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

Author: Grafiati

Published: 4 June 2021

Last updated: 25 May 2024

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1

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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Ciotta, Mariana Ramos, and Colombo Celso Gaeta Tassinari. "CO2 storage in southeastern Brazil: perspectives in the Santos Basin." Rio Oil and Gas Expo and Conference 20, no. 2020 (December 1, 2020): 546–47. http://dx.doi.org/10.48072/2525-7579.rog.2020.546.

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Vilarinho, Naiara, Maíra Xavier Araújo, Freddy Bravo, and Claudiney Biral Dos Santos. "Two new species of Arisemus (Diptera: Psychodidae) from the Northeast Atlantic Forest, Brazil." EntomoBrasilis 14 (September 8, 2021): e961. http://dx.doi.org/10.12741/ebrasilis.v14.e961.

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Arisemus atlanticus Vilarinho, Araújo, Bravo & dos Santos sp. nov. and Arisemus benignoi Vilarinho, Araújo & Bravo sp. nov. are described from the Central Corridor of the Atlantic Forest. Currently, thirty-three species of the genus has been described from the Neotropical Region and only one from Brazil.

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JPT staff, _. "E&P Notes (June 2021)." Journal of Petroleum Technology 73, no. 06 (June 1, 2021): 14–19. http://dx.doi.org/10.2118/0621-0014-jpt.

