Petroleum Geoscience最新文献

{"title":"The role of organic carbon in the Southern Uplands-Down-Longford Terrane accretionary prism, Scotland and Ireland","authors":"J. Parnell, J. Armstrong, N. Blamey, A. Boyce, A. Schito, D. Muirhead","doi":"10.1144/petgeo2022-059","DOIUrl":"https://doi.org/10.1144/petgeo2022-059","url":null,"abstract":"Carbonaceous shales in the Southern Uplands-Down-Longford Terrane accretionary prism had extremely high potential for hydrocarbon generation in the Lower Paleozoic. Structural thickening in the prism enhanced the rapid generation of oil. Shale horizons are separated by thick turbidites composed of low-permeability greywackes, so oil under high fluid pressure either pooled along shale bedding surfaces or migrated into fractured greywackes. Pooled oil became solidified to bitumen, which locally formed deposits on a scale of tonnes, mined as coal. The carbon-rich shale also sequestered large amounts of sulfur from seawater, which precipitated as pyrite firstly during early diagenesis, then further during fluid flow through the shale beds. The oil was also sulfur-bearing. Deformation focused on the shale beds during the evolution of the accretionary prism would have been closely related to the fluid flow which precipitated bitumen and sulfides. The palaeo-fluids were also anomalously rich in methane and hydrogen, similar to fluids venting from modern accretionary prisms.\u0000 \u0000 Supplementary material:\u0000 details of localities searched for coal in Lower Palaeozoic, Southern Uplands-Down-Longford Terrane (locations shown in\u0000 Fig. 6\u0000 ) are available at\u0000 https://doi.org/10.6084/m9.figshare.c.6691597\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-06-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44725469","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Utilization of chemostratigraphy to the subregional scale correlation of Permo-Carboniferous sediments, eastern Saudi Arabia","authors":"N. Craigie, C. Scheibe","doi":"10.1144/petgeo2023-007","DOIUrl":"https://doi.org/10.1144/petgeo2023-007","url":null,"abstract":"The following chemostratigraphy study was completed on the Permo-Carboniferous Unayzah Group in Eastern Saudi Arabia. The aim of the study was to determine whether the technique could be used to identify formation and member boundaries on a subregional scale, with the area extending for approximately 550 Km in a NW-SE direction and 350 Km NE-SW. A total of 30,375 core and cuttings samples were analyzed from 225 wells using ICP (inductively Coupled Plasma) and XRF (X-ray Fluorescence) instruments, with data acquired for 42-53 elements for each sample in the range Na-U in the periodic table. Of these, details of 14 wells are discussed in the present work.\u0000 Based on variations in Zr/Ti, Zr/U, Zr/Y, Y/U, U/Th, Gd/Zr, Nb/Yb and Nb/Th it is possible to identify a hierarchical order of one zone, fours subzones and five divisions, these chemozones being correlative on a subregional scale. By comparing geochemical, biostratigraphic, sedimentological and wireline log data in selected reference wells, it was possible to relate chemozones to particular members of the Unayzah Group. The differences in geochemistry between these chemozones/members is largely explained by changes in provenance, though depositional environment may have exerted at least some influence.","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-06-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41991490","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characterising along- and across-fault fluid flow properties for assessing flow rates and overburden fluid migration along faults - A case study from the North Sea","authors":"T. Bjørnarå, E. Skurtveit, E. Michie, Scott A. Smith","doi":"10.1144/petgeo2023-033","DOIUrl":"https://doi.org/10.1144/petgeo2023-033","url":null,"abstract":"\u0000 The article highlights the importance of understanding the permeability of fault zones as fluid migration pathways, with an example from the Vette Fault Zone in the North Sea. The study characterizes the hydraulic properties of the fault zone by mixing host rock lithologies into the fault zone and deriving the fault width from empirical relationships. A parametric study with 1125 model realizations was conducted to understand the sensitivity related to uncertainties in overburden lithologies and fault width correlations. The study found that the fault zone significantly alters the flow-field compared to a model that only considers lithological juxtaposition. The most significant hydraulic communication in the Vette Fault Zone is downwards from the storage reservoir where sand is mixed into the fault zone. The models highlight the potential for downward hydraulic communication along the fault for brine and CO\u0000 2\u0000 capillary sealing towards the overburden.