in highly variable reservoir performance—yielding prolific hydrocarbon production in some fields, while others remain non-productive—and contribute to the occurrence of multiple oil-water contacts within individual producing reservoirs. We use structural restoration, basin modelling, pore pressure and fracture gradient modelling to assess the pre-rift reservoir failure and the variation of the oil-water contact in the syn-rift reservoirs of the Morgan accommodation Zone, Gulf of Suez. Our results show that: (1) pre-Miocene source rocks are too shallow for maturation due to complex fault linkages and interaction; (2) immature pre-Miocene source rocks prevent effective hydrocarbon generation and charge; (3) no overpressure above the Eocene Thebes Formation; lack of charge attributed to either immature source rocks at juxtaposition points or sealing faults; (4) a fill-to-spill mechanism governs Miocene syn-rift oil-water contact variations; deeper oil-water contact in western blocks results from better connectivity to mature source kitchens west of GS327. These results offer crucial new insights into the interplay of pressure regimes, migration routes, and reservoir compartmentalization governing hydrocarbon plays in complex accommodation zones.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"183 ","pages":"Article 107610"},"PeriodicalIF":3.6,"publicationDate":"2025-09-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145270561","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}

{"title":"New constraints on the nature and composition of the São Paulo Plateau, Santos Basin: Magmatic, continental or hybrid crust?","authors":"Michelle Cunha Graça ,&nbsp;Nick Kusznir ,&nbsp;Natasha Stanton ,&nbsp;Gianreto Manatschal ,&nbsp;Andres Mora","doi":"10.1016/j.marpetgeo.2025.107612","DOIUrl":"10.1016/j.marpetgeo.2025.107612","url":null,"abstract":"<div><div>The São Paulo Plateau (SPP), located in the Santos segment of the southeastern (SE) Brazilian margin underlying thick Cretaceous to Recent sediments, is an enigmatic feature with disputed crustal composition. Proposed crustal types include thinned continental crust, thick magmatic crust, and hybrid crust consisting of continental crust and magmatic addition. We use combined analysis of mainly geophysical datasets to investigate the crustal basement thickness and crustal type of the SPP, and the variation in timing of its rifting and magmatic addition. 2D and 3D combined analysis of deep seismic reflection and gravity anomaly data has been used to determine Moho depth, crustal thickness and basement density variation. Flexural back-stripping has been used to map sediment-corrected residual depth anomaly (RDA). A combination of observations of crustal thickness from gravity inversion, magnetic anomalies reduced to the pole, basement density from gravity-seismic joint-inversion, and RDA have been used together to distinguish and identify crustal basement types. Using these approaches, we show the distribution and coexistence of continental, hybrid and magmatic crust, as well as possible exhumed mantle in the Santos Basin.</div><div>In addition, 2D and 3D post-breakup subsidence modelling consisting of flexural back-stripping, decompaction and reverse thermal subsidence modelling has been used to determine the palaeo-datum of base and top salt at the time of salt formation. This salt palaeo-datum modelling is used to distinguish syn-tectonic from post-tectonic salt and to investigate the contrasting consequences of magmatic versus thinned continental crust on the palaeo-bathymetry of Aptian salt deposition. We show that the distribution of post-tectonic salt primarily corresponds to that of continental crust thinned by widespread early Aptian rifting while syn-tectonic salt locations correspond to that of magmatic crust extended by late Aptian rifting.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107612"},"PeriodicalIF":3.6,"publicationDate":"2025-09-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145219119","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}

{"title":"Constraining self-sourcing stratigraphic plays in North Sumatra: Integration of basin-petroleum system and stratigraphic forward modeling","authors":"Qi Adlan ,&nbsp;Barry M. Hartono ,&nbsp;Harya D. Nugraha ,&nbsp;Adhipa Herlambang ,&nbsp;Waleed AlGharbi ,&nbsp;Eriko Sabra","doi":"10.1016/j.marpetgeo.2025.107611","DOIUrl":"10.1016/j.marpetgeo.2025.107611","url":null,"abstract":"<div><div>Stratigraphic traps are typically identified and delineated using 3D seismic analysis or by integrating well data. These plays involve greater exploration uncertainty than conventional traps, especially in regions where multiple petroleum systems coexist. A notable example is the self-sourcing stratigraphic trap, where hydrocarbons migrate laterally within coeval rock formations. This challenge is particularly significant in frontier areas lacking 3D seismic data and with limited well data. Therefore, developing a reliable methodology is essential to accurately identify potential stratigraphic trap zones while effectively accounting for the complex interactions within petroleum systems.</div><div>This study integrates stratigraphic forward modeling (SFM) and basin and petroleum system modeling (BPSM) to better constrain self-sourcing stratigraphic traps. The North Sumatra Basin was selected as the study area because it features a complex petroleum system involving three source rocks and various trapping mechanisms, including stratigraphic traps from the Middle Miocene. The systematic approach demonstrated in this study involves four key stages: (1) assessing geochemical evidence, (2) using SFM to delineate trap zones, (3) simulating organic matter distribution, and (4) applying BPSM to evaluate source rock maturation and hydrocarbon expulsion. This systematic approach provides a cost-effective framework for early-stage hydrocarbon exploration, helping geoscientists de-risk prospects before committing to high-cost data acquisition like 3D seismic surveys. It is particularly suited for evaluating stratigraphic traps associated with self-sourcing plays and has potential applications in unconventional resource exploration, including shale gas. Regionally, this research provides the first geochemical evidence of oil mixing in the area and presents conclusive insights into the four active petroleum system plays, potentially redefining exploration strategies in the region.</div></div>","PeriodicalId":18189,"journal":{"name":"Marine and Petroleum Geology","volume":"182 ","pages":"Article 107611"},"PeriodicalIF":3.6,"publicationDate":"2025-09-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145154192","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}

{"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>_<em>o</em>) 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>_<em>o</em> &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}

{"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 δ¹⁸O_V-PDB (−6.3 ‰ to −3.2 ‰) and precipitation temperatures (T_h ≈ 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 δ¹³C_V-PDB (−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}

{"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 Q1₂ submember (Q1₂) 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 (n₀) and adsorbed phase methane density (ρ_ads) of the DUDQ shales range from 1.90 to 4.91 cm³/g and 0.28−0.47 g/cm³, respectively. Both n₀ and ρ_ads 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 cm³/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_ads) and total gas content (n_tot) initially tend to increase followed by a subsequent decrease, whereas the free gas content (n_free) tends to increase. Moreover, n_tot 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 × 10¹² m³.</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}

{"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}

{"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 (CO₂ and H₂S) that can negatively impact the economic prospects of the field. Previous studies have indicated that the main H₂S 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 δ³⁴S H₂S 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 H₂S 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 CO₂ being predominant; ii) The progressive increase in gas dryness (C₁/ΣC_1-5) ultimately reaching 99.9 % by the end of the experiments; iii) The carbon isotopic composition (δ¹³C) trending toward heavier values for C₁-C₃ and CO₂; and iv) The sulfur isotopic composition of H₂S approaches the δ³⁴S of sulfate. Additionally, the TSR process reduced the liquid mass by as much as 50 %, mainly focused on the gasoline range fraction (C₆-C₁₄), 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 4.8x10¹³ s⁻¹, ii) unimodal activation energy (<em>Ea</em>) in 53 kcal/mol, iii) total potential of 767 mg H₂S/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 H₂S 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}

{"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}

{"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}