Relevant bibliographies by topics / Northeast Santos basin, Brazil

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Academic literature on the topic 'Northeast Santos basin, Brazil'

Author: Grafiati
Published: 4 June 2021
Last updated: 25 May 2024

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Journal articles on the topic "Northeast Santos basin, Brazil"

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Menezes, Paulo T. L., Jandyr M. Travassos, Marco A. M. Medeiros, and Patricia Takayama. "High-resolution facies modeling of presalt lacustrine carbonates reservoir analog: Morro do Chaves Formation example, Sergipe-Alagoas Basin, Brazil." Interpretation 4, no. 2 (May 1, 2016): SE63—SE74. http://dx.doi.org/10.1190/int-2014-0213.1.

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Barremian lacustrine carbonates, mainly coquinas, are the reservoir rocks of the large presalt petroleum discoveries in deep to ultradeepwaters, at the southeast Brazilian margin, namely, the Santos, Campos, and Espirito Santo Basins. The complex geologic setting of those discoveries, with massive overburden of salt bodies, makes the seismic imaging of the carbonate reservoirs an expensive and challenging issue. In this setting, accurate facies models are a requirement to the predictability of the carbonate reservoir intervals. We have developed an analog high-resolution coquinas facies model based on an interpretation of a pseudo-3D ground penetrating radar survey. We relied not only on the trace amplitude analysis, but also on trace attributes to reduce the ambiguity of the interpretation due to possible visual biases, which may relate electromagnetic reflection amplitude to geologic relevance. We have used the dip and texture attributes to help us better understand the subsurface and to focus on the main stratigraphic features of the reservoir analog. We have applied the dip attribute to discriminate among distinct facies and to provide a dip-steered horizon-tracking tool, honoring the stratigraphic layering. We have also used a texture attribute to downgrade high-frequency noise in the amplitude cube and emphasize the main stratigraphic horizons separating reflections with a similar and consistent pattern. Then, we produced a joint interpretation, based on three trace attributes, that is, amplitude, dip, and texture, to highlight the main radar facies. That resulted in a facies model in which three southwest–northeast-striking coquina bars (reservoir facies), associated with transgressive systems tract interbedded with shales (nonreservoir facies) of highstand systems tract, are clearly marked.
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Oliveira, Josevânia De, Cynthia Lara de Castro Manso, and Edilma De Jesus Andrade. "Equinoides endocíclicos(Echinodermata:Echinoidea)Cretáceo Superior da Formação Jandaíra, Bacia Potiguar, Nordeste do Brasil-Equinoides endocyclic(Echinodermata:Echinoidea) of the Upper Cretaceous in the Formation Jandaíra, Potiguar Basin, Northeast Brazil." Revista de Biologia Neotropical 11, no. 2 (March 13, 2015): 143. http://dx.doi.org/10.5216/rbn.v11i2.27470.

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Foi realizada a revisão sistemática dos equinoides pertencentes às ordens Phymosomatoida e Arbacioida da Formação Jandaíra, Bacia Potiguar provenientes de três localidades fossilíferas. Para a ordem Phymosomatoida foram revisadas as espécies Rosadosoma riograndensis (Maury, 1925) e Phymosoma major Coquand,1862, e para a ordem Arbacioida, Goniopygus sp. As espécies Cyphosoma majus (Coquand, 1862) e Phymosoma tinocoi (Santos, 1960) foram consideradas sinônimas de Phymosoma major. Goniopygus sp. foi transferida para Goniopygus durandi Perón & Gauthier, 1881. A partir dos dados biométricos dos exemplares de Rosadosoma riograndensis e Phymosoma major foi verificado que o diâmetro da carapaça influencia de forma significativa a altura das carapaças, assim como o diâmetro do perístoma. Além disso, foram observados diferentes estágios ontogenéticos nos exemplares analisados. Na Formação Jandaíra, os equinoides endocíclicos tiveram seu registro do Turoniano ao Santoniano.
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Godoy, William, Elizabeth M. Pontedeiro, Fernanda Hoerlle, Amir Raoof, Martinus Th van Genuchten, José Santiago, and Paulo Couto. "Computational and experimental pore-scale studies of a carbonate rock sample." Journal of Hydrology and Hydromechanics 67, no. 4 (December 1, 2019): 372–83. http://dx.doi.org/10.2478/johh-2019-0009.

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Abstract Carbonate rocks host several large water and hydrocarbon reservoirs worldwide, some of them highly heterogeneous involving complex pore systems. Pre-salt reservoirs in the Santos Basin off the south-east coast of Brazil, are an example of such rocks, with much attention focused on proper characterization of their petrophysical and multiphase flow properties. Since it is very difficult to obtain rock samples (coquinas) from these very deep reservoirs, analogues from north-eastern Brazil are often used because of very similar geological age and petrophysical properties. We used a coquina plug from an outcrop in a quarry in northeast Brazil to perform a comprehensive set of analyses. They included Scanning Electron Microscopy (SEM), Energy-Dispersive X-ray Spectroscopy (EDS), X-ray Diffraction (XRD), and micro-computed tomography (μCT) image acquisition using a series of pixel sizes, as well as direct permeability/porosity measurements. Some of the experimental data were collected from the plug itself, and some from a small sample of the rock slab, including thin sections. Results included the carbonate rock composition and the pore system at different scales, thus allowing us to reconstruct and model the porosity and absolute permeability of the coquina using 3D digital imaging and numerical simulations with pore network models (PNMs). The experimental and numerical data provided critical information about the well-connected pore network of the coquina, thereby facilitating improved predictions of fluid flow through the sample, with as ultimate objective to improve hydrocarbon recovery procedures.
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Presley, Jennifer. "High-Pressure Separation: New Technology in the Subsea Toolbox." Journal of Petroleum Technology 76, no. 02 (February 1, 2024): 30–35. http://dx.doi.org/10.2118/0224-0030-jpt.