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Angola Opens Congo, Kwanza Blocks in Ongoing Bid Round Angola’s National Oil, Gas, and Biofuel’s Agency has opened blocks for licensing in the Onshore Lower Congo Basin and the Onshore Kwanza Basin as part of its 2020 oil and gas licensing round. This latest call to tender is part of the agency’s ongoing 2019–2025 hydrocarbons licensing strategy. The Onshore Lower Congo Basin Blocks include CON1, CON5, and CON6; while the Onshore Kwanza Basin Blocks comprise KON5, KON6, KON8, KON9, KON17, and KON20. The round aims to expand research and evaluation activities across sedimentary basins, increase geological knowledge of Angola’s hydrocarbon potential, and invite a new wave of explorers to yield new discoveries. Raven Field Startup for BP in Egypt Natural gas has begun flowing from the BP-operated Raven field, the third stage of the company’s major West Nile Delta (WND) development off the Mediterranean coast in Egypt. The $9-billion WND development includes five gas fields across the North Alexandria and West Mediterranean Deepwater offshore concession blocks in the Mediterranean Sea. Raven is currently producing approximately 600 MMcf/D with a peak potential of 900 MMcf/D and 30,000 B/D of condensate. Raven follows the Taurus/Libra and Giza/Fayoum projects, which started production in 2017 and 2019, respectively. It produces gas to a new onshore processing facility, alongside the existing WND onshore processing plant. In total, the WND development includes 25 wells producing gas to the onshore processing plant via three long-distance subsea tiebacks. The onshore facilities—including the new Raven facility—now have a total gas processing capacity of around 1.4 Bcf/D of gas. All gas produced is fed into Egypt’s national grid. BP is the operator and has an 82.75% stake in the WND development, with Wintershall Dea holding the remaining 17.25% interest. CGX Secures Rig for Kawa-1 Well off Guyana CGX Energy and Frontera Energy, joint venture partners in the Petroleum Prospecting License for the Corentyne block offshore Guyana, have secured semisubmersible Maersk Discoverer to drill the Kawa-1 well. An early third quarter spud for the exploration well is targeting a Santonian age, stratigraphic trap, interpreted to be analogous to the discoveries immediately to the east on Block 58 in Suriname. The well is anticipated to be drilled to a total depth of approximately 6500 m in a water depth of approximately 370 m. The contract has an estimated duration of 75–85 days and has a one-well option attached. If exercised, that probe would spud in the nearby Demerara Block and take an estimated 40 days to reach its target. Talos’ Bulleit Reservoir in US Gulf Smaller Than Expected A technical assessment of the main producing sand performance at Talos Energy’s Green Canyon Block 21 Bulleit field in the US Gulf has indicated a smaller reservoir than originally anticipated. Project partner Otto Energy said the assessment included detailed bottomhole pressure and reservoir performance data collected after hookup and first production. The Block 21 field is flowing via a single subsea well tied back to a platform in nearby Green Canyon Block 18. While additional technical work is ongoing, the currently favored path forward is to move away from the current sand and execute a recompletion of the well in the shallower DTR-10 sand. A DTR-10 recompletion will require the procurement of long-lead items from manufacturers, which are expected to cost $3.5 million with payment expected in mid-2021. The recompletion is expected to begin in mid-2022, with production from the DTR-10 immediately following in mid-to late 2022. Captain Field EOR Stage 2 Project a Go Ithaca Energy, operator of the Captain field, has sanctioned the Captain Enhanced Oil Recovery (EOR) Stage 2 project in the UK Central North Sea after receiving Field Development Plan Addendum consent from the Oil and Gas Authority. EOR Stage 2 is designed to significantly increase hydrocarbon recovery by injecting polymerized water into the reservoir through additional subsea wells, subsea infrastructure, and new topsides facilities. Stage 1 of the project demonstrated that polymer EOR technology can work, with the production response in line with or better than expected across all injection patterns, helping maximize economic recovery. The Captain field was discovered in 1977, in Block 13/22a located on the edge of the outer Moray Firth. The billion-barrel field achieved first production in March 1997—over 24 years ago. Ithaca Energy holds 85% working interest, while partner Dana Petroleum holds the remaining 15%. Equinor Touts new Tyrihans Field Discovery Equinor and partners Total E&P Norge AS and Vår Energi AS have struck oil and gas in a new segment belonging to the Tyrihans field in the Norwegian Sea. Exploration well 6407/1-A-3 BH in production license 073 was drilled from sub-sea template A at Tyrihans North. The well was drilled to a measured depth of 5332 m by semisubmersible drilling rig Transocean Norge and struck a gas column of about 43 m and an oil column of about 15 m in the Ile formation, including about 76 m of moderate to good reservoir quality sandstone. In the Tilje formation, moderate to good quality water-bearing reservoir was struck. The Tyrihans field is in the middle of the Norwegian Sea, some 25 km southeast of the Åsgard field and 220 km northwest of Trondheim. The licensees consider the discovery commercial and intend to start production immediately. Recoverable resources are so far estimated at between 19 and 26 million BOE. Maersk Awarded Intervention Work off Brazil Maersk Drilling has been awarded a contract with Karoon Energy Ltd. for the semisubmersible rig Maersk Developer to perform well intervention on four wells at the Baúna field offshore Brazil. The contract is expected to begin in the first half of 2022, with a firm duration of 110 days. The value of the contract is $34 million, including rig modifications and a mobilization fee. The contract contains options to add up to 150 days of drilling work at the Patola and Neon fields. Carnarvon Completes Farmout of Buffalo Project Carnarvon Petroleum has completed the farmout of 50% of the Buffalo project to Advance Energy PLC. On 17 December 2020, Carnarvon announced that Advance Energy would acquire 50% of the Buffalo project off the west coast of Australia by funding the drilling of the Buffalo-10 well up to $20 million on a free carry basis. Advance met this funding requirement and now has a 50% interest in the project. The well is on track to be drilled in late 2021, subject to securing a drilling rig, where the tendering process is already underway. Following the well, the joint venture will acquire development funding from third-party lenders and any additional funding will be provided by Advance as an interest-free loan. The current plan is to suspend a successful well as a future producer and begin early development studies during 2021. Shell Hires Seadrill Rig for Brazilian Campaign Shell has contracted Seadrill’s drillship West Tellus for a new drilling campaign offshore Brazil this year. The program is expected to start in BC-10 of the Campos Basin, where Shell operates the Parque das Conchas made up of the Abalone, Argonauta, and Ostra fields. BC-10 has produced more than 100 million bbl since oil first started flowing from the block in 2009. The drillship will be used on the third phase of BC-10 activity, which includes five additional production wells and two water-injection wells at the Massa and Argonauta O-Sul fields, with the wells connected to the Espirito Santo FPSO. Shell owns a 50% operating stake in BC-10. India’s ONGC retains a 27% minority share and Qatar Petroleum the remaining 23%. Following the BC-10 work, the operator is expected to drill the first wells in the Campos Basin’s C-M-791 block, which was acquired during the 15th bid round held in 2017. Shell owns a 40% operating stake in the block, with Chevron retaining a 40% interest and Portugal’s Galp Energia the remaining 20%. Panoro Energy Kicks Off 2021 Drilling Campaign Offshore Gabon Panoro Energy has initiated its 2021 Gabon drilling campaign with the spudding of the Hibiscus Extension well on the Dussafu Marin Permit. That well will be followed by drilling at Tortue and Hibiscus North. Hibiscus and Tortue are two out of a total of six discovered fields within the Dussafu Permit offshore Gabon. Panoro currently holds a 7.5% interest in the license and has entered into an agreement to acquire an additional 10% working interest in the Dussafu Permit, bringing its total ownership to 17.5% following completion of the transaction. The Extension well is being drilled with the jackup Borr Norve and is the first well in a three-well campaign planned on Dussafu during 2021. The well is planned as a vertical well to test structure, oil, and reservoir presence in what is believed to be a possible northerly extension of the Gamba reservoir in the Hibiscus field. The well is positioned about 3 km northwest of the Hibiscus discovery well drilled by the joint venture in 2019. The initial well and its appraisal sidetrack established a 2P gross recoverable reserves of just over 46 million bbl at the Hibiscus field. The Extension well is expected to take around 30 days to drill and log to a total depth of 3500 m. Success at the probe could prompt one or two appraisal side-tracks to further delineate the field. Following the Hibiscus Extension, the rig will move to drill a horizontal production well, DTM-7H, at the Tortue field. This will complete the Phase 2 development of Tortue and, along with DTM-6H, will bring the total number of production wells at Tortue up to six. An exploration well at the Hibiscus North prospect, located approximately 6 km north-northeast of the initial Hibiscus well is also scheduled. Hibiscus North is a separate 10–40 million bbl prospect that could be tied into the Hibiscus/Ruche development project. Puma West Strike for BP in the US Gulf An exploration well at the Puma West prospect in the deepwater US Gulf has yielded a significant oil discovery for operator BP. The well, on Green Canyon Block 821, was drilled using Seadrill drillship West Auriga to a total depth of 23,530 ft and encountered oil pay in a high-quality Miocene reservoir with fluid properties like productive Miocene reservoirs in the area. Preliminary data supports the potential for a commercial volume of hydrocarbons. The Puma West partners will begin planning an appraisal program to better define the discovered resource. The discovery well has been suspended as a keeper well to preserve future utility. Puma West is located west of the BP-operated Mad Dog field and is approximately 131 miles off the coast of Louisiana in 4,108 ft of water. The Puma West is operated by BP with a 50% working interest. Partners include Chevron with 25% and Talos Energy with the remaining 25%. Petrobras Pushes First Oil at Mero Into 2022 Petrobras has postponed first oil from its Mero 1 field via the FPSO Guanabara in the Santos Basin offshore Brazil due to delays with the production system. Startup at Mero 1 was originally expected in the fourth quarter of this year and is now expected to begin flowing during the first quarter of 2022 due to COVID-19 pandemic-related delays with the buildout of the production system in China. The FPSO will be installed in the Mero field, which belongs to the Libra Block, in the Santos Basin pre-salt area, with a processing capacity of 180,000 OPD. The field is operated by Petrobras (40%) in partnership with Shell Brasil Petróleo (20%), Total E&P (20%), CNODC Brasil Petróleo e Gás (10%), CNOOC Petroleum Brasil (10%), and Pré-Sal Petróleo, which is the contract manager.

