scholarly journals UNRAVELING MAGMATIC ACTIVITY IN SEDIMENTARY BASINS: SILLS AND RELATED BRITTLE STRUCTURES AFFECTING CAMPOS BASIN PETROLEUM SYSTEM (SE BRAZIL)

2019 ◽  
Vol 4 (4) ◽  
pp. 471-479
Author(s):  
Gabriela De Oliveira Avellar ◽  
Egberto Pereira
Keyword(s):  
Hydrothermal Vents ◽  
Oil And Gas ◽  
Sedimentary Basins ◽  
Petroleum System ◽  
Hydrocarbon Exploration ◽  
Petroleum Systems ◽  
Positive Effects ◽  
Campos Basin ◽  
Igneous Intrusions ◽  
Se Brazil

Historically, volcanic basins have been avoided by oil and gas companies for hydrocarbon exploration, due to high rates of unsuccessful cases, mainly when magmatic suites were unexpected. Furthermore, igneous rocks have always been considered harmful to petroleum systems. However, in the past two decades, researches regarding these systems in volcanic basins have shown a number of positive effects, as increasing permeability of tight rocks, and generation of traps. This work aims to investigate the occurrence and impacts of igneous intrusions on sedimentary basins regarding the reservoir and trap elements. For that, we use eight 2D seismic lines and five wells within the Papa-Terra field, southern Campos Basin, Brazil. Applying seismic stratigraphy, nineteen sills were identified, most of them have saucer-shaped geometries, but they are also planar. We have identified some possible joint connections in the NW sill complex, as well as a possible feeder dyke. Five sills are located right below two domal structures in the overburden, which were interpreted as forced-folds. There are fractures interpreted in the sills’ boundaries and in folded sediments. Some of the fractures in the sills boundaries were interpreted as hydrothermal vents that were active until Upper Cretaceous. The contribution of this study is a documentation of an offshore volcanic basin related to a proven petroleum system in the south Atlantic, which has been neglected by Brazilian researchers over the years. ATIVIDADE MAGMÁTICA EM BACIAS SEDIMENTARES: SOLEIRAS E FALHAS ASSOCIADAS QUE AFETAM O SISTEMA PETROLÍFERO DA BACIA DE CAMPOS (SE BRASIL) ResumoHistoricamente, as empresas de petróleo e gás evitam efectuar propecção de hidrocarbonetos em bacias afetadas por vulcanismo, devido a elevadas taxas de insucesso, principalmente quando os pacotes magmáticos são inesperados. Além disso, as intrusões de rochas ígneas sempre foram consideradas prejudiciais aos sistemas petrolíferos. No entanto, nas últimas duas décadas, pesquisas relacionadas a esses sistemas em bacias vulcânicas mostraram vários efeitos positivos, pois podem contribuir para o aumento da permeabilidade de rochas compactas e geração de armadilhas. Este trabalho tem como objetivo investigar a ocorrência e os impactos de intrusões ígneas numa bacia sedimentar. Para isso, foram analisadas oito linhas sísmicas 2D e cinco poços no campo Papa-Terra, no sul da Bacia de Campos, Brasil. Aplicando a estratigrafia sísmica, foram identificadas dezanove soleiras, a maioria delas com geometrias em forma de pires, mas também planas. Foram identificadas algumas possíveis conexões no complexo da soleira NW, bem como um possível dique de alimentação. Cinco soleiras localizadas logo abaixo de duas estruturas em forma de doma correspondem possivelmente a dobras forçadas. Existem fraturas nos limites das soleiras e em sedimentos dobrados. Algumas das fraturas nos limites das soleiras poderão ter funcionado como ductos circulação hidrotermal que terão estado ativos até o Cretáceo Superior. Este estudo contribuiu para um melhor conhecimento de uma bacia vulcânica offshore relacionada a um sistema petrolífero comprovado no Atlântico Sul, a qual tem sido negligenciada por pesquisadores brasileiros ao longo dos anos. Palavras-chave: Vulcânica. Bacia Sedimentar. Soleira em forma de pires. Estratigrafia sísmica. Bacia Offshore. Margem Continental. Cretáceo Superior. 

Research for the Upstream Petroleum Sector: The Crown Research Institute Concept

1995 ◽  
Vol 13 (2-3) ◽  
pp. 245-252
Author(s):  
J M Beggs
Keyword(s):  
New Zealand ◽  
Oil And Gas ◽  
Sedimentary Basins ◽  
Source Rocks ◽  
Publicly Funded ◽  
Petroleum Systems ◽  
Oil And Gas Resources ◽  
Petroleum Sector ◽  
Geological Sciences ◽  
Research Institute

