Relevant bibliographies by topics / Petroleum Geoscience

Academic literature on the topic 'Petroleum Geoscience'

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Published: 10 December 2022
Last updated: 28 January 2023

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Journal articles on the topic "Petroleum Geoscience"

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Green, Peter. "Australian States and Northern Territory acreage update at APPEA 2010." APPEA Journal 50, no. 1 (2010): 35. http://dx.doi.org/10.1071/aj09003.

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Peter Green is the Geoscience Manager: Energy Geoscience in the Geological Survey Queensland and has extensive experience in basin studies, geoscience and the development of petroleum regulation in Queensland. This paper provides a summary of the land releases for petroleum exploration for onshore areas and coastal waters of Australia for 2010. The summaries include upstream petroleum acreage opportunities for the states and the Northern Territory, and geothermal energy exploration opportunities. The rise in interest in export liquefied natural gas projects has ensured petroleum exploration and production has remained strong. Interest in acquiring petroleum acreage to explore for both conventional and non-conventional plays remains high. Australian state and the Northern Territory governments continue to provide access to land and promotional opportunities for companies to undertake exploration and development of our petroleum resources. Acreage on offer provides a mix of exploration opportunities from conventional oil and gas through to the unconventional plays such as shale gas and tight gas. This change in acreage on offer reflects the changing nature of the onshore petroleum industry in Australia.
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Carr, Lidena, Russell Korsch, and Tehani Palu. "Australia's onshore basin inventory: volume I." APPEA Journal 56, no. 2 (2016): 591. http://dx.doi.org/10.1071/aj15097.

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Following the publication of Geoscience Australia Record 2014/09: Petroleum geology inventory of Australia’s offshore frontier basins by Totterdell et al (2014), the onshore petroleum section of Geoscience Australia embarked on a similar project for the onshore Australian basins. Volume I of this publication series contains inventories of the McArthur, South Nicholson, Georgina, Amadeus, Warburton, Wiso, Galilee, and Cooper basins. A comprehensive review of the geology, petroleum systems, exploration status, and data coverage for these eight Australian onshore basins was conducted, based on the results of Geoscience Australia’s precompetitive data programs, industry exploration results, and the geoscience literature. A petroleum prospectivity ranking was assigned to each basin, based on evidence for the existence of an active petroleum system. The availability of data and level of knowledge in each area was reflected in a confidence rating for that ranking. This extended abstract summarises the rankings assigned to each of these eight basins, and describes the type of information available for each of these basins in the publically available report by Carr et al (2016), available on the Geoscience Australia website. The record allocated a high prospectivity rating for the Amadeus and Cooper basins, a moderate rating for the Galilee, McArthur and Georgina basins, and a low rating for the South Nicholson, Warburton and Wiso basins. The record lists how best to access data for each basin, provides an assessment of issues and unanswered questions, and recommends future work directions to lessen the risk of these basins in terms of their petroleum prospectivity. Work is in progress to compile inventories on the next series of onshore basins.
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Bernecker, Thomas, Steve Abbott, George Bernardel, Megan Lech, Ryan Owens, Tegan Smith, and Jennifer Totterdell. "The 2017 offshore acreage release areas: petroleum geological overview." APPEA Journal 57, no. 2 (2017): 304. http://dx.doi.org/10.1071/aj16029.

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In 2017, 21 new offshore petroleum exploration areas have been released. The majority of the areas are located along the North West Shelf spanning the Westralian Superbasin from the Bonaparte Basin in the north-east to the Northern Carnarvon Basin in the south-west. New areas have been released in offshore south-eastern Australia with new opportunities provided in the Otway, Bass and Gippsland basins. Two large areas in the northern Perth Basin, an offshore frontier, complete the 2017 Acreage Release. All Release Areas are supported by industry nominations and one new cash bid area has been offered in the Dampier Sub-basin. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies. A new regional 2D seismic survey was acquired in the Houtman Sub-basin of the Perth Basin, forming the basis of the latest prospectivity study carried out by Geoscience Australia. The results of the study are presented in the technical program of the 2017 APPEA conference. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGSSA) are made available through the National Offshore Petroleum Information Management System (NOPIMS). Additional datasets are accessible through Geoscience Australia’s data repository.
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Henson, Paul, David Robinson, Lidena Carr, Dianne S. Edwards, Susannah K. MacFarlane, Amber J. M. Jarrett, and Adam H. E. Bailey. "Exploring for the Future—a new oil and gas frontier in northern Australia." APPEA Journal 60, no. 2 (2020): 703. http://dx.doi.org/10.1071/aj19080.

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Exploring for the Future (EFTF) is a four-year, AU$100.5 million initiative from the Australian Government conducted by Geoscience Australia in partnership with state and Northern Territory government agencies, CSIRO and universities to provide new geoscientific datasets for frontier regions. As part of this program, Geoscience Australia acquired two new seismic surveys that collectively extend across the South Nicholson Basin (L120 South Nicholson seismic line) and into the Beetaloo Sub-basin of the McArthur Basin (L212 Barkly seismic line). Interpretation of the seismic has resulted in the discovery of new basins that both contain a significant section of presumed Proterozoic strata. Integration of the seismic results with petroleum systems geochemistry, structural analyses, geochronology, rock properties and a petroleum systems model has expanded the knowledge of the region for energy exploration. These datasets are available through Geoscience Australia’s newly developed Data Discovery Portal: an online platform delivering digital geoscientific information, including seismic locations and cross-section images, and field site and well based sample data. Specifically for the EFTF energy project, a petroleum systems framework with supporting organic geochemical data has been built to access source rock, crude oil and natural gas datasets via interactive maps, graphs and analytical tools that enable the user to gain a better and faster understanding of a basin’s petroleum prospectivity.
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B., Elizabeth Chacon, Jorge A. Briones Carrillo, Carlos G. Aguilar-Madera, Nelson E. Barros-Galvis, and Sóstenes Méndez-Delgado. "Petroleum Engineering as a (still) Promising Career in Geosciences? An Empirical Example in Northeastern Mexico." International Journal of Education 9, no. 4 (December 13, 2017): 62. http://dx.doi.org/10.5296/ije.v9i4.12297.