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Freitas, Javanna L. G. da S., Jaíza M. M. Silva, Júlia Cristina L. Nóbrega, Raisa F. M. Simões, Juliana B. Medeiros, Ricardo O. Alves, Jair L. F. Santos, et al. "Health-Related Quality of Life and Associated Factors: Regional Differences Among Oldest-Old in Brazil." INQUIRY: The Journal of Health Care Organization, Provision, and Financing 59 (January 2022): 004695802210869. http://dx.doi.org/10.1177/00469580221086922.

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Purpose The aim of this research was to investigate the extent to which socioeconomic and regional differences in Brazil may influence the quality of life. To this end, we examined factors associated with health-related quality of life in two populations of oldest-old people, aged 80 and over: one from the Northeast of Brazil and the other from the Southeast. Methods 417 participants aged 80 and over were interviewed face-to-face, 179 from Brejo dos Santos, one of the poorest regions in the Northeast; and 238 from São Paulo, one of the largest urban metropolises in Southeast Brazil. Data, which included socioeconomic and demographic factors, health status, and health-related quality of life, were collected using a structured questionnaire. The dependent variable was determined by the completion rate of the 12-item Short Form Survey and analyzed using multiple logistic regression. Results Although the population of São Paulo had four times as many long-lived women than men, had better literacy levels, used more medications, and presented a greater prevalence of symptoms suggestive of depression in comparison to the Northeast’s population, no difference was observed in the proportion of good physical components among the two populations, 54.3% in Brejo dos Santos’ oldest-old and 50.4% in São Paulo’s ( P = .6272). Quality and quantity of sleep were factors that most affected the health-related quality of life among the oldest-old of Northeast. Conclusion Factors associated with health-related quality of life were different among the oldest-old people of the two locations, thereby corroborating the heterogeneous nature of the longevous population.

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Constantino, Renata, and Eder Cassola Molina. "BASEMENT STRUCTURES IN SANTOS BASIN (BRAZIL) FROM SATELLITE ALTIMETRY AND MARINE GEOPHYSICS." Revista Brasileira de Geofísica 33, no. 1 (November 19, 2015): 29. http://dx.doi.org/10.22564/rbgf.v33i1.599.

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ABSTRACT. This paper estimated the basement depth of the Santos Basin region, S˜ao Paulo State, Brazil, combining gravity data obtained from satellite altimetry and marine gravimetry, bathymetric data and sediment thickness from international data banks, and crustal thickness data available in the region. The first step consisted of calculating the gravity effect of sediments in Santos Basin, and the Crustal Mantle Interface (CMI) was modeled from constrained gravity inversion. Subsequently, the reliability of the models obtained was tested by flexural analysis with satisfactory results, as the flexural and gravimetric CMIs showed good agreement. The gravity effect of flexural CMI and the gravity effect of sediments were then calculated and subtracted from the original Bouguer anomaly. The residual field thus obtained, which is assumed to represent the topographical features of the basement, was inverted in the last step of the work, providing information that shows a basement with features of up to 700 m that appear to be in agreement with tectonic features previous discussed, such as the Avedis volcanic chain. The basement depth estimated during this study showed depths ranging from 1,500 to 10,500 m, and the deepest region is consistent with the Cabo Frio Fault. The methodology used in the study showed that from a combined data analysis, it is possible to obtain a three-dimensional model of the basement in ocean areas. This non-seismic approach can be advantageous in terms of efficiency and cost. The knowledge of the basement can offer important insights for the development of genetic and tectonic models of exploratory interest in the region.Keywords: basement, Santos Basin, gravity. RESUMO. Este trabalho visa estimar a profundidade do embasamento na região da Bacia de Santos por meio de uma análise combinada de dados gravimétricos obtidos a partir de altimetria por satélite e gravimetria marinha, com dados batimétricos e modelos de espessura sedimentar provenientes de bancos de dados internacionais e dados de espessura crustal disponíveis na região. Na primeira etapa do trabalho foi calculado o efeito do pacote sedimentar no sinal gravimétrico na Bacia de Santos, como também foi modelada a profundidade da Interface Crosta Manto (ICM) a partir de inversão gravimétrica com vínculos. Na etapa seguinte, a confiabilidade dos modelos obtidos foi testada através de an´álise flexural e o resultado foi satisfatório, mostrando que a ICM flexural e a ICM gravimétrica estão em concordância. Prosseguindo para etapa seguinte, o efeito gravimétrico da ICM encontrada por análise flexural e o efeito gravimétrico dos sedimentos foram então calculados e subtraídos da anomalia Bouguer original. O campo residual assim obtido, que se admite representar as feições topográficas do embasamento, foi invertido na última etapa do trabalho, fornecendo informações que mostram um embasamento com feições topográficas de até 700 m, que parecem estar em concordância com feições tectônicas discutidas em trabalhos pretéritos, como por exemplo a cadeia vulcânica Avedis. A profundidade do embasamento estimada durante este trabalho mostrou profundidades que vão desde 1.500 a 10.500 m, sendo que a região mais profunda corresponde à falha de Cabo Frio. Este trabalho demonstrou que, a partir de uma análise combinada de dados, é possível obter um modelo tridimensional do embasamento. O método, por ser não sísmico, pode ser vantajoso em questões de eficiência. O conhecimento deste embasamento é crucial na identificação de feições tectônicas, enquanto as informações sobre sua profundidade e topografia podem oferecer importantes subsídios para a elaboração de modelos genéticos e tectônicos de interesse exploratório na região.Palavras-chave: embasamento, Bacia de Santos, gravimetria.