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_ Subsea production systems have come far in the more than 60 years since the first deployment in the US Gulf of Mexico, helping many countries unlock their offshore hydrocarbon riches in the years that followed. For Brazil, it was a combination of advances in subsea technologies and floating production, storage, and offloading vessel (FPSO) designs that supported the growth of its offshore oil and gas prowess. From those first forays into the Sergipe-Alagoas basin in the northeast during the 1970s, the country’s offshore oil and gas footprint has grown significantly, with today’s production from the pre-salt Campos and Santos basins—located farther from shore and in much deeper water—launching state-run oil company Petrobras to a top spot among the ranks of global producers. The ongoing development of its offshore fields will continue to boost the country’s oil and natural gas production in 2024. Since December 2022, five FPSOs have been brought online, with four installed in 2023 delivering record output. The fifth one—the FPSO Sepetiba—delivered a New Year’s Day surprise when it came online at Mero 2 oil field on 31 December 2023. HISEP, a new subsea technology currently being readied for pilot testing, could potentially ensure continued future production of the Mero field and others by capturing CO2-rich dense gases directly from the wellstream and reinjecting it into the reservoir. The technology also frees up much-needed space and reduces weight on the FPSO’s topside by moving the separation process to the seafloor. Challenges and Solutions Brazil’s challenging offshore pre-salt region—first explored by Petrobras in 2005—contains estimated reserves of 30 to 40 billion BOE and comes with an extensive list of development challenges. Its Santos Basin, for example, lies in ultradeep water with hydrocarbon reservoirs located at extreme depths ranging from 5500 to 7600 m below sea level and under salt layers more than 2000 m thick. But the challenges do not end there. Managing the basin’s high gas/oil ratio (GOR) and CO2 content leaves a significant operational footprint. In OTC 29762, authors from Petrobras noted that developing the pre-salt reservoirs requires “large production facilities with complex gas processing plants that limit the oil processing and storage capacities.” In the paper presented at the 2019 Offshore Technology Conference (OTC) Brasil, the authors said that the gas processing plants for some pre-salt fields with high production indexes, GOR, and CO2 content account for nearly 60% of the total FPSO topsides area. The Santos Basin is home to the Mero oil field, the country’s third-largest pre-salt field and the first under a production-sharing contract awarded to the Petrobras-led Libra Consortium. The field is considered one of the largest hydrocarbon discoveries in the past decade, covering about 320 km2 of the Libra block and with a net pay zone reaching 420 m filled with 29 °API oil and high productivity, according to Ana Luiza Neder, et al. (OTC 32784).
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Denney, Dennis. "Santos Basin, Brazil: Successful Drilling Campaign 2008-2010." Journal of Petroleum Technology 64, no. 04 (April 1, 2012): 100–106. http://dx.doi.org/10.2118/0412-0100-jpt.

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JPT staff, _. "E&P Notes (December 2022)." Journal of Petroleum Technology 74, no. 12 (December 1, 2022): 14–16. http://dx.doi.org/10.2118/1222-0014-jpt.

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ExxonMobil, Partners Tout New Angola Block 15 Discovery ExxonMobil has made a new oil discovery with the Bavuca South-1 exploration well in Block 15 offshore Angola. The well is part of the Angola Block 15 redevelopment project targeting to deliver around 40,000 B/D of new oil production. According to ExxonMobil, the well encountered 30 m of hydrocarbon-bearing sandstone. The probe is located approximately 365 km northwest of Luanda and was drilled in 1100 m of water by the Valaris DS-9 rig. As the block’s operator, ExxonMobil is leading the installation of new technology and a multiyear drilling program aimed at adding new production volumes to help offset natural production declines. There have been 17 previous discoveries on Block 15: Hungo, Kissanje, Marimba, and Dikanza in 1998; Chocalho and Xikomba in 1999; Mondo, Saxi, and Batuque in 2000; Mbulumbumba, Vicango, and Mavacola in 2001; Reco Reco in 2002; and Clochas, Kakocha, Tchihumba, and Bavuca in 2003. ExxonMobil affiliate Esso Exploration Angola (Block 15) Limited is the operator of Block 15 and holds a 36% interest. BP Exploration (Angola) Limited holds 24%, ENI Angola Exploration BV holds 18%, Equinor Angola Block 15 AS holds 12%, and Sonangol P&P holds 10%. The National Agency for Petroleum, Gas, and Biofuels (ANPG) is the Block 15 concessionaire. Neptune Energy Begins Drilling Calypso Exploration Well Neptune Energy has spudded its Calypso exploration well 6407/88 S in the Norwegian Sea utilizing semisubmersible Deepsea Yantai. The Calypso prospect is located 14 km northwest of the Draugen field and 22 km northeast of the Njord A platform, within the Neptune-operated PL938 license. Calypso is positioned within one of Neptune’s core areas on the Norwegian Continental Shelf. In the event of a commercial discovery, Calypso could potentially be tied back to existing infrastructure. The reservoir target is the middle and lower Jurassic formations and is expected to be reached at a depth of approximately 2960 m. The drilling program comprises a main bore (6407/8-8 A) with an optional sidetrack (6407/8-8 S) based on the outcome of the exploration well. Neptune Energy operates the well with a 30% working interest. Partners include OKEA ASA, 30%; Pandion Energy AS, 20%; and Vår Energi ASA, 20%. Petrobras Strikes Oil Near Sepia Field Petrobras has a new oil find at its 4-BRSA-1386D-RJS (Pedunculo) well in the extreme northwest of the Sépia field in Brazil’s Santos Basin. The well spud in late July in a water depth of 2200 m, and the oil-bearing interval was verified by logs and fluid samples. According to Petrobras, the effective thickness of the oil column is one of the largest ever recorded in Brazil. The discovery is in the Sepia coparticipation area and comprises the Sepia block acquired by Petrobras (100%), and the Sépia-ECO block, which was acquired in December 2021 in the ANP’s second bidding round of surplus volumes. Petrobras (operator) was awarded Sépia-ECO along with partners TotalEnergies, QatarEnergy, and Petronas Petróleo Brasil Ltda., with Pré-Sal Petróleo SA as manager. The Sépia shared reservoir is currently producing 170,000 B/D. Petrobras also successfully completed the test at the pioneer well 1-BRSA-1381-SPS (Curaçao) in the pre-salt of the southwestern part of the Santos Basin. The new discovery is located 240 km from the city of Santos-SP, at a depth of 1905 m, in the Aram Block. The test evaluated a thick range of pre-salt carbonate reservoirs, in which it was possible to know its productivity through dynamic production data, according to Petrobras. During the test, oil samples were collected that will be characterized by laboratory analyses. The consortium will continue its activities in the Aram Block, aiming to evaluate the dimensions and commerciality of the new accumulation. The block was acquired in March 2020, in the sixth bidding round of the ANP, under the production-sharing regime, with Pré-Sal Petróleo SA as manager. Petrobras is the operator of the block (80% interest) in partnership with CNPC 20%. Shell, Murphy Eye Fresh Mexican Gulf Wildcats Shell is preparing to drill an exploration test in the Salina basin in offshore Mexico. According to Mexican hydrocarbons regulator CNH, the supermajor intends to spud the Jokol-1EXP wildcat in Block 28 starting in January 2023. The operator plans to use drillship Maersk Voyager for the work. The rig has been drilling the Zanderij-1 probe in Block 42 offshore Suriname and is expected to depart for Mexico soon. The Jokol-1EXP well is set to test a prospective light-oil reservoir at final depth of around 5586 m. The wellsite is roughly 40 km southwest of the Tamha-1EXP well. Meanwhile, Murphy Oil is drilling ahead on the deepwater Tulum-1EXP, where it hopes to tap 150 million BOE in reserves off the coast of Tabasco. The operator’s Mexican subsidiary, Murphy Sur, received authorization from CNH earlier this year. Murphy will use the Valaris DPS-5 semisubmersible to target lower Miocene and Oligocene formations and is drilling Tulum-1EXP as a deviated well to a depth of 5569 m. Tulum-1EXP is the second exploratory well of the Block 5 consortium led by Murphy Sur (40%), with partners PC Carigali Mexico Operations, Petronas’ Mexican subsidiary, and Wintershall Dea holding 30% each. Block 5 is in the center of the highly touted Salina Basin, a deepwater area in Mexico with significant hydrocarbon potential. CNOOC Has Certified Gas Find With Baodao 21-1 The proved gas-in-place of CNOOC’s Baodao 21-1 gas field has been certified at 50 billion m3 by the Chinese government. Baodao 21-1 gas field is in Baodao Sag, Qiongdongnan Basin, Western South China Sea in water depths ranging from 660 to 1570 m. The main gas-bearing zone is the Paleogene Lingshui formation, and the discovery is in condensate gas reservoirs. The discovery well Baodao 21-1 completed at a total depth of 5188 m, encountering 113 m of gas pay. The well is tested to produce an average of 587,000 m3 of natural gas per day. Baodao 21-1 is the first deepwater, deep-stratum large gas field in the South China Sea, realizing the biggest discovery in more than half a century in Songnan-Baodao Sag, according to CNOOC. ADNOC Sets Well-Length Record Abu Dhabi National Oil Company (ADNOC) said it set a new world record for the longest oil and gas well at its Upper Zakum Concession. Stretching 50,000 ft, the well is around 800 ft longer than the previous world record set in 2017. ADNOC Drilling drilled the well from Umm Al Anbar, one of ADNOC Offshore’s artificial islands. The extended-reach wells will tap into an undeveloped part of the giant Upper Zakum reservoir with the potential to increase the field’s production capacity by 15,000 B/D. Umm Al Anbar is one of Upper Zakum’s four artificial islands, serving as a hub for offshore drilling and operations. The producer added that its use of the artificial island concept has resulted in cost savings and environmental benefits compared to conventional approaches that traditionally require more offshore installations and infrastructure. New Tampen Area Wells Planned The Norwegian Petroleum Directorate issued to Equinor, Aker BP, and Var Energi a pair of drilling permits for exploration wells in the Tampen area of the Norwegian North Sea. The partnership has applied to drill the 34/6-6A wildcat in PL-554 using drilling rig Transocean Spitsbergen. The well is located to the northeast of the Visund field. Equinor will operate the well with a 40% working interest. Aker BP and Var Energi each hold a 30% stake. The second probe, 34/6-6S, was also permitted by the same partnership in the same license. Petronas Strengthens Partnership With TotalEnergies and Shell Through New PSC Petronas has signed a production-sharing contract (PSC) with TotalEnergies EP Malaysia, Petronas Carigali Sdn Bhd (PCSB), Sabah Shell Petroleum Company Limited (SSPC), and Shell Sabah Selatan Sdn Bhd (SSS) for Block 2K, an ultradeepwater block located off the coast of Sabah. Block SB 2K, with depths up to 3000 m, covering 1952 km2, is in the northwest ultradeepwater area within a proven hydrocarbon basin. Under the PSC terms, TotalEnergies will be the operator with a 34.9% participating interest. PCSB holds a 40% participating interest while the remaining 25.1% is equally split between the other two partners, SSPC and SSS. The signing of the PSC for Block 2K completes the licensing of the five ultradeepwater blocks off the coast of Sabah, along the newly identified Oligo-Miocene carbonate trend proven by Tepat-1 oil discovery in Block N in 2018. Block 2V was signed last year followed by Blocks 2W and X early this year. A total of four wells are expected to be drilled in these blocks in 2022 and 2023.
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MENDES, SAMUEL LUCAS DA SILVA DELGADO, PAULO CESAR DE PAIVA, and ALEXANDRA E. RIZZO. "New species of Pseudoscalibregma Ashworth, 1901 (Annelida: Scalibregmatidae Malmgren, 1867) from Brazil." Zootaxa 5399, no. 1 (January 10, 2024): 19–36. http://dx.doi.org/10.11646/zootaxa.5399.1.2.