\u0000 \u0000 \u0000 Thematic collection:\u0000 This article is part of the Fault and top seals collection available at:\u0000 www.lyellcollection.org/topic/collections/fault-and-top-seals-2022\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-06-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44913099","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Evaluating the impact of 4D seismic data artifacts in data assimilation","authors":"Da Rosa, D. Schiozer, A. Davolio","doi":"10.1144/petgeo2022-069","DOIUrl":"https://doi.org/10.1144/petgeo2022-069","url":null,"abstract":"Time-lapse or 4D Seismic data (4DS) are important constraints in reservoir studies because they enable monitoring of saturation and pressure changes that result from hydrocarbon production. 4DS have been quantitatively added, along with production data, in history matching or data assimilation (DA) procedures to reduce uncertainty and improve production forecasts. Before performing quantitative studies, it is important to ensure that the 4DS are reliable, with minimal artifacts such as side-lobe effects, that can disturb the identification of anomalies. In this work, we propose different ways of treating 4DS in DA for a real reservoir. Explicitly, we evaluated the impact on DA results when considering different amounts of 4D information and three treatments to the identified artifacts. The treatments were: ignoring them, excluding them from DA, or defining no seismic changes at their locations. The results show that well and seismic matches are improved when 4DS are assimilated, also improving the production predictions. Despite being a thin reservoir, assimilating two single-layer maps allowed us to predict relevant observed dynamic behaviour, such as the evolved gas trapped in the lower interval. Furthermore, when a treatment was applied to the artifacts, they produced better models than using a single two-layer map (with lower production errors and visually closer impedances to the observed data). Our recommendation is the assimilation of well and 4DS data, with the exclusion of unreliable information, for better life-cycle decisions.","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-05-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41691075","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Estimating Additional Resistivity by Permeability in Brine Saturated Sandstones","authors":"Wenjun Zhao, Tangyan Liu, Jizhou Tang, J. Zhang","doi":"10.1144/petgeo2022-067","DOIUrl":"https://doi.org/10.1144/petgeo2022-067","url":null,"abstract":"\u0000 Determining rock resistivity for saturation estimation in reservoirs is challenging due to the complex nature of pores in the rock. This paper aims to establish a computational relationship between formation factors (\u0000 F\u0000 ) and permeability (\u0000 K\u0000 ) by combining theoretical and experimental data. Firstly, the relationship between the permeability of the curved capillary model and formation factors, as well as the relationship between the permeability of the complex curved capillary model and formation factors, are deduced. Theoretical analysis proved that the formation factors(\u0000 F\u0000 ) have a power relationship with permeability(\u0000 K\u0000 ) and porosity (\u0000 \u0000 \u0000 φ\u0000 \u0000 \u0000 ), and confirms the existence of additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ). To validate the the theoretical study, we conducted model analysis using open experimental data from thirty-five sandstone cores with different porosity and permeability from the tight gas sandstone in the Western U.S. Basins, which measured resistivity data in saline at 20ppm, 40ppm, and 80ppm, respectively. We confirmed the existences of additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ) by fitting the relationship between the rock resistivity of saturated formation water (\u0000 R\u0000 o\u0000 ) and the formation water resistivity (\u0000 \u0000 R\u0000 w\u0000 \u0000 ). We then fitted the formation resistivity change factor (\u0000 \u0000 F\u0000 d\u0000 \u0000 ) with permeability (\u0000 K\u0000 ), the formation resistivity change factor (\u0000 \u0000 F\u0000 d\u0000 \u0000 ) with porosity (\u0000 \u0000 \u0000 φ\u0000 \u0000 \u0000 ), the additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ) with permeability (\u0000 K\u0000 ), and the additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ) with porosity (\u0000 \u0000 \u0000 φ\u0000 \u0000 \u0000 ). Both changeable formation resistivity change factor (\u0000 \u0000 F\u0000 d\u0000 \u0000 ) and additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ) showed a strong linear relationship with permeability (\u0000 K\u0000 ) in logarithmic coordinates.