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Huang, Yan, Dechun Lin, Bing Bai, Stan Roby, and Cesar Ricardez. "Challenges in presalt depth imaging of the deepwater Santos Basin, Brazil." Leading Edge 29, no. 7 (July 2010): 820–25. http://dx.doi.org/10.1190/1.3462785.

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Rocha, Ygor dos Santos, Rosana Cardoso Lopes Pereira, and João Graciano Mendonça Filho. "Geochemical assessment of oils from the Mero Field, Santos Basin, Brazil." Organic Geochemistry 130 (April 2019): 1–13. http://dx.doi.org/10.1016/j.orggeochem.2019.01.011.

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Schattner, U., M. Lazar, L. A. P. Souza, U. ten Brink, and M. M. Mahiques. "Pockmark asymmetry and seafloor currents in the Santos Basin offshore Brazil." Geo-Marine Letters 36, no. 6 (September 14, 2016): 457–64. http://dx.doi.org/10.1007/s00367-016-0468-0.

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da Rocha Fragoso, Mauricio, Gabriel Vieira de Carvalho, Felipe Lobo Mendes Soares, Daiane Gracieli Faller, Luiz Paulo de Freitas Assad, Raquel Toste, Lívia Maria Barbosa Sancho, et al. "A 4D-variational ocean data assimilation application for Santos Basin, Brazil." Ocean Dynamics 66, no. 3 (February 9, 2016): 419–34. http://dx.doi.org/10.1007/s10236-016-0931-5.

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NASCIMENTO, ELIELTON, and ULISSES PINHEIRO. "A new species of Desmacella Schmidt, 1870 (Porifera, Demospongiae, Desmacellidae) from the Northeast region of Brazil." Zootaxa 5190, no. 1 (September 27, 2022): 143–46. http://dx.doi.org/10.11646/zootaxa.5190.1.7.

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Desmacella is a Desmacellidae characterized by monactinal megascleres, arranged in plumose bundles; microscleres are sigmas and raphides; the latter may be absent (Hajud & Van Soest 2002). Thirty species are known worldwide, of which 19 occur in the Atlantic Ocean and three on the Brazilian coast: Desmacella annexa Schmidt, 1870; D. microsigmata, Cavalcanti, Santos & Pinheiro, 2015; D. tylovariabilis, Cavalcanti, Santos & Pinheiro, 2015 (de Voogd et al. 2022; Muricy 2022). In this paper, a new species of Desmacella from the Northeast region of Brazil is described. The material examined was compared with the descriptions and/or characterizations of all Desmacella species that occur in the Atlantic Ocean (Cavaltanti et al. 2015: 367–368). The specimen was preserved in ethanol 80% and is deposited in the Porifera Collection of the Natural History Museum of the Universidade Federal da Bahia.

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Barros, MC, EC Fraga, and JLO Birindelli. "Fishes from the Itapecuru River basin, State of Maranhão, northeast Brazil." Brazilian Journal of Biology 71, no. 2 (May 2011): 375–80. http://dx.doi.org/10.1590/s1519-69842011000300006.

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The Itapecuru is a relatively large river in the northeastern Brazilian state of Maranhão. During several expeditions to this basin, we collected 69 fish species belonging to 65 genera, 29 families and 10 orders. Characiformes and Siluriformes were the orders with the largest number of species and Characidae, Loricariidae, Cichlidae, Auchenipteridae and Pimelodidae were the richest families. About 30% of the fish fauna of the Itapecuru basin is endemic or restricted to northeastern Brazil. Just over a fifth (22%) of the species is also known to occur in the Amazon basin and only a few are more widely distributed in South American.

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Arora, B. R., A. Rigoti, Í. Vitorello, A. L. Padilha, N. B. Trivedi, and F. H. Chamalaun. "Electrical Imaging of the Intracratonic Parnaíba Basin, North-Northeast Brazil." Journal of geomagnetism and geoelectricity 49, no. 11 (1997): 1631–48. http://dx.doi.org/10.5636/jgg.49.1631.

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Silva, Iara Samara de Alcântara, Alek André Costa de Sousa, Igor Viegas Alves Fernandes de Souza, Ramsés Capilla, Georgiana Feitosa da Cruz, Antônia Maria das Graças Lopes Citó, and Sidney Gonçalo de Lima. "Characterization of oils from Fazenda Belém – Potiguar Basin, Northeast Brazil." Petroleum Science and Technology 36, no. 3 (December 27, 2017): 173–78. http://dx.doi.org/10.1080/10916466.2017.1403448.