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Pseudoscalibregma Ashworth, 1901 is a small genus of the family Scalibregmatidae Malmgren, 1867. Currently, a total of eight valid species are accepted. Of these, the majority are found at great depths. This work contains the first report of Pseudoscalibregma to the Brazilian coast, with the description of three new species: Pseuscalibregma ermindae sp. nov., P. magalhaesi sp. nov. and P. parapari sp. nov. The material was sampled from the Brazilian southeast region, on Campos and Santos sedimentary basins, during scientific expeditions called “Santos Project—Santos Basin Environmental Characterization” and “Ambes Project—Espírito Santo Basin Assessment Project”, both coordinated by PETROBRAS/CENPES. We also include an identification key to Pseudoscalibregma species.
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Santos, A. J. G., B. P. Mazzilli, and D. I. T. Favaro. "Characterization of stockpiled phosphogypsum waste in Santos basin, Brazil." Radioprotection 37, no. C1 (February 2002): C1–1307—C1–1315. http://dx.doi.org/10.1051/radiopro/2002165.

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Jin, KunQiang, and Yunfeng Zhang. "Formation Conditions and Exploration Directions of Large Cretaceous Sub-salt Oil and Gas Reservoirs in Santos Basin." E3S Web of Conferences 206 (2020): 01013. http://dx.doi.org/10.1051/e3sconf/202020601013.

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The rich oil and gas resources and good reservoir-forming conditions in the Santos Basin in Brazil make it a majorstrategic succession area for oil and gas exploration in the Santos Basin. The sub-salt bio-reservoir-cap configuration in the SantosBasin can be divided into two types: bio-reservoir-cap superposition and bio-reservoir superposition; the preservation conditions canbe divided into cap-slip-off extension deformation type, and the cap-layer is strongly extruded Deformation type, 3 types of capping stable extrusion deformation type; reservoir formation zone can be divided into 2 types: subsalt raw salt storage and subsalt raw salt storage. The high area outside the Santos Basin in the sub-salt source-salt storage zone is a favorable exploration direction for finding large oil and gas areas under the salt in the Santos Basin.
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Steventon, Michael J., Christopher A.-L. Jackson, David M. Hodgson, and Howard D. Johnson. "Lateral variability of shelf-edge and basin-floor deposits, Santos Basin, offshore Brazil." Journal of Sedimentary Research 90, no. 9 (September 1, 2020): 1198–221. http://dx.doi.org/10.2110/jsr.2020.14.