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More than ever, it is the time to increase the number of engineering students applying to geosciences in order to satisfy the growing national challenges and administrate our natural resources in a responsible and sustainable manner. This work analyzes the petroleum engineer career at the UANL through an 8-yr experience in order to critically evaluate the current academic profile that Petroleum Engineers need within a global and shared world. This brief appraisal also presents an updated revision of all certified academic programs offering the Petroleum Engineering career in Mexico. At the same time, this work also proposes a modest but realistic academic modality for this particular career to better fulfill the actual academic and industrial demands on this area. Adjusting the academic geoscience workforce implies a redefinition of curricular programs, values and competences for this career in a synergic action with government policies and public and private employees worldwide. Certainly, the change should be the driving force to design modern up-to-date professional profiles and better oil professionals with a global perspective to take on alternative development.
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Bernecker, Thomas, Aaron Heugh, Karen Higgins, and Ryan Owens. "The hydrocarbon potential of the 2016 proposed Offshore Acreage Release Areas for petroleum exploration." APPEA Journal 56, no. 1 (2016): 451. http://dx.doi.org/10.1071/aj15033.

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The Australian Government usually releases new offshore exploration acreage once a year. The proposed 2016 Release Areas are located across various offshore hydrocarbon provinces and include mature basins with ongoing oil and gas production as well as exploration frontiers. In support of the annual acreage release, Geoscience Australia provides a variety of geological information with an emphasis on basin evolution, stratigraphic frameworks, and overviews of hydrocarbon prospectivity. Geoscience Australia’s petroleum geological studies are aimed at the evolution of hydrocarbon-bearing basins at a regional scale, and include a review of source rock occurrences, their distribution and geochemical characters. Following the recent oil discovery in the Roebuck Basin, a strong focus of Geoscience Australia’s work is being placed on the Triassic period, and any new findings will directly underpin the release of new exploration acreage. Recent updates to stratigraphic frameworks and new results from geochemical studies are regularly published, and are used by Geoscience Australia for prospectivity assessments. Furthermore, the Australian Government continues to assist offshore exploration activities by providing ready access to a wealth of geological and geophysical data.
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Burnett, T. L. "Petroleum Exploration Risk Reduction Using New Geoscience Technology." Energy Exploration & Exploitation 14, no. 6 (December 1996): 507–34. http://dx.doi.org/10.1177/014459879601400602.

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As economics of the oil and gas industry become more restrictive, the need for new means of improving exploration risks and reducing expenses is becoming more acute. Partnerships between industry and academia are making significant improvements in four general areas: Seismic acquisition, reservoir characterization, quantitative structural modeling, and geochemical inversion. In marine seismic acquisition the vertical cable concept utilizes hydrophones suspended at fixed locations vertically within the water column by buoys. There are numerous advantages of vertical cable technology over conventional 3-D seismic acquisition. In a related methodology, ‘Borehole Seismic,’ seismic energy is passed between wells and valuable information on reservoir geometry, porosity, lithology, and oil saturation is extracted from the P-wave and S-wave data. In association with seismic methods of determining the external geometry and the internal properties of a reservoir, 3-dimensional sedimentation-simulation models, based on physical, hydrologic, erosional and transport processes, are being utilized for stratigraphic analysis. In addition, powerful, 1-D, coupled reaction-transport models are being used to simulate diagenesis processes in reservoir rocks. At the regional scale, the bridging of quantitative structural concepts with seismic interpretation has lead to breakthroughs in structural analysis, particularly in complex terrains. Such analyses are becoming more accurate and cost effective when tied to highly advanced, remote-sensing, multi-spectral data acquisition and image processing technology. Emerging technology in petroleum geochemistry enables geoscientists to infer the character, age, maturity, identity and location of source rocks from crude oil characteristics (‘Geochemical Inversion’) and to better estimate hydrocarbon-supply volumetrics, which can be invaluable in understanding petroleum systems and in reducing exploration risks and associated expenses.
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Spencer, Anthony M., Per Ivar Briskeby, Lone Dyrmose Christensen, Rune Foyn, Marie Kjølleberg, Erling Kvadsheim, Ian Knight, Morten Rye-Larsen, and John Williams. "Petroleum geoscience in Norden – exploration, production and organization." Episodes 31, no. 1 (March 1, 2008): 115–24. http://dx.doi.org/10.18814/epiiugs/2008/v31i1/016.

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Bernecker, Thomas, George Bernardel, Claire Orlov, and Nadège Rollet. "Petroleum geology of the 2018 offshore acreage release areas." APPEA Journal 58, no. 2 (2018): 437. http://dx.doi.org/10.1071/aj17056.