New Zealand's scientific institutions have been restructured so as to be more responsive to the needs of the economy. Exploration for and development of oil and gas resources depend heavily on the geological sciences. In New Zealand, these activities are favoured by a comprehensive, open-file database of the results of previous work, and by a historically publicly funded, in-depth knowledge base of the extensive sedimentary basins. This expertise is now only partially funded by government research contracts, and increasingly undertakes contract work in a range of scientific services to the upstream petroleum sector, both in New Zealand and overseas. By aligning government-funded research programmes with the industry's knowledge needs, there is maximum advantage in improving the understanding of the occurrence of oil and gas resources. A Crown Research Institute can serve as an interface between advances in fundamental geological sciences, and the practical needs of the industry. Current publicly funded programmes of the Institute of Geological and Nuclear Sciences include a series of regional basin studies, nearing completion; and multi-disciplinary team studies related to the various elements of the petroleum systems of New Zealand: source rocks and their maturation, migration and entrapment as a function of basin structure and tectonics, and the distribution and configuration of reservoir systems.

scholarly journals Pre-salt rift morphology controls salt tectonics in the Campos Basin, offshore SE Brazil

2021 ◽  
Author(s):  
Francyne B. Amarante ◽  
Christopher A-L. Jackson ◽  
Leonardo M. Pichel ◽  
Claiton M. S. Scherer ◽  
Juliano Kuchle
Keyword(s):  
Hydrocarbon Exploration ◽  
Passive Margin ◽  
Salt Tectonics ◽  
Borehole Data ◽  
Temporal And Spatial Distribution ◽  
South Central ◽  
Campos Basin ◽  
Se Brazil ◽  
Gravity Driven ◽  
Base Salt

<p>Salt-bearing passive margin basins offshore SE Brazil have been and remain attractive for hydrocarbon exploration and production. In the Campos Basin, major reservoir types include post-salt turbidites, which are located in structural traps related to thin-skinned faulting above salt anticlines and rollers. Classic models of gravity-driven salt tectonics commonly depict kinematically linked zones of deformation, characterised by updip extension and downdip contraction, separated by a weakly deformed zone associated with downdip translation above a relatively smooth base-salt surface. We use 2D and 3D seismic reflection and borehole data from the south-central Campos Basin to show that this does not adequately capture the styles of salt-detached gravity-driven deformation above relict, rift-related relief. The base-salt surface is composed of elongated, broadly seaward-dipping ramps with structural relief reaching c. 2 km. These ramps define the boundary between the External High and the External Low, basement structures related to the rift tectonics. Local deformation associated with the base-salt ramps can overprint and/or influence regional, margin-scale patterns of deformation producing kinematically-variable and multiphase salt deformation. We define three domains of thin-skinned deformation: an updip extensional domain, subdivided into subdomains E1 and E2, an intermediate multiphase domain and a downdip contractional domain. The multiphase domain is composed of three types of salt structures with a hybrid extensional-contractional origin and evolution. These are: (i) contractional anticlines that were subjected to later extension and normal faulting; (ii) diapirs with passive and active growth later subjected to regional extension, developing landward-dipping normal faults on the landward flank; and, lastly, (iii) an extensional diapir that was subsequently squeezed. We argue that this multiphase style of deformation occurs as a consequence of base-salt geometry and relief creating local variations of salt flow that localize extension at the top and along the ramps, and contraction at the base. Translation and extension of salt and its overburden across major base-salt ramps resulted in three ramp syncline basins northeast of the study area, partially bounded by salt-detached listric faults. The temporal and spatial distribution and evolution of these and other key salt and overburden structures, and their relationship to base-salt relief, suggest 30 to 60 km of horizontal gravity-driven translation of salt and overburden.</p>

Geometric characterization of igneous intrusions: 3-D seismic insights from the Campos Basin, SE Brazil

2019 ◽  
Vol 102 ◽  
pp. 725-739 ◽  
Author(s):  
Ulisses Miguel da Costa Correia ◽  
Bruno César Zanardo Honório ◽  
Michelle Chaves Kuroda ◽  
Leandro Hartleben Melani ◽  
Alexandre Campane Vidal
Keyword(s):  
Geometric Characterization ◽  
Campos Basin ◽  
Igneous Intrusions ◽  
Se Brazil

scholarly journals Analysis of the Petroleum System of Dima Oil Field by Using PetroMoD 1D

2021 ◽  
pp. 526-531
Author(s):  
Haider A. F. Al-Tarim
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Petroleum System ◽  
Oil Field ◽  
Reservoir Rock ◽  
Geological Time ◽  
Reservoir Rocks ◽  
Petroleum Systems ◽  
Geological Age ◽  
Stratigraphic Succession

The study of petroleum systems by using the PetroMoD 1D software is one of the most prominent ways to reduce risks in the exploration of oil and gas by ensuring the existence of hydrocarbons before drilling.      The petroleum system model was designed for Dima-1 well by inserting several parameters into the software, which included the stratigraphic succession of the formations penetrating the well, the depths of the upper parts of these formations, and the thickness of each formation. In addition, other related parameters were investigated, such as lithology, geological age, periods of sedimentation, periods of erosion or non-deposition, nature of units (source or reservoir rocks), total organic carbon (TOC), hydrogen index (HI) ratio of source rock units, temperature of both surface and formations as they are available, and well-bottom temperature.      Through analyzing the models by the evaluation of the source rock units, the petrophysical properties of reservoir rock units, and thermal gradation with the depth during the geological time, it became possible to clarify the elements and processes of the petroleum system of the field of Dima. It could be stated that Nahr Umr, Zubair, and Sulaiy formations represent the petroleum system elements of Dima-1 well.