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Oliveira, Lindomário Barros de, Maria da Graça de Vasconcelos Xavier Ferreira, and Flávio Adriano Marques. "Characterization and classification of two soils derived from basic rocks in Pernambuco State Coast, Northeast Brazil." Scientia Agricola 61, no. 6 (December 2004): 615–25. http://dx.doi.org/10.1590/s0103-90162004000600009.

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Geomorphic surfaces that present soils derived from basic rocks under warm and humid climate are unique scenarios for studying tropical soils. This paper aimed to characterize and classify two pedons derived from basalt at the Atlantic Forest Zone, Pernambuco State, Northeastern coast of Brazil. Two representative pedons (P1 and P2) were selected on a hillslope at the Cabo de Santo Agostinho municipality. Field macromorphological descriptions were carried out and soil horizon were sampled for physical, chemical, mineralogical and micromorphological characterization. The soils were classified, according to the Brazilian System of Soil Classification (and US Soil Taxonomy) as: "Latossolo Vermelho-Amarelo distroférrico argissólico" (Typic Hapludox) (P1) and "Nitossolo Vermelho distroférrico típico" (Rhodic Paleudult) (P2). Pedon 1 differs from Pedon 2 in some aspects. For instance, P1 presents more yellowish colors, absence of clay illuviation, more friable consistence and the prismatic structure undergoes transformation to angular and subangular blocks. Pedon 2 presents ferri-argilans and leptocutans which indicate that vertical and lateral illuviation of clay is an active process in their formation. These chemically poor and mineralogically uniform soils are a result of the high temperature and rainfall of the studied area.

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Piovesan, Enelise, Cristianini Bergue, and Gerson Fauth. "New ostracode species from the Upper Cretaceous of the Santos Basin, Brazil." Revista Brasileira de Paleontologia 13, no. 3 (December 29, 2010): 175–80. http://dx.doi.org/10.4072/rbp.2010.3.02.

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Trescastro Bergue, Cristianini, and João Carlos Coimbra. "Late Pleistocene and Holocene bathyal ostracodes from the Santos Basin, southeastern Brazil." Palaeontographica Abteilung A 285, no. 4-6 (October 27, 2008): 101–44. http://dx.doi.org/10.1127/pala/285/2008/101.

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Santos Filho, João Regis dos, Alberto Garcia Figueiredo, Juliane Castro Carneiro, Gilberto Tavares de Macedo Dias, and Allan Soares Ramalho. "Mesophotic bioclastics and bioconstructions at the continental shelf of Santos Basin, Brazil." Sedimentary Geology 442 (December 2022): 106294. http://dx.doi.org/10.1016/j.sedgeo.2022.106294.

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Giles Miller, C., Martha Richter, and Dermeval A. Do Carmo. "Fish and ostracod remains from the Santos Basin (Cretaceous to Recent), Brazil." Geological Journal 37, no. 4 (2002): 297–316. http://dx.doi.org/10.1002/gj.917.

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Evain, M., A. Afilhado, C. Rigoti, A. Loureiro, D. Alves, F. Klingelhoefer, P. Schnurle, et al. "Deep structure of the Santos Basin-São Paulo Plateau System, SE Brazil." Journal of Geophysical Research: Solid Earth 120, no. 8 (August 2015): 5401–31. http://dx.doi.org/10.1002/2014jb011561.

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RADASHEVSKY, VASILY I., ALEXANDRA E. RIZZO, and ANTONIO J. M. PEIXOTO. "First record of Trochochaeta japonica (Annelida: Spionidae) in Brazil with identification key to species of the genus." Zootaxa 4462, no. 4 (August 29, 2018): 566. http://dx.doi.org/10.11646/zootaxa.4462.4.8.

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Polychaetes of the spionid genus Trochochaeta occur mainly in the northern hemisphere, including North and Central America. In South America, they have been reported only from the northeast region of Brazil – Sergipe and Paraíba – despite numerous biological investigations around the continent. In 2006, a dense population (up to 7000 individuals per square meter) of Trochochaeta was discovered in the estuary of Santos, São Paulo, Brazil, hosting the busiest container sea port in Latin America, and in 2008, one Trochochaeta specimen was found in Camamu Bay, Bahia. We identify these worms as Trochochaeta japonica Imajima, 1989 and describe and illustrate their morphology. This is the first record of the species from outside of its type locality in Honshu, Japan. It might have been introduced to the estuary of Santos as larvae in ballast water of ocean-going vessels. We review the systematics of Trochochaeta and provide an identification key to 12 currently recognized species.

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Queiroz, Vinicius, Licia Sales, Elizabeth G. Neves, and Rodrigo Johnsson. "Pericelis cata Marcus and Marcus, 1968 (Platyhelminthes: Polycladida): first record from northeast of Brazil." Check List 9, no. 3 (June 1, 2013): 628. http://dx.doi.org/10.15560/9.3.628.

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The polyclad Pericelis cata has been reported in two distinct localities along the North Atlantic: Curaçao and the Caribbean coast of Colombia. Recently identified from the Southwestern Atlantic, the species was first described from the Cabo Frio region (23°S) (Rio de Janeiro State), a transitional zone between warm and cold water species located southeastern Brazil. The second location is in the northeastern coast in warm waters, in the entrance of the Todos-os-Santos Bay, a geographic area within the Brazilian Biotic Province, an important center of marine biodiversity of the Tropical Atlantic.