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A total of 21 areas were released in 2018 for offshore petroleum exploration. They are located in the Bonaparte, Browse, Northern Carnarvon, Bight, Otway and Gippsland basins. All release areas were supported by industry nominations, indicating that interest in exploring Australia’s offshore basins remains strong, despite the significant decrease in the number of exploration wells drilled in recent years. Sixteen areas are being released under the work program bidding system with two rounds, one closing on 18 October 2018 and the other on 21 March 2019. Five areas are being released for cash bidding and include the producible La Bella gas accumulation in the Otway Basin. Prequalification for participation in the cash-bid auction closes on 4 October 2018 with the auction scheduled for 7 February 2019. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies. The regional evaluation of the petroleum systems in the Browse Basin has been completed and work continues on assessing the distribution of Early Triassic source rocks and related petroleum occurrences across the North West Shelf. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006, are made available through the National Offshore Petroleum Information Management System. Additional datasets are accessible through Geoscience Australia’s data repository.
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Constable, Tania. "2014 Offshore Petroleum Exploration Acreage Release." APPEA Journal 54, no. 1 (2014): 377. http://dx.doi.org/10.1071/aj13039.

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The potential for natural gas to fuel economic growth around the world is tremendous. Australia has a pivotal role to play with our abundant natural gas reserves and record levels of investment in LNG production capacity. Australia is presently the world’s third-largest exporter of LNG, with an export capacity of 24.3 million tonnes per annum (mtpa) from three operational projects. Capacity will increase to around 90 mtpa by 2018, once the seven projects being constructed come online. The Australian Government is committed to ensuring the long-term growth of the petroleum industry, and the promotion of competitive, sustainable and well-regulated markets operating in the best interests of the nation. Exploration is essential for the future of Australia’s resources sector to enhance our international competitiveness while maintaining Australian energy security and that of our energy trading partners. Investment in offshore petroleum exploration is facilitated though the annual Offshore Petroleum Exploration Acreage Release prepared by the Australian Government Department of Industry and Geoscience Australia. The Offshore Petroleum Exploration Acreage Release is underpinned by a stable economic environment and clear regulatory framework that provides investment certainty and security of title. This paper provides details about the acreage included in the 2014 Offshore Petroleum Exploration Acreage Release. All areas are supported by geological data and analysis from Geoscience Australia. This paper also discusses the introduction of cash bidding for mature areas and areas containing known petroleum accumulations, in addition to Australian Government initiatives in the offshore petroleum sphere.
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Dissertations / Theses on the topic "Petroleum Geoscience"

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Collot, Julien. "Évolution géodynamique du domaine Ouest-offshore de la Nouvelle-Calédonie et de ses extensions vers la Nouvelle-Zélande." Brest, 2009. https://tel.archives-ouvertes.fr/tel-00540173.

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Le Sud-Ouest Pacifique est le résultat de la fragmentation de la marge Est du Gondwana depuis le Crétacé. L’objet du présent travail de thèse est d’approfondir la connaissance des bassins de Nouvelle-Calédonie et de Fairway, situés à l’Ouest de la NC, afin de préciser l’évolution géodynamique du SO Pacifique du Crétacé à l’Oligocène. L’analyse de nouvelles données géophysiques a permis de dégager 3 étapes de cette fragmentation : 1. Formation du Bassin de Fairway-Aotea au Crétacé moyen en position intra-arc continental. La formation de ce bassin reflète les prémices de la déchirure continentale de la marge Est Gondwanienne dont la cause est à rechercher dans un changement de la dynamique de h subduction. 2. Déformation locale de la partie Nord du BNC à l’Eocène terminal synchrone à l’obduction Néo Calédonienne. Nous proposons ainsi un modèle selon lequel le BNC aurait subsidé et réagi comme un bassin flexural d’avant-pays suivant un processus de sous-charriage, au fur et à mesure que h nappe progressait sur le bâti Calédonien. 3. Subsidence Eocène Oligocène régionale affectant les structures reliant la Nouvelle-Zélande à la NC. Les traits morphostructuraux de cette déformation nous permettent d’émettre l’hypothèse que l’ablation d’une partie de la croûte inférieure de ce système serait responsable de h subsidence. Nous proposons ainsi un modèle dans lequel la reprise de la convergence vers 45 Ma entre les plaques Australienne et Pacifique aurait entraîné un épaississement crustal de l’ensemble aboutissant à une instabilité gravitaire de sa racine et provoquant son détachement dans le manteau. Ces nouveaux résultats ont des implications pour le potentiel pétrolier régional
The southwest Pacific results from the fragmentation of Gondwanaland since the Cretaceous time. The purpose of the current PhD work is to deepen our understanding of the history of the New Caledonia and Fairway basins, located west of New Caledonia, in order to better constrain the geodynamical evolution of the SW Pacific from Cretaceous to Oligocene. The analysis of new geophysical data has led to distinguish 3 main phases of this fragmentation : 1. Mid Cretaceous formation of the Fairway-Aotea Basin in a continental intra-arc position. The formation of this basin reflects the initial stage of continental fragmentation of the Eastern Gondwana margin. The causes of this fragmentation are to be searched for in a major change of the dynamics of the peri-Pacific subduction zone. 2. Latest late Eocene local deformation of the Northern NCB, synchronously with the New Caledonian obduction. We suggest that as the ophiolitic nappe was being obducted onto New Caledonia, the NC Basin subsided under the effect of the loading and underthrusted to accommodate the compressional deformation as a foreland flexural basin. Regional Eocene Oligocene subsidence of the structures linking NC to New Zealand. The morphostructural style of this deformation leads us to suggest that detachment of the lower crust is the cause of subsidence. We therefore propose a model in which the renewal of the Australia-Pacific convergent plate boundary around 45 Ma would have driven the lithosphere to thicken, leading to a root instability and to its detachment in the mantle. These newresults have regional petroleum implications, which are discussed in the PhD
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Halvorsen, Hanne Sundgot. "Mapping of shallow Tunnel Valleys combining 2D and 3D Seismic Data." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18383.