\u0000 \u0000 \u0000 We also verified the existence of a suitable equation using available experimental data by changing formation parameters and permeability. The study shows that the fitting equations may be utilized to determine changeable formation resistivity change factor (\u0000 \u0000 F\u0000 d\u0000 \u0000 ), additional resistivity (\u0000 \u0000 R\u0000 x\u0000 \u0000 ), and the rock resistivity of saturated formation water (\u0000 R\u0000 o\u0000 ) with varying permeability. The predicted rock resistivity of saturated formation water (\u0000 R\u0000 o\u0000 ) strongly correlates with the one measured in the laboratory, providing better precision for future reservoir evaluation in saturation estimations.\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44662834","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 Rossano-San Nicola Fault Zone evolution impacts the burial and maturation histories of the Crotone Basin, Calabrian Arc, Italy","authors":"Giacomo Mangano, T. Alves, M. Zecchin, D. Civile, S. Critelli","doi":"10.1144/petgeo2022-085","DOIUrl":"https://doi.org/10.1144/petgeo2022-085","url":null,"abstract":"This work addresses the tectonic significance of a NW-SE strike-slip fault zone in the Calabrian Arc of Southern Italy, the Rossano-San Nicola Fault Zone (RSFZ). High-quality seismic reflection and 1D forward models of exploration boreholes and pseudo-wells show that the RSFZ experienced multiple Miocene phases of contractional/transpressional tectonics. These were followed by crustal extension during the Pliocene in association with the oceanisation of the Tyrrhenian Sea, Apennine orogenesis, and collision between the Calabrian Arc and adjacent tectonic plates. Such a setting had a profound influence on the Crotone Basin and its economic potential: 1) tectonic reactivation allowed reservoir units of the Crotone Basin to be charged by gas derived from Triassic/Lower Jurassic source rocks, and 2) source rocks reached their maximum depth and remained in the gas generation window after the emplacement of a large mass-transport complex in the Pliocene. In the surrounding areas, tectonic activity near the RSFZ contributed to source-rock maturation by enhancing local sedimentation rates, particularly during Langhian (Middle Miocene) and Zanclean (early Pliocene) tectonics. This work is important as it demonstrates the tectono-stratigraphic evolution of the Crotone Basin to be closely related to the structural evolution of the RSFZ. Crucially, the study area reveals the first example of a gas field fully sealed by a large mass-transport complex. As a corollary, we tie the Late Cenozoic geological history of the Crotone Basin to the geodynamic evolution of the central Mediterranean region, namely the Ionian and Tyrrhenian seas. We identify new prospects in the Crotone Basin and provide a time frame for gas generation and accumulation in Southern Italy.","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44256773","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Geopressure: an introduction to the thematic collection","authors":"R. Swarbrick","doi":"10.1144/petgeo2023-026","DOIUrl":"https://doi.org/10.1144/petgeo2023-026","url":null,"abstract":"\u0000 Thematic collection:\u0000 This article is part of the Geopressure collection available at:\u0000 https://www.lyellcollection.org/topic/collections/geopressure\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-04-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47391645","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 insights into the stratigraphic evolution of southwest Britain: Implications for Triassic salt and hydrocarbon prospectivity","authors":"S. S. Husein, A. Fraser, G. Roberts, R. Bell","doi":"10.1144/petgeo2022-051","DOIUrl":"https://doi.org/10.1144/petgeo2022-051","url":null,"abstract":"The discovery of Wytch Farm field in the Wessex Basin, and Kinsale Head field in the North Celtic Sea Basin in the early 1970s, led to exploration interest offshore in the Western Approaches Trough. Despite this activity, little evidence for prospective hydrocarbon resources has been found. To better understand the failures and analyse remaining hydrocarbon potential in this region, we make use of a large collection of new seismic reflection and well data to map Carboniferous to Neogene stratigraphy. The improved seismic imaging has allowed a better interpretation of the hitherto poorly understood, salt-related structures in the South Melville and the Plymouth Bay basins. The implications of the new interpretations for Carnian (Late Triassic), and Carboniferous stratigraphic and geodynamic evolution are assessed and contextualised with regional salt deposition in the Wessex, Bristol, and South Celtic Sea basins. From a petroleum system perspective, the Lias and Carboniferous source rocks are evaluated and modelled to analyse the maturity and evolution of the petroleum systems. We conclude that the Lias is an ineffective petroleum system due to timing and source maturation risk. However, the Triassic salt and associated subcropping faults have produced several possible pre-salt hydrocarbon traps. The traps may be charged from sporadic Mid-Late Carboniferous coal-bearing post-orogenic basins, a petroleum system previously overlooked.