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Magalhães, J. R. G., J. T. C. Oliveira, J. A. Barbosa, and M. Lima Filho. "Continental Oceanic Crustal Transition in the Paraíba Basin Platform, Northeast Brazil." Estudos Geológicos 23, no. 2 (December 30, 2013): 125–39. http://dx.doi.org/10.18190/1980-8208/estudosgeologicos.v23n2p125-139.

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ARAI, MITSURU. "Geochemical Reconnaissance of the Mid-Cretaceous anoxic event in the Santos Basin, Brazil." Revista Brasileira de Geociências 18, no. 3 (September 1, 1988): 273–82. http://dx.doi.org/10.25249/0375-7536.1988273282.

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Rodriguez, C. R., C. A. L. Jackson, R. E. Bell, A. Rotevatn, and M. Francis. "Deep-water reservoir distribution on a salt-influenced slope, Santos Basin, offshore Brazil." AAPG Bulletin 105, no. 8 (August 2021): 1679–720. http://dx.doi.org/10.1306/11182017340.

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De Almeida, Rafael Valladares, Alexandre Campane Vidal, Eddy Ruidiaz, Najlah Zeitoum, and Beatriz Ninci. "Facies characterization and porosity-permeability analysis of carbonates in the Santos Basin, Brazil." Rio Oil and Gas Expo and Conference 22, no. 2022 (September 26, 2022): 12–13. http://dx.doi.org/10.48072/2525-7579.rog.2022.012.

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Gherardi, Douglas F. M., Alexandre P. Cabral, Antonio Henrique da Fontoura Klein, Dieter C. E. H. Muehe, Mauricio A. Noernberg, Moyses G. Tessler, and Silvia M. Sartor. "Mapping the Sensitivity to oil spill of the Santos basin coastline, Southeast Brazil." Brazilian Journal of Aquatic Science and Technology 12, no. 2 (December 19, 2008): 11. http://dx.doi.org/10.14210/bjast.v12n2.p11-31.

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Jácomo, Marta H., Gelvam A. Hartmann, Taynah B. Rebelo, Nathália H. Mattos, Alessandro Batezelli, and Emilson P. Leite. "Mineralogical Modeling and Petrophysical Properties of the Barra Velha Formation, Santos Basin, Brazil." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 64, no. 4 (August 1, 2023): 518–43. http://dx.doi.org/10.30632/pjv64n4-2023a3.

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The Santos Basin, offshore Brazil, has the most significant petroleum carbonate reservoir province in South America. The presalt carbonates reservoirs of the Barra Velha Formation (BVF) present a complex mineralogic distribution and heterogeneous physical properties, making it challenging to construct a reliable mineralogical model. Understanding rock mineralogy is important to petroleum prospects and the study of porous media, besides calibrating seismic facies. In this paper, we present a mineralogical inversion procedure to model reservoir and nonreservoir intervals within the BVF in a presalt field applying multicomponent inversion. The uppermost 15 to 28 m of the BVF, known as “Lula Fingers,” present higher values of gamma ray when compared with deeper intervals and are characterized by high modeled dolomite contents. Below the Lula Fingers region, the Upper BVF can be divided into BVF100 (top), which is characterized by low gamma ray values just above the BVF200 (bottom). They are formed mainly by shrub and spherulite-rich in-situ facies with fewer clay and Mg-clays contents, which are often replaced by dolomite and quartz. The bottom part of Upper BVF (BVF200) presents a microporous Mg-clay-rich interval, mainly in the structural flanks region, or a macroporous Mg-clay-poor interval, mainly in high levels. The present model fits well with the stratigraphic interval and allows a better understanding of the mineralogical distribution over the entire BVF100 and BVF200, particularly the lateral mineralogical variability in regions with structural highs and flanks.

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LESSA, GUILHERME C., JOSÉ M. L. DOMINGUEZ, ABÍLIO C. S. P. BITTENCOURT, and ARNO BRICHTA. "The tides and tidal circulation of Todos os Santos Bay, Northeast Brazil: a general characterization." Anais da Academia Brasileira de Ciências 73, no. 2 (June 2001): 245–61. http://dx.doi.org/10.1590/s0001-37652001000200009.

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The Todos os Santos Bay, located on northeastern Brazil, is the second largest coastal bay in the country, after São Marcos Bay. The three main drainage basins convey an average of 120 m³/s of freshwater towards the bay, the majority of it, however, held by a dam in Paraguaçu River since 1985. The original average freshwater inflow was two orders of magnitude smaller than the estimated tidal discharge through the main bay entrance, and the oceanographic characteristics of the bay, as indicated by bay salinity measurements, are clearly marine. The tides are semi-diurnal, and are amplified up the bay by a factor of 1.5. Shallow water constituents become more important as the tide propagates along Paraguaçu Channel and Paraguaçu River, where they generate time asymmetries that change between spring and neap tides. Currents in the bay are mainly bi-directional, and are stronger during the ebbing tide in most of the bay. Offshore, relatively strong tidal currents appear to be felt in a radius of about 10 km, where they are superimposed on winds driven currents orientated to the southwest.