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In this study 19 tunnel valleys within block 2/4 in the central North Sea basin have been mapped. Furthermore, the possibility for these valleys to act as migration paths for leaked gas has been evaluated. In January 1989 a kick occurred while drilling well 2/4-14 in the area of study, hence the pertinence of evaluating this hypothesis at this locality is evident. The work has been performed using multichannel 2D lines and a conventional 3D seismic survey. The quality of the 2D and 3D data is clearly dissimilar at shallow burial depths, as the 2D data is considered to be high-resolution while the 3D data is low-resolution. However, both data sets have proved to give valuable information on the valley morphology. Great details about the extent and basal morphology have been retrieved from the conventional 3D volume; whereas seismic characteristics of the valley infill have been interpreted from the 2D lines. Tunnel valleys are major, elongated incisions carved into sediments or permeable bedrock during glaciations. They tend to be sinuous in planform, but might also appear as straight valleys. Tunnel valleys often consist of several cut- and fill-structures, both laterally and vertically, and thus form a network of interconnected valleys. This has also been observed in the area of study. No sedimentological logs have been available in the study. Hence, the interpretations of valley fill lithologies are based on the seismic characteristics, and thereby they are quite cautious. The typical fill sequence observed correlates fairly good with similar valleys mapped in the area previously. A lower part of chaotic reflectors, believed to be glaciofluvial sands and gravels, is overlain by sub-horizontal layers of glaciomarine mud. Moreover, velocity pull-up effects are seen in the underburden of some of the valleys. These indicate relatively high velocities of the infill sediments, and hence, it is likely to be clayey tills. Even so, the possibility of gas migration within the tunnel valley system is believed to be conspicuous.
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Fanka, Walter Roye Taju. "Well Log and Seismic Data Interpretation : Rock Physics Study of Poorly Consolidated Sandstones in The North Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18608.

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We use rock physics models for poorly consolidated rocks to diagnose reservoir sandstones in the Alvheim Field, North Sea. Geological factors that will control the rock physics and seismic properties include clay content, sorting, diagenesis, mineralogy, and bedding configuration. The various geologic factors will affect the fluid and stress sensitivity in these rocks. We investigate the interrelationships between various geological factors and seismic fluid and stress sensitivity, by combining well log data and rock physics models. Finally, we determine inter-well characteristics in terms of varying geological factors at different locations and discuss the results in terms of expected seismic signatures in the area.
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Ammah, Anass Nii-Armah. "Applying Time-Lapse Seismic Inversion In Reservoir Management: A Case Study Of The Norne Field." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-18611.

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Time-lapse seismic inversion approach to reservoir management has proven to be a vital tool in the industry today because of its effectiveness in tracking the movement of fluid front within the reservoir as well as identifying isolated bypassed accumulations. A base (2001) and three monitor (2003, 2004 and 2006) seismic surveys from the Norne field were inverted during this research. Water and gas have been injected into the reservoir to maintain the initial pressure within the field. These seismic surveys were analyzed for time-lapse impedance changes due to the differences in the produced hydrocarbons and the injected fluids. Check-shot corrected well data as well as interpreted horizons were integrated in the inversion process. Two independent wavelets were extracted from base and monitor surveys and combined to form an all-encompassing frequency and amplitude wavelet. The base and monitors were jointly inverted. This is because of the reduction in inconsistencies that are associated with independent inversions of surveys and the production related changes expected in time-lapse inverted seismic data.The results of the inversion show the impedance difference across the field for the various monitor surveys. Areas surrounding producer wells show slight changes in impedance while great impedance difference are observed around injector wells. A statistical analysis of the inversion results also shows steady increase in impedance across the field for the subsequent monitors. Structural and stratigraphic interpretation of the time-lapse inverted data also confirmed the sealing properties of some formations. This sealing property supported the impedance changes within the field. Fault interpretations as well as its sealing and non-sealing properties were inferred from the impedance differences across various discontinuities. Time-lapse acoustic impedance inversion of the Norne post-stack seismic data has revealed the impacts of production, dynamic fluid changes across main identified geologic structures, fluid front migration, fluid communication across structures and segments and other identified stratigraphic elements.
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Kaenmee, Kwanjai. "Structural Interpretation and Investigation of the Displacement Gradients of the Normal Fault System beneath the Horda Platform, the northern North Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19211.

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The North Sea basin is one of the best-studied areas in the world with respect to thestructural and sedimentary architecture of rift zones. The Base Cretaceous Unconformity,which defines a mappable horizon at the transition from synrift to postrift sequencesassociated with the Jurassic–Cretaceous rift, is well known as a reference marker for bothseismic and well log interpretations and covers most of the basin. This unconformity isinterpreted at the locations of the Øygarden Fault Zone, the Troll Fault Block, the NorthViking Graben, the Tampen Spur, the Snorre Fault Block, the Sogn Graben and the HordaPlatform. The complexities of the unconformity have been established and vary with thestructural and geographical position within the basin. However, as the Base CretaceousUnconformity covers most of the northern North Sea, its structural time map, is used to derivethe picture of post-structural framework of a rift basin and to locate essential structures in thedeeper sections.Three main reflectors (Pre-Jurassic 1, Pre-Jurassic 2 and Top seismic basement)located beneath the Base Cretaceous Unconformity on the Horda Platform, and have beeninterpreted using 2D seismic reflection data. These three reflectors have been studied in orderto investigate in detail the displacement gradients and possible linkage of the early faultsystem under the Horda Platform, and to evaluate their effect on the large-scale sedimentarchitecture. A main reason to work on the structures under the Horda Platform is due to thefact that these structures are believed to have existed already in the early stages of thenorthern North Sea basin development.The extensional normal fault systems of both the Permo-Triassic and the Late Jurassicrifts are considered a key control on the geological structures and sedimentary architecture ofthe region as presently seen. The basin evolution related Permo-Triassic rifting is mostpronounced on the eastern part of the Horda platform where its synrift geometry is obviouslyseen with the huge segment length and largest uplift explainable by a flexural stretchingmodel. The rift axis is transferred to position at base of the Viking graben during the Late-Jurassic rifting with the smaller magnitude of extension than the Permo-Triassic as clearlyseen by the less thickness of the synrift geometry. However, the structural evolution of normalfaults and the basin architecture under the Horda Platform is particularly affected by thecomplex interaction of fault linkage, fault propagation, fault growth, and death of faultthrough times from the early stage to the final stage of the basin development. Apart from theeffects of major tectonic controls, additionally, non-tectonic parameters, such as climate, seaor lake level changes, and differences in amount and type of sediment supply, should be takeninto account to influence the stratigraphic and sedimentation patterns in the basin.
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Catterall, Jeffrey John. "Structural Framework of the Statfjord Formation (Rhaetian-Sinemurian) in the Oseberg South Field, Norwegian North Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for geologi og bergteknikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20095.