\u0000 \u0000 Supplementary material\u0000 : [Appendix showing seismic, well data and petroleum systems boundary conditions. Burial history plots of the petroleum systems modelling scenarios used to generate source rock transformation ratio plots shown in Figs 9 & 10. [Item 1: Spreadsheet with seismic and well data used in the study, and petroleum system modelling input data. Item 2: Raw decompacted burial history plot, and burial history plots of the 3 Lias petroleum systems scenarios]\u0000 https://doi.org/10.6084/m9.figshare.c.6486999\u0000 \u0000 \u0000 Thematic collection:\u0000 This article is part of the UKCS Atlantic Margin collection available at:\u0000 https://www.lyellcollection.org/topic/collections/new-learning-from-exploration-and-development-in-the-ukcs-atlantic-margin\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-03-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46491601","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Shear velocity estimation based on rock physics modeling of limestone gas reservoir in the Pannonian basin","authors":"D. Vukadin","doi":"10.1144/petgeo2022-070","DOIUrl":"https://doi.org/10.1144/petgeo2022-070","url":null,"abstract":"In the Pannonian Basin, especially in Croatia, there are a small number of wells with acquired shear velocities. Often, quantitative interpretation must rely only on compressional velocity data, and shear velocity must be modelled. Shear wave velocity estimation in combination with other petrophysical data is essential for detailed reservoir characterization. Compressional and shear wave velocity allow the seismic modelling of different saturation states in a reservoir. This paper demonstrates a workflow for S-wave velocity estimation where shear velocity data is absent in the gas field and neighboring fields with the same lithology, based on the Kuster-Toksöz and Xu-Payne models applied to the Pannonian basin limestone reservoir. The results are calibrated with the P-wave velocity obtained from borehole data and the VSP S-wave interval velocity. Although rock physics models are idealized analogues of real rocks, a very good correlation was obtained between the modelled and measured P-wave velocity, as well as between the modelled S-wave velocity and the VSP interval velocity. The study also illustrates the problem of defining the pore aspect ratio in zones of increasing shale content. Due to the limited research on the limestones of the Pannonian Basin, these results enable a better understanding of the seismic parameters of the Pannonian Basin limestones. The results indicate that the proposed workflow gives an adequate estimation of S-wave velocities.","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-03-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48220930","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"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 potential extent of Early Triassic Kockatea Shale equivalent source rocks in the Northern Carnarvon and Perth Basins (Western Australia)","authors":"T. Taniwaki, C. Elders, A. Holman, K. Grice","doi":"10.1144/petgeo2022-023","DOIUrl":"https://doi.org/10.1144/petgeo2022-023","url":null,"abstract":"\u0000 In the northern Perth Basin (Western Australia), the Early Triassic Kockatea Shale is the primary petroleum source rock. Possible source rocks in the Northern Carnarvon Basin are more varied and include the Upper Jurassic Dingo Claystone as well as the Early Triassic Locker Shale. Biomarker analyses were conducted on petroleum samples from these basins to understand the nature of the petroleum systems. Many of the analysed petroleum samples contain carotenoids (okenane, chlorobactane and isorenieratane) derived from photosynthetic sulfur bacteria, suggesting that their source rocks were deposited under conditions of photic zone euxinia (PZE) and/or derived from microbialites. In the northern Perth Basin, the major lithofacies contributing to the source rock are dark coloured mudstones deposited under PZE conditions and/or derived from microbialites. In the southern Perth Basin, the potential source rock is either Permian, Jurassic or Cretaceous in age as indicated by the low concentrations or absence of carotenoids and the Triassic biomarker\u0000 n\u0000 -C\u0000 33\u0000 alkylcyclohexane. There is also a possibility that the Lower Triassic Locker Shale is the source rock of petroleum in the Tubridgi field on the Peedamullah Shelf of the Northern Carnarvon Basin, based on the similarity of biomarkers to Perth Basin petroleum sourced from the Kockatea Shale. However, the possibility of charge from the Upper Jurassic Dingo Claystone cannot be entirely excluded.\u0000","PeriodicalId":49704,"journal":{"name":"Petroleum Geoscience","volume":" ","pages":""},"PeriodicalIF":1.7,"publicationDate":"2023-03-02","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46282674","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}