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ABSTRACT Construction of continental margins is driven by sediment transported across the shelf to the shelf edge, where it is reworked by wave, tide, and fluvial processes in deltas and flanking clastic shorelines. Stalling of continental-margin progradation often results in degradation of the outer shelf to upper slope, with resedimentation to the lower slope and basin floor via a range of sediment gravity flows and mass-movement processes. Typically, our understanding of how these processes contribute to the long-term development of continental margins has been limited to observations from broadly two-dimensional, subsurface and outcrop datasets. Consequently, the three-dimensional variability in process regime and margin evolution is poorly constrained and often underappreciated. We use a large (90 km by 30 km, parallel to depositional strike and dip, respectively) post-stack time-migrated 3D seismic-reflection dataset to investigate along-strike variations in shelf-margin progradation and outer-shelf to upper-slope collapse in the Santos Basin, offshore SE Brazil. Early Paleogene to Eocene progradation of the shelf margin is recorded by spectacularly imaged, SE-dipping clinoforms. Periodic failure of the outer shelf and upper slope formed ca. 30-km-wide (parallel to shelf-margin strike) slump scars, which resulted in a strongly scalloped upper-slope. Margin collapse caused: 1) the emplacement of slope-attached mass-transport complexes (MTCs) (up to ca. 375 m thick, 12+ km long, 20 km wide) on the proximal basin floor, and 2) accommodation creation on the outer shelf to upper slope. This newly formed accommodation was infilled by shelf-edge-delta clinoforms (up to 685 m thick), that nucleated and prograded basinward from the margin-collapse headwall scarp, downlapping onto the underlying slump scar and/or MTCs. Trajectory analysis of the shelf-edge deltas suggests that slope degradation-created accommodation was generated throughout the sea-level cycle, rather than during base-level fall as would be predicted by conventional sequence-stratigraphic models. Our results highlight the significant along-strike variability in depositional style, geometry, and evolution that can occur on this and other continental margins. Coeval strata, separated by only a few kilometers, display strikingly different stratigraphic architectures; this variability, which could be missed in 2D datasets, is not currently captured in conventional 2D sequence stratigraphic models.
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Dissertations / Theses on the topic "Northeast Santos basin, Brazil"

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Moreira, Da Costa Maia Renata. "Evolução estratigráfica cenozoica da porção norte da bacia de santos : quantificação do fluxo sedimentar e da subsidência através de análise sísmica e de modelagem estratigráfica." Thesis, Paris 6, 2014. http://www.theses.fr/2014PA066208/document.

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Le principal objectif de cette étude est de mieux comprendre et de quantifier les paramètres et les processus de contrôle de la morphologie et de l’évolution stratigraphique du nord du bassin de Santos pour les derniers 49,5 my. Il s’agit de déconvoluer le signal climatique et tectonique dans l’enregistrement sédimentaire à travers de l’analyse sismique à diverses résolutions (~7-8 s et ~400 ms de penetration), de l’analyse lithologique et le calage chrono stratigraphique des limites de séquence majeures, à partir de 19 forages industriels. La modélisation stratigraphique par Dionisos combinée à nos observations nous a permis de quantifier les paramètres majeurs qui vont contrôler l’architecture sédimentaire à différentes échelles de temps. 9 séquences stratigraphiques sont ainsi identifiées et regroupées en 3 mégaséquences (Mégaséquences A, B et C): (i) La Mégaséquence A est caractérisée par des systèmes deltaïques qui viennent remplir l’espace d’accommodation créé par le fluage du sel vers le bassin entre la baie de Guanabara et Cabo Frio. Le flux sédimentaire qui la nourrit est mis en relation avec le paléo fleuve du Paraíba do Sul qui se deplace vers le bassin de Campos à la fin du development de la Mégaséquence et resulte dans une drastique reduction des flux du bassin de Santos; (ii) La Mégasequence B est caractérisée par la rétrogradation de tous les systèmes sédimentaires comme une réponse directe à la diminution des flux sédimentaires. Cette megasequence est aussi caracterisée par l’implantation des depots contouritiques entre 30 et 21 Ma, problablement liés à des changements dans la circulation oceanique dû a l’ouverture de la passage de Drake et de la Tasmanie (entre 37 et 28 Ma); (iii) La Mégasequence C est caractérisée par une progradation et le déplacement des offlap breaks de 70 km vers l’océan, depuis les derniers 11.5 my comme réponse de l’augmentation de flux sédimentaire qui caractérise le passage à des cycles glacio-eustatiques marqués dans le Quaternaire
The main objective of this study is to better understand and to quantify experimentally the main parameters that control the geomorphological and stratigraphic evolution of the Cenozoic sedimentary succession of the northeast Santos basin, Brazil, in the last 49.5 my. For this purpose, a variety of combining methologies were used, such as: seismic analysis of a dataset composed of different resolution levels (~7-8 s and ~400 ms penetration), chronostratigraphic and lithological data from 19 exploratory wells and stratigraphic modeling. Seismic analysis and stratigraphic modelling led to the identification of 9 main stratigraphic sequences that could be grouped into 3 megasequences (Megasequences A, B and C): (i) Megasequence A is characterized by deltaic features developed into a ramp feature located between Guanabara Bay and Cabo Frio. The formation of this delta resulted in a sedimentary overcharge that induced the basinward salt migration. The sedimentary input that feeds this delta was interpreted as related to an ancient Paraíba do Sul River that diversion to the Campos basin at the end of the megasequence development, resulting in a dramatically reduce the sedimentary influxes into Santos basin; (ii) Megasequence B is characterized by the retrogradational trend of sedimentary systems that offset offlap break of surfaces developed at 30 and 21 Ma about 78 km landward. This megasequence is also characterized by the beginning of conturites deposition related to the changes of oceanic circulation due to the opening of Drake and Tasmanian passages; (iii) Megasequence C is characterized by progradational systems that resulted in the coastline shift about 70 km oceanwards, in the last 11.5 my. The dominant progradational trend of this sequence is interpreted as a response of the increase in the sedimentary influx rate intensified by the spectral characteristics and amplitude of the glacial-induced eustatic signal that characterizes the Quaternary period
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Moreira, Da Costa Maia Renata. "Evolução estratigráfica cenozoica da porção norte da bacia de santos : quantificação do fluxo sedimentar e da subsidência através de análise sísmica e de modelagem estratigráfica." Electronic Thesis or Diss., Paris 6, 2014. https://accesdistant.sorbonne-universite.fr/login?url=https://theses-intra.sorbonne-universite.fr/2014PA066208.pdf.