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The Statfjord Formation (Rhaetian-Sinemurian) produces from six fields across the North Sea, but no discoveries have yet been made in the 12 exploration wells across the Oseberg South Field. The field has undergone two major periods of rifting in the Permian-Triassic and from the mid-Jurassic to Early Cretaceous. The Statfjord Formation was deposited during the Permian-Triassic post-rift period, but its tectonic influence on the paleogeography of the formation is not well understood. An isopach map produced from seismic interpretation and RMS modelling of the Statfjord Formation showed a westward thickening trend towards the present-day Viking Graben. This study presents results obtained using new, high-quality OBC seismic data that has allowed for faults throughout the field to be mapped in great detail. Supported by stratigraphic correlations and biostratigraphy, the mapping has showed that most faults can be assigned to either of the main rifting phases or their associated post-rift subsidence histories. Large, east-dipping faults are believed to have originated during the Permo-Triassic rifting, with evidence of movement into the Cretaceous. Large thickness increases of the formation over the westward dipping Oseberg and Brage Faults, as well as syn-rift sediments within some grabens in the J structure indicate movements of these faults during deposition. Biostratigraphic data show that the lowermost part of the Statfjord Formation was approximately the same thickness across the field until the Late Triassic, constraining the initiation of the Oseberg and Brage Faults to the Early Jurassic. Interpretations from timelines correlated within the Statfjord Formation suggest that the rate of subsidence along different faults was not consistent through time. Thickness changes along strike of the fault indicate that the movement along the fault was diachronous. This study aims to show that major fault activity influenced the deposition, and possibly preservation potential of sediment in the Statfjord Formation. The second phase of rifting is believed to have initiated many of the faults within the field, as well as reactivated the Oseberg and Brage Faults. Additional NW-SE faults in the Omega structure show no evidence of syn-rift sediments at the Statfjord Formation level, suggesting a mid-Jurassic post-rift origin. Similarly oriented faults were seen in the C structure, however, the presence of syn-rift sediments was difficult to ascertain, and no conclusions about the timing of initiation were made.
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Ahanor, David. "Integrated Reservoir Modelling of the Norne Field. : Volume Visualization/Seismic Attribute,Structural and Property Modeling." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for geologi og bergteknikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20379.

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ABSTRACT The purpose of this thesis project work is to build reservoir models (structural, facies and Petrophysical property models) of the different reservoir surfaces using integrated data sets (seismic, wells, fault sticks, eclipse models, horizon surfaces) of the Norne field which is located in blocks 6608/10 and 6508/1 in the southern part of the Nordland II area. Different visualizations techniques, volume rendering and seismic attributes were applied to aid the seismic interpretation and to provide detailed evaluation/integration of the data. 3D seismic interpretation for the whole seismic volume within the reservoir section was done manually with controlled input surfaces/reflectors of the Top horizons of the Not and Åre Formations. Fault and surfaces interpretation of the reservoir were generated as key inputs in the modeling process The structural 3D grid skeleton and models were generated with critical inputs of the manually interpreted faults/horizons, using different qualitative/quantitative templates in Petrel. This was followed by well interpretation and upscaling to provide discrete facies which are needed in populating the structural models of each of the reservoir surfaces. A probabilistic facies model was done to capture the proportion of the spatial dimensions of each discrete facies in the model frame. The initiation of this study involves quantitative data quality controls and management of inputs files into the Petrel window, qualitative control involves transferring geologic licenses/understanding to the various interpretations in the visualization schemes, seismic interpretation and reservoir modeling templates. The combination of different data type and idea (volumes, wells, top surfaces, and fault sticks) types means that the user must have a multivariate understanding (Geologic, Geophysical, Petrophysical, Geostastistic, Geo-Modeling and Reservoir Engineering) in other to integrate the data sets and deliver the models. Eleven wells were used in reference to the Top surface of the Not, Åre Top surfaces and Statoil Reference report of the field, to deliver and control the seismic interpretation. A wedge shape structure was observed in the reservoir section. Typically, minor and major faults were interpreted as forming compartments in the reservoir, which were interpreted across the different lines. The structural framework in the field was largely defined by the Norne Horst and associated faults, with the erosional surface of the BCU with internal sub unconformities observed. The property facies model of the reservoir surfaces (Garn, Ile, Tofte, and TIlje) suggest that the Norne Horst and sub relief structures are mainly sand rich, which provides additional prospect indicators in exploring the field
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Heinicke, Susanne. "Paleobathymetric reconstruction in the Hammerfest and Tromsø basins, southwestern Barents Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for geologi og bergteknikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20381.