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Sales, João Marcos de Jesus, Antenor de Oliveira Aguiar Netto, and Clayton Moura de Carvalho. "Hydrological modeling of hydrographic basin in the northeast semiarid region of Brazil." Research, Society and Development 11, no. 3 (March 4, 2022): e48711326735. http://dx.doi.org/10.33448/rsd-v11i3.26735.

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The use of hydrological models allows to understand, evaluate and anticipate events of natural or man-made origin in a simpler and more economical way for the quantity and quality of resources in a hydrographic basin. The present work aims to perform a hydrological modeling in the hydrographic basin in the semiarid, using the SWAT model, to verify the influence of the use and exploitation of water production on the land. For this, the SWAT hydrological model (Soil Water Assessment Tool) was used. A study area located in the Jacaré Curitiba Basin, in Poço Redondo-SE, a semi-arid region of the state, inserted in the Caatinga biome and in the lower São Francisco. The adopted methodology was used for bibliographic survey, field work, hydrological monitoring, chemical and physical medicine of soil and soil, survey of land use and exploration, calibration and validation of hydrological model. The SWAT model successfully simulated or hydrographed the flow for the period from Nov/2015 to Jul/2018, duly calibrated and validated. As simulations of different land use scenarios, the greatest production of water in agricultural areas stands out, which can cause greater generation of sediments. The calibrated and validated SWAT model means a possibility for future studies in non-semiarid watersheds and then contributes to studies on water and soil management.

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Silva, Márcio Joaquim da, Brisa Guimarães Costa, Telton Pedro Anselmo Ramos, Paulo Auricchio, and Sergio Maia Queiroz Lima. "Ichthyofauna of the Gurgueia River, Parnaíba River basin, northeastern Brazil." Check List 11, no. 5 (October 14, 2015): 1765. http://dx.doi.org/10.15560/11.5.1765.

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The Gurgueia River in southern Piauí state, Brazil, is the largest affluent on the right margin of the Parnaíba River basin. This study aimed to inventory the Gurgueia River ichthyofauna, and contribute to the knowledge of fish diversity in Northeastern Brazil. We sampled 71 locations throughout the Gurgueia sub-basin between 2006 and 2014, which resulted in 90 fish species representing 67 genera, 26 families and six orders, including two non-native species. Six species are newly recorded for the Parnaíba basin (Hasemania nana, Hemigrammus brevis, H. guyanensis, H. ora, Corydoras sp. and Cetopsorhamdia sp.), increasing its freshwater ichthyofauna to 152 species. The Gurgueia River contains 59.2% of the ichthyofauna known for the Parnaíba basin, and can be used as a reference point for the establishment of priority areas for the conservation of the freshwater fish fauna of the Brazilian Northeast.

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MENDES, SAMUEL LUCAS DA SILVA DELGADO, PAULO CESAR DE PAIVA, and ALEXANDRA E. RIZZO. "First record of Oligobregma Kudenov & Blake, 1975 (Annelida: Polychaeta: Scalibregmatidae Malmgren, 1867) from Brazil with the description of three new species." Zootaxa 5424, no. 1 (March 12, 2024): 80–98. http://dx.doi.org/10.11646/zootaxa.5424.1.4.

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Oligobregma represents the most speciose genus of Scalibregmatidae with 17 valid species. Most of them occur at great depths and are found living on soft bottoms. Here, we present the descriptions of O. nonatoi sp. nov., O. cruzae sp. nov., and O. bakkeni sp. nov., sampled from the Brazilian continental shelf and slope, and a key to all species of Oligobregma. O. nonatoi sp. nov. differs from its congeners by the presence of a triangular prostomium with short rounded horns, acicular spines on notopodia of chaetigers 1–4 and on neuropodia of chaetigers 1–3. Oligobregma cruzae sp. nov. can be distinguished by the presence of a quadrangular prostomium with two short, rounded horns, acicular spines on chaetigers 1–4, and lyrate chaetae from chaetiger 5. Finally, O. bakkeni sp. nov. is unique among its congeners by the presence of acicular spines with rounded tips. This is the first record of this genus along the Brazilian coast and the specimens were collected on Espírito Santo, Campos and Santos sedimentary basins, both located in Brazilian southeast region. The sampling campaigns were carried out in scientific expeditions related to two research projects: “Santos Project – Santos Basin Environmental Characterization” and “Ambes Project – Espírito Santo Basin Assessment Project”, both coordinated by CENPES/PETROBRAS.

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Ramos, Telton Pedro Anselmo, Yuri Gomes Ponce de Carvalho-Rocha, Leonardo Oliveira-Silva, Sílvia Yasmin Lustosa-Costa, and Paula Honório Pires Ferreira. "Continental fishes from the Tambaba Environmentally Protected Area, Paraíba State, Brazil." Papéis Avulsos de Zoologia 59 (October 17, 2019): e20195950. http://dx.doi.org/10.11606/1807-0205/2019.59.50.

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Tambaba environmentally protected area is situated on the south coast of Paraíba State, within the Atlantic forest biome of the northeastern region in Brazil. The Tambaba environmentally protected area consists of a series of independent drainages: Graú, Mucatú, and Bucatú river micro-basins, and Caboclo River sub-basin that belongs to Gurugi River micro-basin. Ichthyological samples were collected in five scientific expeditions between months of June and July in 2015. Twenty-nine sites from different habitats (e.g., spanning tributaries, streams, rivers, and estuaries) were accessed for sampling. A total of 44 species distributed within 38 genera, 25 families, and 17 orders were assigned to the Tambaba hydrographic region. Freshwater species comprised 36% (n = 16) and marine-estuarine species 64% (n = 28) of the total collected specimens. Two invasive species occur in the freshwater sites: Cichla monoculus and Poecilia reticulata. Cheirodon jaguaribensis, Cichlasoma orientale, and Crenicichla brasiliensis are endemic to the Brazilian Northeast region with the first species restricted to the Northeast Caatinga and Coastal drainages hydrographic ecoregion.

