Análise das respostas de atributos sísmicos dos carbonatos barremiano, albiano e neógeno no campo de Bonito, bacia de Campos - RJ

The Bonito oil field, located on southwest of Campos Basin-RJ, has been explored since 1982. The main reservoir is composed by calcarenites of Quissamã Formation (Macaé Group) from Albian, but two other carbonate levels are present on the field, firsts is Coqueiros Formation (Aptian) and the second Siri Member (Oligo-Miocene). In this context and considering that carbonates reservoirs are a challenge for exploratory geoscientists, since the difficulty on recognize the effective reservoir distribution. This work aim to characterize the geophysical/geological facies based on seismic attributes responses, related to reservoir geometrical distribution, for the tree carbonates intervals on Bonito oil Field. A tree dimensional interpretation of the levels has been developed, based on well cross correlation and a 3D seismic interpretation, resulting on the stratigraphic and structural framework of the field, which showed a NE-SW fault trend controlling the Aptian carbonates reservoirs, and halocnetics structures showing a structural trap on Albian carbonates reservoirs. The definition of the structural/ stratigraphic framework possibly the seismic attributes calculations over the reservoir intervals. To select the best response in comparison with the reservoir distribution, obtained by seismic interpretation, the attributes response were compared with isopachs maps of each carbonate stratigraphic level. The attributes Maximum Amplitude, Maximum Magnitude and Rms Amplitude showed a good answer to reservoir distribution. The Rms Amplitude also showed a good correlation with physical rock properties, like RHOB bulk density, for the Albian and Aptian carbonates, as consequence it is possible make a characterization of reservoir distribution based on seismic attribute answer

Análise paleopalinológica do Albiano (Cretáceo inferior) da Bacia de Campos, com ênfase no estudo de dinoflagelados

Pós-graduação em Geociências e Meio Ambiente - IGCE

Análise estratigráfica dos reservatórios turbidíticos do Campo de Namorado

Pós-graduação em Geologia Regional - IGCE

Modelo petrofísico 3D do Arenito Namorado no Campo de Namorado - Bacia de Campos, RJ

The Namorado Oil Field represents the beginning of the oil exploration in Brazil, in the 70s, and it is still a subject of researches because the importance of this turbidite sandstone in the brazilian oil production. The Namorado’s production level was denominated “Namorado sandstone”, it is composed by turbidite sandstone deposited during the Albian-Cenomanian. In order to define the structural geometry of the main reservoir, geological and geophysical tools like RECON and Geographix (Prizm – Seisvision) softwares were used, and its application was focused on geological facies analysis, for that propose well logs, seismic interpretation and petrophysical calculations were applied. Along this work 15 vertical wells were used and the facies reservoirs were mapped of along the oil field; it is important to mentioned that the all the facies were calibrated by the correlation rock vs log profile, and 12 reservoir-levels (NA-1, NA-2, NA-3, NA-4, NA-5, NA-6, NA-7, NA-8, NA-9, NA-10, NA-11 e NA-12) were recognized and interpreted. Stratigraphic sections (NE-SW and NW-SE) were also built based on stratigraphic well correlation of each interpreted level, and seismic interpretation (pseudo-3D seismic data) on the southeastern portion of the oil field. As results it was interpreted on two- and three-dimensional maps that the deposition reservoir’s levels are hight controlled by normal faults systems. This research also shows attribute maps interpretation and its relationship with the selection of the reservoir attribute represented on it. Finally the data integration of stratigraphic, geophysical and petrophysical calculations lets us the possibility of obtain a detail geological/petrophysical 3D model of the main reservoir levels of “Namorado sandstone” inside the oil/gás field

Coquinas eoaptianas do sudoeste da Bacia de Campos: fácies deposicionais, eventos diagenéticos e fatores controladores da qualdade do reservatório

Pós-graduação em Geologia Regional - IGCE

Calcários albianos de campo petrolífero na Bacia de Campos: fácies, diagênese e modelo deposicional

Pós-graduação em Geologia Regional - IGCE

Modelo deposicional de carbonatos albianos da Formação Quissamã: análise faciológica, diagenética e estratigráfica de um campo de óleo na porção meridional da Bacia de Campos

Pós-graduação em Geologia Regional - IGCE

Caracterização dos reservatórios do grupo Macaé no Campo de Garoupa - Bacia de Campos - por meio de interpretação sísmica e perfis de poço

The study area is the Garoupa Field, located 75 km from the coast of Rio de Janeiro in bathymetric elevation of 125 m and it is the first important offshore discovery of the Campos Basin with hydrocarbon production in the Albian carbonates. The high significance of carbonate rock reservoirs for the global oil industry and its degree of complexity, combined with the fact that the Garoupa Field is a mature field, make this research project interesting to develop a re-exploratory vision of the study area. The objective of this paper is to characterize the physical properties of the Macae Group reservoirs in the Garoupa Field through well correlation techniques, petrophysical analysis and seismic interpretation (3D), in order to evaluate qualitatively and quantitatively the response of geophysical data to the presence of carbonate rock reservoirs. From the analysis of well profiles (gamma ray, resistivity, density and sonic) it was possible to identify six reservoir levels in the Quissamã Formation. As a result, the reservoirs have good correlation between the wells in the Garoupa Field and show lateral facies variation. In the seismic interpretation, structural contour maps were generated in time (ms) from the top of the Macae Group and two horizons that correspond to the reservoir levels. These maps show that the oil producing area of this field is a structural high located at the west of the interpreted seismic cube, and it was classified as a rollover limited by lateral faults forming a horst. The seismic attribute maps show a good response to the reservoirs of the Garoupa Field because they are associated with amplitude anomalies, verified by the correlation between the physical properties of the reservoir rock and seismic data through cross plots, with emphasis in a linear correlation between the resistivity profile and the values of Maximum Absolute Amplitude and RMS Amplitude attributes