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Seismic interpretation of 13 lines has been conducted in the Hammerfest and Tromsø basin areas in the southwestern Barents Sea. Based on interpretations, a 3D Geomodel comprising 10 layers has been constructed. Depth conversion of the Geomodel was accomplished after building of the herein required velocity model. Paleobathymetric reconstruction was performed for 9 time intervals from Top Oxfordian/Late Jurassic until Intra Sotbakken/Base Pliocene utilizing SINTEF´s basin modeling tool SEMI Paleowater. The restoration method is based on the information about depositional geometries from seismic sequences combined with zero or near zero water depth indicators. The time intervals have been restored using the deep marine infill scenario. The reconstruction showed that the Early Cretaceous paleo-water depth was greatly influenced by the Late Jurassic-Early Cretaceous rifting episode that resulted in the formation of deep marine basins and structural highs. Differential subsidence during the Cretaceous led to more stable areas in the east and rapidly subsiding basins in the west of the study area. Compressional tectonics in the Early Paleogene resulted in the development of the Senja Ridge as a positive structure. From the Oligocene until the Miocene, a period of shallow marine conditions was restored in the Hammerfest and Tromsø basins. The transition to a passive continental margin and resulting thermal subsidence led to a new deepening in the Neogene.
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Peyerl, Drielli 1985. "A contribuição do Conselho Nacional do Petróleo e da Petrobras na formação de profissionais para a exploração do petróleo no Brasil." [s.n.], 2014. http://repositorio.unicamp.br/jspui/handle/REPOSIP/286634.

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Orientador: Silvia Fernanda de Mendonça Figueirôa
Tese (doutorado) - Universidade Estadual de Campinas, Instituto de Geociências
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Resumo: Em 1864, um acontecimento singular e oficial iniciou e transformou o rumo das pesquisas relacionadas ao petróleo no Brasil: o Decreto n° 3.352-A, no qual, pela primeira vez, cita-se a palavra petróleo no corpo de um texto da Legislação Brasileira. Correlacionado a esse acontecimento, tem-se a criação da Escola de Minas de Ouro Preto em 1875, onde o ensino de Geociências no país começa a ser sistematicamente praticado. Embora formalmente titulados como engenheiros de minas, muitos atuaram na realidade como geólogos antes da existência de um curso específico de Geologia. Nos desdobramentos de busca e exploração de petróleo no Brasil durante o do século XX tivemos iniciativas particulares e governamentais (Comissão Geográfica e Geológica de São Paulo, Comissão White, Serviço Geológico e Mineralógico do Brasil) que contribuíram para a pesquisa e futuramente para a prospecção do petróleo no país. Em 1938, cria-se o Conselho Nacional do Petróleo ¿ CNP com o intuito de regulamentar e encontrar petróleo no território brasileiro. No ano seguinte descobre-se a primeira jazida de petróleo na região de Lobato, na Bahia, modificando-se a política do petróleo no Brasil. A descoberta de petróleo serviu como impulso para a indústria e para as atividades que dele dependiam. Enquanto isso, um dos problemas enfrentados pelo CNP foi a falta de pessoal qualificado para as demandas técnicas e de conhecimento geológico sobre o território brasileiro. Em 1954, a Petrobras (1953) iniciou suas atividades a partir do acervo recebido do antigo CNP, com o objetivo de executar tarefas no setor de exploração de petróleo no território. Algumas características do CNP permaneceram na empresa, principalmente em relação à pressão política e nacionalista que buscava consolidar o Brasil como um país rico em petróleo. Nesse processo, tanto o CNP como a Petrobras investiram na elaboração de cursos de aperfeiçoamento e profissionalização de sua própria equipe de trabalho. Inclusive formando profissionais na área de Geologia e Engenharia do Petróleo. Além dela, outras sociedades científicas e convênios com universidades, contribuíram para a formação e constituição das Geociências no Brasil num outro patamar de institucionalização e profissionalização. Assim, esta tese tem por objetivo investigar e compreender o papel do CNP e principalmente da Petrobras na construção e formação de cursos na área de Geociências, como parte do processo histórico de busca e exploração pelo petróleo iniciado aqui em 1864 e finalizando-se em 1968 com a descoberta do primeiro poço offshore, quando também, a Petrobras investe massivamente nas pesquisas para exploração de petróleo no mar. A principal fonte da presente pesquisa concentra-se no Acervo pessoal do paleontólogo Frederico Waldemar Lange (1911-1988), que se encontra sob a guarda e conservação do Laboratório de Estratigrafia e Paleontologia da Universidade Estadual de Ponta Grossa (UEPG)
Abstract: In 1864, an event that was both unique and official started and transformed the direction of Brazil¿s researches related to oil: the Decree n° 3.352-A where, for the first time, the word "oil" can be found in a text on the Brazilian Law. Correlated to this event, the Ouro Preto Mining School was founded in 1875, where the teaching of Geosciences begins to be systematically practiced. Although formally titled as mining engineer, many in fact acted as geologists before the existence of a specific course of Geology. In the development for search and exploitation of oil in Brazil during the twentieth century we had private and government initiatives (Comissão Geográfica e Geológica de São Paulo, Comissão White, Serviço Geológico e Mineralógico do Brasil) that contributed to research and future prospecting for oil in the country. In 1938, the National Petroleum Council (Conselho Nacional do Petróleo ¿ CNP) is created, in order to find and control oil in the Brazilian territory. In the following year the first petroleum deposits is found at the region of Lobato, Bahia, changing the oil policy in Brazil. The discovery of oil served as impetus for the industry and for activities which depend upon it. Meanwhile, one of the problems faced by CNP was the lack of qualified personnel to the technical demands and geological knowledge of the Brazilian territory. In 1954, Petrobras (1953) began operations from assets received from the old CNP, in order to perform tasks in the oil exploration industry in the territory. Some characteristics from CNP remained at Petrobras, especially the political and nationalist pressure that sought to consolidate Brazil as an oil-rich country. In this process, both CNP and Petrobras invested in the development of training courses and professionalization in their own team, mainly training professionals in the field of Geology and Petroleum Engineering. Besides Petrobras and CNP, other scientific societies and agreements with universities contributed to the formation and constitution of Geosciences in Brazil in another level of institutionalization and professionalization. Thus, this thesis aims to investigate and understand the role of CNP and especially of Petrobras in the construction and shaping of courses in the area of Geosciences, as part of the historical process of search and exploration for oil that began here in 1864 and ended in 1968 with the discovery of the first well-offshore, thus the Petrobras invests massively in research for oil exploration in the sea. The main source of this research is from the personal files of paleontologist Frederico Waldemar Lange (1911-1988), avaible for inspection at the Paleontology and Stratigraphy Laboratory of the State University of Ponta Grossa (UEPG)
Doutorado
Ensino e Historia de Ciencias da Terra
Doutora em Ciências
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Books on the topic "Petroleum Geoscience"