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Le principal objectif de cette étude est de mieux comprendre et de quantifier les paramètres et les processus de contrôle de la morphologie et de l’évolution stratigraphique du nord du bassin de Santos pour les derniers 49,5 my. Il s’agit de déconvoluer le signal climatique et tectonique dans l’enregistrement sédimentaire à travers de l’analyse sismique à diverses résolutions (~7-8 s et ~400 ms de penetration), de l’analyse lithologique et le calage chrono stratigraphique des limites de séquence majeures, à partir de 19 forages industriels. La modélisation stratigraphique par Dionisos combinée à nos observations nous a permis de quantifier les paramètres majeurs qui vont contrôler l’architecture sédimentaire à différentes échelles de temps. 9 séquences stratigraphiques sont ainsi identifiées et regroupées en 3 mégaséquences (Mégaséquences A, B et C): (i) La Mégaséquence A est caractérisée par des systèmes deltaïques qui viennent remplir l’espace d’accommodation créé par le fluage du sel vers le bassin entre la baie de Guanabara et Cabo Frio. Le flux sédimentaire qui la nourrit est mis en relation avec le paléo fleuve du Paraíba do Sul qui se deplace vers le bassin de Campos à la fin du development de la Mégaséquence et resulte dans une drastique reduction des flux du bassin de Santos; (ii) La Mégasequence B est caractérisée par la rétrogradation de tous les systèmes sédimentaires comme une réponse directe à la diminution des flux sédimentaires. Cette megasequence est aussi caracterisée par l’implantation des depots contouritiques entre 30 et 21 Ma, problablement liés à des changements dans la circulation oceanique dû a l’ouverture de la passage de Drake et de la Tasmanie (entre 37 et 28 Ma); (iii) La Mégasequence C est caractérisée par une progradation et le déplacement des offlap breaks de 70 km vers l’océan, depuis les derniers 11.5 my comme réponse de l’augmentation de flux sédimentaire qui caractérise le passage à des cycles glacio-eustatiques marqués dans le Quaternaire
The main objective of this study is to better understand and to quantify experimentally the main parameters that control the geomorphological and stratigraphic evolution of the Cenozoic sedimentary succession of the northeast Santos basin, Brazil, in the last 49.5 my. For this purpose, a variety of combining methologies were used, such as: seismic analysis of a dataset composed of different resolution levels (~7-8 s and ~400 ms penetration), chronostratigraphic and lithological data from 19 exploratory wells and stratigraphic modeling. Seismic analysis and stratigraphic modelling led to the identification of 9 main stratigraphic sequences that could be grouped into 3 megasequences (Megasequences A, B and C): (i) Megasequence A is characterized by deltaic features developed into a ramp feature located between Guanabara Bay and Cabo Frio. The formation of this delta resulted in a sedimentary overcharge that induced the basinward salt migration. The sedimentary input that feeds this delta was interpreted as related to an ancient Paraíba do Sul River that diversion to the Campos basin at the end of the megasequence development, resulting in a dramatically reduce the sedimentary influxes into Santos basin; (ii) Megasequence B is characterized by the retrogradational trend of sedimentary systems that offset offlap break of surfaces developed at 30 and 21 Ma about 78 km landward. This megasequence is also characterized by the beginning of conturites deposition related to the changes of oceanic circulation due to the opening of Drake and Tasmanian passages; (iii) Megasequence C is characterized by progradational systems that resulted in the coastline shift about 70 km oceanwards, in the last 11.5 my. The dominant progradational trend of this sequence is interpreted as a response of the increase in the sedimentary influx rate intensified by the spectral characteristics and amplitude of the glacial-induced eustatic signal that characterizes the Quaternary period
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Rodríguez, Tribaldos Verónica. "Epeirogeny of South America and evolution of Parnaíba Basin, northeast Brazil." Thesis, University of Cambridge, 2018. https://www.repository.cam.ac.uk/handle/1810/273673.

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It is recognised that some proportion of South American large-scale topography has been generated by convection within the Earth's mantle. Yet, spatial and temporal patterns of dynamic topography remain poorly understood. Variation of present-day dynamic topography can be mapped in the oceans by calculating residual depths with respect to the well-known age-depth relationship. Along the margins abutting South America, anomalies with amplitudes of $\pm1$ km and wavelengths of $\sim10^{3}$ km are observed. Onshore, dynamic topography is investigated by analysing a range of disparate datasets. Positive long-wavelength free-air gravity anomalies and slow shear-wave mantle velocities correlate with high plateaux of the Borborema Province and the Central Andean Altiplano. Admittance analyses of these regions are used to gauge dynamic support. Admittance of $ > 20$ mGal km$^{-1}$ at wavelengths $ > $ 500 km suggests partial dynamic support. In this context, inverse modelling of longitudinal river profiles is applied to retrieve a continental-scale uplift history. Erosional parameters are calibrated against an independently derived uplift history of the Borborema Province that reveals uplift in the last 30 Ma. Results suggest that the bulk of South American regional topography grew during Cenozoic times. In the Central Andean Altiplano and Southern Patagonia, most uplift occurred in the last 20 Ma. In both areas, widespread Cenozoic magmatism suggests that youthful uplift might be related to asthenospheric upwelling. Uplift histories are used to predict sediment flux to the Amazon Fan, which reveals that onset of the delta is a direct consequence of intensified Andean uplift. Analysis of the Parna\'iba cratonic basin of northeast Brazil is carried out to evaluate long-term evolution of vertical motions and to understand the mechanisms driving this basin's subsidence. Joint interpretation of a deep seismic reflection profile that traverses the basin and receiver function analyses reveal a 3 km thick basin underlain by three crustal blocks. Moho depths of 38--43 km are observed beneath the Amazon craton west of the basin, whereas depths of 35 km are found underneath the Borborema Province to the east. The Moho is located at 38--42 km depth beneath the basin. Stratigraphic architecture from shallow seismic reflection profiles reveals undisturbed deposition between Palaeozoic and Mesozoic times. Rift-type structures are locally imaged. Subsidence analysis reveals thermally-driven subsidence with thermal time constants of $\sim$ 70--80 Ma. Assessment of crustal thickness variations indicates that minimal extension of up to 80 km, with small stretching factors (up to 1.15), is plausible beneath Parna\'iba. One- and two-dimensional strain rate histories suggest that pre-Silurian rifting followed by thermal subsidence is possible if a minimum of 1 km of syn-rift deposition occurred. Basin-wide erosional unconformities are observed throughout the sedimentary section and correlate with departures from long-term subsidence trends. These steps are interpreted as transient uplift events that led to development of ephemeral landscapes, suggesting that dynamic topography could have played a role in the evolution of this Phanerozoic basin.
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Tozer, Brook. "Crustal structure, gravity anomalies and subsidence history of the Parnaíba cratonic basin, Northeast Brazil." Thesis, University of Oxford, 2017. https://ora.ox.ac.uk/objects/uuid:90ce8bb0-e55d-4b3c-87e1-aab60084ef42.