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Hufaizal, Muhammad Zulhakim, Nor Syazwani Zainal Abidin, and Mohd Syafiq Firdauz. "Petroleum system modelling of Pelotas basin, offshore Brazil using 2D basin modelling approach." IOP Conference Series: Earth and Environmental Science 1003, no. 1 (April 1, 2022): 012006. http://dx.doi.org/10.1088/1755-1315/1003/1/012006.

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Abstract The ongoing exploration activities at the Pelotas basin of Brazil uncover some missing gaps in the existing wells for hydrocarbon accumulation prediction. Therefore, there is a need to further investigate the petroleum system of the basin, especially the organic facies, variations and distributions of the effectiveness of potential source rock. The adjacent basin, Santos basin is currently producing oil and gas fields will be used as the analogs to the Pelotas Basin. The aims of this research are to justify the presence of geological elements and processes of the petroleum system of the Pelotas Basin and to evaluate the potential of hydrocarbon prospectivity for exploration and exploitation of the basin. Two – dimensional basin modelling using TemisFlow will be used in this study. Hydrocarbon generation from the Turonian and Ypresian to Bartonian source rock started during Late Eocene. Visible Hydrocarbon migration can be seen from the Hydrocarbon saturation model. Hydrocarbon migration for Turonian source rock occurred during Early Miocene while for Ypresian to Bartonian, hydrocarbon migrate during Middle Miocene. Peak hydrocarbon expulsion reached during Middle Miocene for Turonian source rock and Ypresian to Bartonian source rock. Based on modelling result, hydrocarbon accumulation can be seen in Upper slope Early Miocene Sandstone, Early Miocene turbiditic sandstone and Early Oligocene turbiditic sandstone. Hydrocarbon composition in Early Miocene turbiditic sandstone and Upper Oligocene sandstone is mainly hydrocarbon liquid while for Early Miocene sandstone, the hydrocarbon composition is mix of hydrocarbon liquid and gas. Based on the prediction of source facies distribution, thermal maturity assessment, and migration and trapping mechanism, the oil and gas pool can be proposed for the future exploration and exploitation in the Pelotas Basin, offshore Brazil.

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YiXuan, ZHU, ZHANG ZhongMin, and ZHANG DeMin. "Sedimentary environment and genesis of the Early Cretaceous microbial carbonates in Santos Basin, Brazil." Acta Petrologica Sinica 38, no. 9 (2022): 2619–33. http://dx.doi.org/10.18654/1000.0569/2022.09.07.

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YiXuan, ZHU, ZHANG ZhongMin, and ZHANG DeMin. "Sedimentary environment and genesis of the Early Cretaceous microbial carbonates in Santos Basin, Brazil." Acta Petrologica Sinica 38, no. 9 (2022): 2619–33. http://dx.doi.org/10.18654/1000-0569/2022.09.07.

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Sulato, Everton Tiago, Karen Luko-Sulato, Jorge Henrique Pedrobom, Lucia Maria de Souza de Oliveira, Guilherme dos Santos Lima, José Silvio Govone, André S. Barreto, Marcus Antônio Gonçalves de Araújo Júnior, and Amauri Antonio Menegário. "Metals and metalloids in green turtle hepatic tissue (Chelonia mydas) from Santos Basin, Brazil." Environmental Research 203 (January 2022): 111835. http://dx.doi.org/10.1016/j.envres.2021.111835.

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Rodriguez, C. R., C. A.-L. Jackson, A. Rotevatn, R. E. Bell, and M. Francis. "Dual tectonic-climatic controls on salt giant deposition in the Santos Basin, offshore Brazil." Geosphere 14, no. 1 (January 12, 2018): 215–42. http://dx.doi.org/10.1130/ges01434.1.

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Neto, Arthur Ayres, Joana de Noronha Teixeira Mendes, Juliana Maria Gonçalves de Souza, Miguel Redusino, and Rodrigo Leandro Bastos Pontes. "Geotechnical Influence on the Acoustic Properties of Marine Sediments of the Santos Basin, Brazil." Marine Georesources & Geotechnology 31, no. 2 (April 2013): 125–36. http://dx.doi.org/10.1080/1064119x.2012.669815.

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Pichel, Leonardo M., Christopher A. ‐L Jackson, Frank Peel, and Tim P. Dooley. "Base‐salt relief controls salt‐tectonic structural style, São Paulo Plateau, Santos Basin, Brazil." Basin Research 32, no. 3 (July 7, 2019): 453–84. http://dx.doi.org/10.1111/bre.12375.

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Ariza Ferreira, Danilo Jotta, Wagner Moreira Lupinacci, Igor de Andrade Neves, João Paulo Rodrigues Zambrini, André Luiz Ferrari, Luiz Antonio Pierantoni Gamboa, and Maria Olho Azul. "Unsupervised seismic facies classification applied to a presalt carbonate reservoir, Santos Basin, offshore Brazil." AAPG Bulletin 103, no. 4 (April 2019): 997–1012. http://dx.doi.org/10.1306/10261818055.

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