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Edward, Swarbrick Richard, ed. Petroleum geoscience. Malden, MA: Blackwell Pub., 2004.

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Bjørlykke, Knut, ed. Petroleum Geoscience. Berlin, Heidelberg: Springer Berlin Heidelberg, 2015. http://dx.doi.org/10.1007/978-3-642-34132-8.

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Bjorlykke, Knut. Petroleum Geoscience. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3.

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Sorkhabi, Rasoul, ed. Encyclopedia of Petroleum Geoscience. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-319-02330-4.

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Dasgupta, Troyee, and Soumyajit Mukherjee. Sediment Compaction and Applications in Petroleum Geoscience. Cham: Springer International Publishing, 2020. http://dx.doi.org/10.1007/978-3-030-13442-6.

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service), SpringerLink (Online, ed. Petroleum Geoscience: From Sedimentary Environments to Rock Physics. Berlin, Heidelberg: Springer-Verlag Berlin Heidelberg, 2010.

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Middle East Geoscience Conference (1994 Manama, Bahrain). The Middle East petroleum geosciences: Selected Middle East papers from the Middle East Geoscience Conference : GEO '94 : April 25-27, 1994, Bahrain. Manama, Bahrain: Published for GEO '94 by Gulf PetroLink, 1994.

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International Geoscience Conference on Deepwater and Frontier Exploration in Asia & Australasia (2004 Jakarta, Indonesia). Proceedings of an International Geoscience Conference on Deepwater and Frontier Exploration in Asia & Australasia: Jakarta, December 7-8, 2004. Jakarta, Indonesia: Indonesian Petroleum Association, 2004.

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Mukherjee, Soumyajit, ed. Petroleum Geosciences: Indian Contexts. Cham: Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-03119-4.

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Cranganu, Constantin, Henri Luchian, and Mihaela Elena Breaban, eds. Artificial Intelligent Approaches in Petroleum Geosciences. Cham: Springer International Publishing, 2015. http://dx.doi.org/10.1007/978-3-319-16531-8.

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Book chapters on the topic "Petroleum Geoscience"

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Sorkhabi, Rasoul. "Petroleum Geoscience." In Selective Neck Dissection for Oral Cancer, 1. Cham: Springer International Publishing, 2017. http://dx.doi.org/10.1007/978-3-319-02330-4_11-1.

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Bjørlykke, Knut. "Petroleum Migration." In Petroleum Geoscience, 349–60. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_15.

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Bjørlykke, Knut. "Petroleum Migration." In Petroleum Geoscience, 373–84. Berlin, Heidelberg: Springer Berlin Heidelberg, 2015. http://dx.doi.org/10.1007/978-3-642-34132-8_15.

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Bjørlykke, Knut. "Introduction to Petroleum Geology." In Petroleum Geoscience, 1–26. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_1.

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Bjørlykke, Knut. "Subsurface Water and Fluid Flow in Sedimentary Basins." In Petroleum Geoscience, 259–79. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_10.

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Bjørlykke, Knut, Kaare Høeg, and Nazmul Haque Mondol. "Introduction to Geomechanics: Stress and Strain in Sedimentary Basins." In Petroleum Geoscience, 281–98. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_11.

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Gabrielsen, Roy H. "The Structure and Hydrocarbon Traps of Sedimentary Basins." In Petroleum Geoscience, 299–327. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_12.

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Bjørlykke, Knut. "Compaction of Sedimentary Rocks Including Shales, Sandstones and Carbonates." In Petroleum Geoscience, 329–37. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_13.

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Bjørlykke, Knut. "Source Rocks and Petroleum Geochemistry." In Petroleum Geoscience, 339–48. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_14.

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Bjørlykke, Knut. "Well Logs: A Brief Introduction." In Petroleum Geoscience, 361–73. Berlin, Heidelberg: Springer Berlin Heidelberg, 2010. http://dx.doi.org/10.1007/978-3-642-02332-3_16.

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Conference papers on the topic "Petroleum Geoscience"

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Denli, Huseyin, Hassan A. Chughtai, Brian Hughes, Robert Gistri, and Peng Xu. "Geoscience Language Processing for Exploration." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207766-ms.