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Cratonic basins cover more than 10% of Earth's continental surface area, yet their origin remains enigmatic. In this thesis a suite of new and legacy geophysical and geological data are integrated to constrain the origin of the Parnaíba basin, a cratonic basin in Northeast Brazil. These data include a 1400 km long, deep (20 s two-way travel time) seismic reflection profile, five +/- 110 km offset wide-angle split-spread receiver gathers, gravity anomaly, and well data. In the centre of the basin, the depth to pre-Paleozoic basement is ~ 3.3 km, a zone of midcrustal reflectivity (MCR) can be traced laterally for ~ 250 km at depths between 17-25 km and Moho depth is ~ 42 +/- 2 km. Gravity and P-wave modelling suggests that the MCR represents the upper surface of a high density (2985 kg m3) and Vp (6.7 - 7.0 km s-1) lower crustal body, likely of magmatic origin. Backstripping of well data shows a concave up decreasing tectonic subsidence, similar in form to that commonly observed in rift-type basins. It is shown, however, that the seismic and gravity data are inconsistent with an extensional origin. It is shown that an intrusive body in the lower crust that has loaded and flexed the surface of the crust, combined with sediment loading, provides a satisfactory fit to the observed gravity anomaly, sediment thickness and basin shape. A buried load model is also consistent with seismic data, which suggest that the Moho is as deep or deeper beneath the basin centre than its flanks and accounts for at least part of the tectonic subsidence through a viscoelastic stress relaxation that occurs in the lithosphere following load emplacement. Comparative analysis of the Michigan and Congo basins shows gravity data from these basins is also consistent with a lower crustal mass excess, while subsidence analysis shows viscoelastic stress relaxation may also contribute to their early subsidence histories. However, unlike Parnaíba, both of these basins appear to have been subjected to secondary tectonic processes that obscure the primary 'cratonic basin' subsidence signals. Parnaíba basin, therefore, offers an excellent record for the investigation of cratonic basin formation.
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Ashby, David Edward. "Influences on continental margin development : a case study from the Santos Basin, south-eastern Brazil." Thesis, Durham University, 2013. http://etheses.dur.ac.uk/6989/.

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South Atlantic margins display significant variation in structural style along their length. An understanding of factors that influence this variation in structural style is a key component in any understanding of the evolution of the South Atlantic. The Santos basin is an obliquely rifted basin located offshore SE Brazil. Structures in the basin are thought to have been influenced by the reactivation of basement structures and/or fabrics during the onset of the Gondwana breakup. The onshore region adjacent to the Santos Basin offers the chance to test whether basement structures have played a significant role in influencing the initiation and development of syn-rift faults, dykes and fractures. Field and remote sensing studies of the onshore region and on the conjugate margin in Africa show the strong geometric and temporal link between major 135Ma dyke swarms and the development of faults and fractures. 3 structural domains are defined, and correlated with lineament domains from the African margin. Faults, dykes and fractures within the lineament domains in SE Brazil share consistent orientations as large scale morphotectonic lineaments. Brittle structures show orientations and kinematics that are consistent with regional E-W oriented transtension. Little evidence of basement influence can be seen at outcrop scale, although it is speculated that larger scale structures may be reactivated. Faults in the offshore basin share similar geometries to brittle structures onshore. As rifting progressed, and dyke intrusion ceased, NNE-SSW trending structures to the north of the basin ceased to be active, while N-S trending extensional faults continued to deform. N-S trending faults and fractures are also observed to cut dykes in the onshore region. The importance of understanding onshore geology when interpreting offshore basins is highlighted in this study, as is the need to integrate diverse datasets when trying to understand the complex influences on margin development.
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Cardona, Milagros Gabriela da Cruz. "Taxonomic description of five new species of Blattodea Crato Member, Santana formation, Araripe Basin, Northeast Brazil." Universidade Federal do CearÃ, 2016. http://www.teses.ufc.br/tde_busca/arquivo.php?codArquivo=17101.

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FundaÃÃo Cearense de Apoio ao Desenvolvimento Cientifico e TecnolÃgico
A riquÃssima assembleia fossilÃfera encontrada na FormaÃÃo Santana do CretÃceo da Bacia do Araripe, alberga uma grande quantidade de insetos fÃsseis, incluindo a ordem "Blattaria", especialmente no Membro Crato de idade Albiana-Aptiana. A alta taxa de preservaÃÃo destes organismos e das suas partes mais frÃgeis, como as asas, acontece graÃas ao ambiente lacustre e de baixa energia em que foram depositados. As asas, tambÃm denominadas por tÃgminas, possuem um padrÃo de nervuras que permite avaliar exatamente a sua importÃncia taxonÃmica no meio paleontomolÃgico. No presente trabalho à realizado um estudo taxonÃmico, onde sÃo descritas cinco novas espÃcies provenientes do calcÃrio laminado da porÃÃo superior do Membro Crato da Mina Pedra Branca em Nova Olinda, CearÃ. Os exemplares descritos encontram-se incluÃdos, um no gÃnero Mesoblattinopsis Pinto 1989, um no gÃnero Blattulopsis Pinto 1990 e trÃs no gÃnero Mesoblattina Geinitz 1880. Para isso e para uma melhor organizaÃÃo dos critÃrios que permitiram incluÃ-las nos gÃneros mencionados anteriormente foram elaboradas tabelas que mostram as principais diferenÃas entre os exemplares e as espÃcies jà descritas.
A riquÃssima assembleia fossilÃfera encontrada na FormaÃÃo Santana do CretÃceo da Bacia do Araripe, alberga uma grande quantidade de insetos fÃsseis, incluindo a ordem "Blattaria", especialmente no Membro Crato de idade Albiana-Aptiana. A alta taxa de preservaÃÃo destes organismos e das suas partes mais frÃgeis, como as asas, acontece graÃas ao ambiente lacustre e de baixa energia em que foram depositados. As asas, tambÃm denominadas por tÃgminas, possuem um padrÃo de nervuras que permite avaliar exatamente a sua importÃncia taxonÃmica no meio paleontomolÃgico. No presente trabalho à realizado um estudo taxonÃmico, onde sÃo descritas cinco novas espÃcies provenientes do calcÃrio laminado da porÃÃo superior do Membro Crato da Mina Pedra Branca em Nova Olinda, CearÃ. Os exemplares descritos encontram-se incluÃdos, um no gÃnero Mesoblattinopsis Pinto 1989, um no gÃnero Blattulopsis Pinto 1990 e trÃs no gÃnero Mesoblattina Geinitz 1880. Para isso e para uma melhor organizaÃÃo dos critÃrios que permitiram incluÃ-las nos gÃneros mencionados anteriormente foram elaboradas tabelas que mostram as principais diferenÃas entre os exemplares e as espÃcies jà descritas.
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Santos, Alice Nataraja Garcia [Verfasser], and Rainer [Akademischer Betreuer] Rothfuß. "Wind energy, territory and environmental justice on the northeast coast of Brazil / Alice Nataraja Garcia Santos ; Betreuer: Rainer Rothfuß." Tübingen : Universitätsbibliothek Tübingen, 2016. http://d-nb.info/1198121416/34.