scholarly journals Basin inversion and structural architecture as constraints on fluid flow and Pb-Zn mineralisation in the Paleo-Mesoproterozoic sedimentary sequences of northern Australia

2020 ◽  
Author(s):  
George M. Gibson ◽  
Sally Edwards
Keyword(s):  
Oil And Gas ◽  
Sedimentary Basins ◽  
Normal Faults ◽  
Northern Australia ◽  
Tectonic Event ◽  
Basin Inversion ◽  
Petroleum Systems ◽  
Sedimentary Sequences ◽  
Structural Architecture ◽  
Migration Pathways

Abstract. As host to several world-class sediment-hosted Pb-Zn deposits and unknown quantities of conventional and unconventional gas, the variably inverted 1730–1640 Ma Calvert and 1640–1580 Ma Isa superbasins of northern Australia have been the subject of numerous seismic reflection studies with a view to better understanding basin architecture and fluid migration pathways. Strikingly similar structural architecture has been reported from much younger inverted sedimentary basins considered prospective for oil and gas elsewhere in the world. Such similarities suggest that the mineral and petroleum systems in Paleo-Mesoproterozoic northern Australia may have spatially and temporally overlapped consistent with the observation that basinal sequences hosting Pb-Zn mineralisation in northern Australia are bituminous or abnormally enriched in hydrocarbons. This points to the possibility of a common tectonic driver and shared fluid pathways. Sediment-hosted Pb-Zn mineralisation coeval with basin inversion first occurred during the 1650–1640 Ma Riversleigh Tectonic Event towards the close of the Calvert Superbasin with further pulses accompanying the 1620–1580 Ma Isa Orogeny which brought about closure of the Isa Superbasin. Mineralisation in all cases is hosted by the syn-inversion fraction of basin fill, contrary to most existing interpretations of Pb-Zn ore genesis where the ore-forming fluids are introduced during the rifting or syn-extensional phase of basin development. Syn-extensional normal faults of Calvert and Isa age are mutually orthogonal, giving rise to a complex compartmentalisation of sub-basins with predominantly NNW and ENE strikes. Basin inversion subsequent to 1640 Ma occurred overall in a transpressive tectonic regime linked to continent-continent collision accompanied by orogen-parallel extensional collapse and right-stepping strike-slip faulting.

PETROLEUM SYSTEMS OF THE PETREL SUB-BASIN-AN INTEGRATED APPROACH TO BASIN ANALYSIS AND IDENTIFICATION OF HYDROCARBON EXPLORATION OPPORTUNITIES

1996 ◽  
Vol 36 (1) ◽  
pp. 248 ◽  
Author(s):  
B.A. McConachie ◽  
M.T. Bradshaw ◽  
J. Bradshaw
Keyword(s):  
Source Rock ◽  
Outer Part ◽  
Integrated Approach ◽  
Petroleum System ◽  
Hydrocarbon Exploration ◽  
Petroleum Potential ◽  
Petroleum Systems ◽  
Marine Source Rock ◽  
Marine Source ◽  
Timor Sea

A petroleum system evaluation of the Petrel Sub-basin in the Bonaparte Gulf, northwest Australia, suggests that the wells drilled in the area have not fully evaluated the petroleum potential. Some of the lowest risk plays in the basin have not been tested adequately or have not been assessed in probable economic fairways.Several important discoveries have highlighted the existence of at least three petroleum systems in the Petrel Sub-basin; Larapintine, Transitional and Gondwanan. Best known are the Gondwanan gas discoveries at Petrel, Tern and most recently Fishburn, where hydrocarbons are reservoired in Late Permian sandstones and are probably sourced from Permian deltaic sequences. Kurt her inshore, oil has been recovered from Carboniferous and Early Permian reservoirs at Turtle and Barnett. The source of the oil is considered to be Carboniferous anoxic marine shales of a distinct petroleum system transitional between the Gondwanan and Larapintine systems (Milligans Formation source rock and Late Carboniferous to Permian reservoirs). Onshore, there is a gas discovery at Gariinala-1 and significant oil shows in Ningbing-1, in Late Devonian Larapintine system rocks. Geochemical analysis of the oil shows it to be sourced from a carbonate marine source rock, different from the clastic derived oils obtained from Turtle and Barnett.Recent discoveries in the Timor Sea have provoked a re-assessment of the very similar, largely untested, Mesozoic, Westralian petroleum system in the outer part of the Petrel Sub-basin. The prospective Mesozoic play fairway occurs in the northern part of the Petrel Sub-basin, extending into Area B of the Zone of Cooperation.

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