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Abstract Deep learning has recently been providing step-change capabilities, particularly using transformer models, for natural language processing applications such as question answering, query-based summarization, and language translation for general-purpose context. We have developed a geoscience-specific language processing solution using such models to enable geoscientists to perform rapid, fully-quantitative and automated analysis of large corpuses of data and gain insights. One of the key transformer-based model is BERT (Bidirectional Encoder Representations from Transformers). It is trained with a large amount of general-purpose text (e.g., Common Crawl). Use of such a model for geoscience applications can face a number of challenges. One is due to the insignificant presence of geoscience-specific vocabulary in general-purpose context (e.g. daily language) and the other one is due to the geoscience jargon (domain-specific meaning of words). For example, salt is more likely to be associated with table salt within a daily language but it is used as a subsurface entity within geosciences. To elevate such challenges, we retrained a pre-trained BERT model with our 20M internal geoscientific records. We will refer the retrained model as GeoBERT. We fine-tuned the GeoBERT model for a number of tasks including geoscience question answering and query-based summarization. BERT models are very large in size. For example, BERT-Large has 340M trained parameters. Geoscience language processing with these models, including GeoBERT, could result in a substantial latency when all database is processed at every call of the model. To address this challenge, we developed a retriever-reader engine consisting of an embedding-based similarity search as a context retrieval step, which helps the solution to narrow the context for a given query before processing the context with GeoBERT. We built a solution integrating context-retrieval and GeoBERT models. Benchmarks show that it is effective to help geologists to identify answers and context for given questions. The prototype will also produce a summary to different granularity for a given set of documents. We have also demonstrated that domain-specific GeoBERT outperforms general-purpose BERT for geoscience applications.
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C. Gringarten, A. "Teaching Petroleum Engineering and Petroleum Geoscience at Imperial College." In 64th EAGE Conference & Exhibition. European Association of Geoscientists & Engineers, 2002. http://dx.doi.org/10.3997/2214-4609.201405786.

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Thomas, L. K., C. E. Evans, and B. J. Todd. "An Integrated Engineering/Geoscience Desktop." In Petroleum Computer Conference. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/30193-ms.

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Ojo, V. "Applied Geoscience Project." In Fifth EAGE Eastern Africa Petroleum Geoscience Forum. European Association of Geoscientists & Engineers, 2021. http://dx.doi.org/10.3997/2214-4609.2021605005.

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Ershaghi, Iraj, and Donald L. Paul. "Integrating the Energy Transition into Petroleum Engineering and Geoscience Education." In SPE Western Regional Meeting. SPE, 2022. http://dx.doi.org/10.2118/209302-ms.

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Abstract The emerging carbon-constrained environment for energy is creating both opportunities and challenges for the established oil and gas industry. The petroleum industry engineering and geoscience professionals will need to evolve to meet both the challenges of the Energy Transition and continue to provide the feedstock for hydrocarbon-based products needed for a stable and robust economy. There are opportunities for the petroleum engineering schools and geoscience programs to develop and offer expanded educational opportunities for both new graduates and industry professionals to equip them with critical expertise and leadership skills for the Energy Transition.
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Fontaine, JM, O. Dubrule, G. Gaquerel, C. Lafond, and J. Barker. "Recent Developments in Geoscience for 3D Earth Modelling." In European Petroleum Conference. Society of Petroleum Engineers, 1998. http://dx.doi.org/10.2118/50568-ms.

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Sajid, Muhammad. "Machine Learning as a Silent Observer of Advanced Geoscience Interpretation." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207939-ms.

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Abstract Machine learning is proving its successes in all fields of life including medical, automotive, planning, engineering, etc. In the world of geoscience, ML showed impressive results in seismic fault interpretation, advance seismic attributes analysis, facies classification, and geobodies extraction such as channels, carbonates, and salt, etc. One of the challenges faced in geoscience is the availability of label data which is one of the most time-consuming requirements in supervised deep learning. In this paper, an advanced learning approach is proposed for geoscience where the machine observes the seismic interpretation activities and learns simultaneously as the interpretation progresses. Initial testing showed that through the proposed method along with transfer learning, machine learning performance is highly effective, and the machine accurately predicts features requiring minor post prediction filtering to be accepted as the optimal interpretation.
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Han, Fei, and Sam Z. Sun. "Petroleum Geoscience Big Data and GPU Parallel Computing." In 2015 IEEE International Conference on Multimedia Big Data (BigMM). IEEE, 2015. http://dx.doi.org/10.1109/bigmm.2015.59.

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Breedlove, J. R., S. B. Guthery, K. M. Landgren, and Stewart McAdoo. "Geoshare: An Emerging Industry Standard for Geoscience Data Exchange." In Petroleum Computer Conference. Society of Petroleum Engineers, 1992. http://dx.doi.org/10.2118/24425-ms.

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Albano, J. R., J. Dogliani, L. E. Pandolfo, and J. C. Quintana. "DBU+ A Geoscience Integrated Tool." In SPE Latin American and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2001. http://dx.doi.org/10.2118/69643-ms.

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Reports on the topic "Petroleum Geoscience"

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Edwards, D. S., S. K. MacFarlane, E. Grosjean, T. Buckler, C. J. Boreham, P. Henson, R. Cherukoon, et al. Australian source rocks, fluids and petroleum systems – a new integrated geoscience data discovery portal for maximising data potential. Geoscience Australia, 2020. http://dx.doi.org/10.11636/133751.

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Evenchick, C. A., F. Ferri, P. S. Mustard, M. McMechan, K. Osadetz, L. Stasiuk, N. S F Wilson, R. Enkin, T. Hadlari, and V. J. McNicoll. Recent results and activities of the Integrated Petroleum Resources Potential and Geoscience Studies of the Bowser and Sustut basins project. Natural Resources Canada/ESS/Scientific and Technical Publishing Services, 2003. http://dx.doi.org/10.4095/214831.

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