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Santos, Alice [Verfasser], and Rainer [Akademischer Betreuer] Rothfuß. "Wind energy, territory and environmental justice on the northeast coast of Brazil / Alice Nataraja Garcia Santos ; Betreuer: Rainer Rothfuß." Tübingen : Universitätsbibliothek Tübingen, 2016. http://d-nb.info/1198121416/34.

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Cardoso, de Melo Guerra Marta. "Role of halokinesis in controlling structural styles and sediment dispersal patterns in the Santos Basin, offshore SE Brazil." Thesis, University of Edinburgh, 2008. http://hdl.handle.net/1842/12158.

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Souza, Rogério Schiffer. "Integrated diagenetic modeling and reservoir quality assessment and prediction of the Água Grande sandstones, early Cretaceous, Recôncavo Basin, northeast Brazil /." Digital version accessible at:, 1999. http://wwwlib.umi.com/cr/utexas/main.

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Books on the topic "Northeast Santos basin, Brazil"

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Mello, Marcio Rocha, Pinar Oya Yilmazn, and Barry J. Katz, eds. Memoir 124: The Supergiant Lower Cretaceous Pre-Salt Petroleum Systems of the Santos Basin, Brazil. AAPG, 2021. http://dx.doi.org/10.1306/aapg124.

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Book chapters on the topic "Northeast Santos basin, Brazil"

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Liu, Ya-ming. "Salt Evolution Mechanism and Hydrocarbon Accumulation in Santos Basin, Brazil." In Proceedings of the International Field Exploration and Development Conference 2021, 3527–35. Singapore: Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-2149-0_330.

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Ashabranner, L. B., E. K. Tripsanas, and R. C. Shipp. "Multi-direction Flow in a Mass-Transport Deposit, Santos Basin, Offshore Brazil." In Submarine Mass Movements and Their Consequences, 247–55. Dordrecht: Springer Netherlands, 2010. http://dx.doi.org/10.1007/978-90-481-3071-9_20.

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Yang, Xiao-fa, Zuo-ji Tian, Ya-ming Liu, Zhong-zhen Ma, Yu-bing Zhou, Yong-bin Zhao, Dan-dan Wang, and Tong-fei Huang. "Early Cretaceous Volcanism and Its Control on Tectonic Framework in the Santos Basin, Offshore Brazil." In Springer Series in Geomechanics and Geoengineering, 547–57. Singapore: Springer Nature Singapore, 2024. http://dx.doi.org/10.1007/978-981-97-0464-4_44.

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de Lima, Flaviana Jorge, Etiene Fabbrin Pires, Antônio Álamo Feitosa Saraiva, Juliana Manso Sayão, André Jasper, and Dieter Uhl. "Early Cretaceous (Aptian–Albian) Wildfires in the Araripe Basin, Northeast Brazil: Palaeoclimatic and Palaeoenvironmental Implications." In Brazilian Paleofloras, 1–12. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-319-90913-4_32-1.

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DA SILVA, HERCULES TADEU F., B. C. Vendeville, and R. E. Martin. "Sediment Accumulation Rates of the Lower Cretaceous Tectonosequence, Recôncavo Basin, Northeast Brazil." In Rates of Geologic Processes, Tectonics, Sedimentation, Eustasy and Climate - Implications for Hydrocarbon Exploration: 14th Annual, 9–18. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 1993. http://dx.doi.org/10.5724/gcs.93.14.0009.

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Ciotta, Mariana. "CO2 Geological Storage in Santos Basin: Potential and Best Suitable Sites." In Perspectives to CO2 Geological Storage and Greenhouse Gas Negative Emissions in South-Southeastern Brazil: Paraná and Santos Sedimentary Basins, 27–40. Editora Blucher, 2022. http://dx.doi.org/10.5151/9786555501346-02.

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Michelon, Diogo, Edmundo Marques, Jorge Figueiredo, Heitor Ferraz, and Paulo Barros. "Santonian-Campanian Channelized Systems of the Santos Basin, Brazil: Stratigraphic Framework and Reservoir Potential." In New Understanding of the Petroleum Systems of Continental Margins of the World: 32nd Annual, 381–96. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 2012. http://dx.doi.org/10.5724/gcs.12.32.0381.

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Karner, G. D., C. Johnson, J. Shoffner, M. Lawson, M. Sullivan, J. Sitgreaves, J. McHarge, J. Stewart, and P. Figueredo. "Chapter 9: Tectono-Magmatic Development of the Santos and Campos Basins, Offshore Brazil." In Memoir 124: The Supergiant Lower Cretaceous Pre-Salt Petroleum Systems of the Santos Basin, Brazil, 215–56. AAPG, 2021. http://dx.doi.org/10.1306/13722321msb.9.1853.

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Tavares dos Santos, P., and A. C. Gordon. "Chapter 14: Búzios Field: Geological Setting of the Largest Pre-Salt Field, Santos Basin, Brazil." In Memoir 124: The Supergiant Lower Cretaceous Pre-Salt Petroleum Systems of the Santos Basin, Brazil, 375–94. AAPG, 2021. http://dx.doi.org/10.1306/13722365msb.14.1853.

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Pinheiro, Marcio Soares, and Paulo Roberto Duailibe Monteiro. "Decommissioning strategies for fixed offshore platforms in Brazil." In UNITING KNOWLEDGE INTEGRATED SCIENTIFIC RESEARCH FOR GLOBAL DEVELOPMENT. Seven Editora, 2023. http://dx.doi.org/10.56238/uniknowindevolp-012.

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In the early 1970s, consumption of petroleum products in Brazil doubled. With that, was great the need the discoveries of new wells. The possibilities for expanding production were at sea, which began to receive even more attention. After the discovery of the first offshore field, in Sergipe, Petrobras made more than 20 discoveries on the coast of several states. It was the beginning of a new era. In 1977, the Campos Basin, located between the states of Espírito Santo and Rio de Janeiro, began its commercial offshore production, becoming the most important oil province in Brazil until the discovery of the Pre-Salt province, in the Santos Basin. As these fields are producing for a long time, many of them are already completely depleted or their production is in way of to be not commercial anymore, and their facilities need to be decommissioned. This review of decommissioning practices of fixed offshore platforms carried out worldwide has focus on the removal of topside with special vessels designed for this purpose or with conventional methods (crane vessels + barge). It will show the benefits of using specialised heavy lift vessels to remove the topsides and move it to shore for dismantling / recycling / reuse / disposal. The cases for study were the successful decommissioning projects in the North Sea: Brent B/D, Valhall QP, Viking, Curlew, Eider A, Golden Eye and Leman, Iwaki-Oki, Halfweg Q1, Yme and Ninian North.
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Conference papers on the topic "Northeast Santos basin, Brazil"

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Tavakoli, B., S. Whitehead, P. T. Trinh, B. Duquet, and S. Rhodde. "Amplitude Friendly Imaging for Elastic Inversion: A Brazilian Offshore Case Study." In Offshore Technology Conference Brasil. OTC, 2023. http://dx.doi.org/10.4043/32790-ms.

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Abstract The Lapa field is situated in block BM-S-09 of the Santos Basin, with production having started some years ago. Here the pre-salt reservoir rocks are formed by the Aptian microbial carbonates of Itapema and Barra Velha Formations. More precisely, the target lays in a marginal high in a mantle-decoupled domain under extension constraint with transfer zone and local inversion. The hydrocarbon bearing reservoirs are oil-bearing showing a 4-way dip closure with one main porous sequence and a tight zone underneath. With the northeast part of the field already well developed, the context of a re-processing, imaging and inversion program is that of a planned increase in activity in the southwest part of the field. The southwest part of the field is complicated by rapidly changing thickness of overburden salt, that can have an impact on seismic products. The objective of the study is to get a seismic image more suitable for the interpretation of this structurally complex field, with reliable amplitude information for lithology and porosity characterization of Lapa reservoirs. Amplitudes on seismic images can reveal important information regarding Petro-Elastic (PE) properties of geological formations. "Amplitude preservation" during seismic data processing and imaging is key for many exploration and development projects. Though in data processing steps (pre-migration) this is assured by direct evaluation of input and output data amplitudes, in the imaging process, amplitude preservation is a more effortful task. This is mainly due to the complications concerning imaging algorithms (e.g. the approximations for wave propagation regime) and geological complexity of the subsurface. For example, in complex media, such as deep salt structures, imaging algorithms based on asymptotic approximation of wave propagation (e.g. Kirchhoff and Beam migration) may not deliver very accurate images (from structural and amplitude perspectives). Therefore, for subsurface imaging of complex zones, industry tends toward more accurate algorithms such as Reverse Time Migration (RTM) and Least Squares (LS) imaging. Moreover, for elastic inversion based on or AVO/AVA principles (Amplitude Variation with respect to Offset/Angle) one needs to create offset/angle gathers in an amplitude friendly manner. In this study, we present our workflow to produce an amplitude friendly image with a high SNR (signal to noise ratio) suitable for elastic inversion.
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Vogel, Michael, Ilson Carlos Almeida da Silveira, Belmiro Mendes de Castro Fiho, Jose Antonio Lima, Adriene Pereira, and Paul Williams. "Metocean Measurements at Northern Santos Basin - Brazil." In Offshore Technology Conference. Offshore Technology Conference, 2010. http://dx.doi.org/10.4043/20947-ms.

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Huang, Yan, Dechun Lin, Bing Bai, and Cesar Ricardez. "Pre‐salt depth imaging of Santos Basin, Brazil." In SEG Technical Program Expanded Abstracts 2009. Society of Exploration Geophysicists, 2009. http://dx.doi.org/10.1190/1.3255446.

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Fiduk, Joseph Carl. "Analysis of Layered Evaporites Within the Santos Basin, Brazil." In Offshore Technology Conference. Offshore Technology Conference, 2010. http://dx.doi.org/10.4043/20938-ms.

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Klarner, S., B. Ujetz, R. Fontana, and J. Altenkirch. "Seismic Signature of Upper Cretaceous Volcanics; Santos Basin, Brazil." In 68th EAGE Conference and Exhibition incorporating SPE EUROPEC 2006. European Association of Geoscientists & Engineers, 2006. http://dx.doi.org/10.3997/2214-4609.201402348.

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De Lima, Fabiano Marcos, Carlos Correa Junior, William Soares Filho, Catia Galottas, José Antonio Moreira Lima, and Thiago Pires de Paula. "An underwater acoustic modelling framework for Santos Basin, Brazil." In 179th Meeting of the Acoustical Society of America. ASA, 2020. http://dx.doi.org/10.1121/2.0001347.

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Andrioni, Marcelo, Jose Antonio Moreira Lima, Luiz Alexandre Guerra, Eric Oliveira Ribeiro, Luis Manoel Paiva Nunes, Wellington Ceccopieri, Valéria de Souza Rego, and Silas Manoel de Oliveira. "Ocean Eddies’ Influence on Lula Field, Santos Basin, Brazil." In ASME 2012 31st International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2012. http://dx.doi.org/10.1115/omae2012-83480.

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Current data measured by an instrumented mooring line deployed at the Santos Basin, in a water depth of 2200 m, show a mean velocity of 0.20 m/s with no preferential direction. Extreme current events detected were associated with the presence of a pair of eddies with a dipole configuration. The jet stream created by the interaction of the cyclone-anticyclone pair was able to generate speeds up to 1.2 m/s at the first hundred meters of the water column. An investigative study with sea surface height anomaly fields processed from environmental satellites clearly shows the eddy structure during extreme current events.
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Egorov, Vsevolod, Alex Blacque, S. V. (Rao) Yalamanchili, James Cokinos, Rachel Masters, Kenneth Mohn, and Michael Davidson. "Continental‐oceanic boundary indicators in the Santos Basin, Brazil." In SEG Technical Program Expanded Abstracts 2007. Society of Exploration Geophysicists, 2007. http://dx.doi.org/10.1190/1.2792557.

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Zhang, Jie, Dali Shao, Hongping Wang, Guozhang Fan, Chaofeng Wang, Hongying Deng, and Yonggang Zhang. "Sequence Stratigraphy and Reservoir Characteristics of Offshore Santos Basin, Brazil." In Offshore Technology Conference. Offshore Technology Conference, 2016. http://dx.doi.org/10.4043/26915-ms.

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P. Buonora, M., A. Zerilli, T. Labruzzo, and L. F. Rodrigues. "Advancing Marine Controlled Source Electromagnetics in the Santos Basin, Brazil." In 70th EAGE Conference and Exhibition - Workshops and Fieldtrips. European Association of Geoscientists & Engineers, 2008. http://dx.doi.org/10.3997/2214-4609.20147717.

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