Geologia das coquinas-reservatório do Campo de Pampo, Bacia de Campos

The Pampo oil field is located in the southwest of the trend Badejo-Linguado-Pampo in an accumulation of single - mixed trap: structural-stratigraphic-diagenetic. Its main reservoir is a coquina shell of bivalves (the lowest) in the Lagoa Feia Group. During the rift phase, the Badejo-Linguado-Pampo trend´s accumulations evolve according to three tectono-stratigraphic cycles. The first two cycles are formed by siliciclastic rocks with fining up sequences and carbonates coquinas bivalves. The youngest cycle related to Alagoas age is a transgressive event represented by the presence of an evaporitic layer in the top (anhydrite). This study aims to characterize the reservoir Coqueiros Formation based on the analysis of 2D and 3D seismic data and well data-correlation profiles. The structural map of the top of coquinas reservoir indicates a curvilinear contour of Pampo Fault as described on the literature. This fault was interpreted on seismic data as a basement´s high, and it doesn´t show influence on the horizons above the top of Lagoa Feia Group. The Pampo fault is responsible for the division of the field into two blocks: the hanginwall in the West and the footwall to the East. This division is well marked on the reservoir´s isopach map where a greater thickness of reservoir is observed on the lower block. In the Southeast extreme of Badejo-Linguado-Pampo trend, on Pampo Field, the thick siliciclastic´s interval ends laterally to the basement, and its lower´s cycle forms a wedge, as consequence the carbonate-coquina overlaps directly the basement. Another implication of the higher and distal position of Pampo field is that the third cycle is absent, truncated by the unconformity pre-Macaé Group (Albian)

Análises tectono-estratigráfica e faciológico-diagenética da coquina-reservatório Lagoa Feia, Campo de Linguado, Bacia de Campos

A tectono-stratigraphic study of bivalve coquina-reservoir of Linguado Field allowed to identify two trends of permoporosity development. The delineation of these depositional-diagenetic traps were made through structural and stratigrafic cross-sections and maps. It resulted in the identification of shelf-ramp systems (tilted to SSE), it tickens from 60 to 70 meters and ends against an antithetic fault. The main coquina is bounded by fine siliciclastic units, white clay (low Gamma Ray values) or shale (high Gamma Ray values) lithologies, influencing diagenesis of basal or top coquina limestones (cimented, non-porous). Also in the middle of coquina-reservoir the “clayer” material is also associated with cemented carbonates, with also compartimentalize the reservoir into two subzones. The coquina porosity of the subzones is taken from density-neutron logs, while induction log estimates permeabilities and fluid saturations. It’s noticed the porosity development into pairs, good one followed by a regular/poor one and vice versa. These pairs form verticals succession, pair cycles where porosity improves or decreases upwards. These two scales of pore heterogeneity impose strong layering to the reservoir, and influences fluid saturations, oil-water contacts and porosity cut-offs. In a cross-section with density and induction logs, it can be observed the porosity variation along the shelf-ramp coquina (between 3LI_0004_RJS e 3RJS_0157C_RJ), the porosity is better developed in a downdip direction in the case of the two shelf wells, and also be the three ramp wells. The southern west downdip, 3RJS_0157C_RJ well, has best porosity pairs-cycles; however, its lowest structural conditions favour water saturation. Therefore it is fundamental for reservoir fluid evaluation a cross-plot analysis of RHOB-NPHI and Induction logs

Caracterização da distribuição física dos dolomitos do membro Búzios no Campo de Badejo - Bacia de Campos

In the region of Badejo oil Ffeld (Campos Basin) lies an Lower Albian dolomitic layer that shows reservoir rock and seal conditions, among others and, it is occasionally karstified. This work applies geostatistical techniques of ordinary and indicatior kriging, in an attempt to determine a method that assists the analysis of different scenarios offered for petroleum drilling from a quantitative point of view this fact is justified, because there are different visions and strategies that would be adopted under different dolomite conditions (stable - low porosity and high density; reservoir - high porosity and medium density; instable - high porosity and low dentisty). The main objective is a methodological introduction that has not been tested in dolomites before aiming to characterize the distribution of the three conditions described above by ordinary and indicatior kriging, which was based on the obtained data from the dolomite layer identification through well logs interpretation and correlation, followed by seismic interpretation. In addition, it was generated structural contour maps, based on 2D and 3D seismic data interpretation, and then, seismic attributes maps were calculated, in order to transform them into pseudo-density maps, i.e., maps that correlate the density values with the attribute values. As primary results, structural contour maps and seismic attributes were obtained and ordinary and indicatior kriging maps were done, on which it is possible to interpret the distribution of the main reservoir and risk probability for drilling of exploration wells obtaining trends N35E and N10W direction for areas of stability or reservoir levels, while the central part of the map presents a higher risk for loss of drilling fluid. The cut-off values levels were based on the values of first and third quartiles of cumulative histogram (instable and stable zones, respectively), as well as the reservoir level was set as the interval...

Análise da sedimentação cretácea no Triângulo Mineiro e sua correlação com áreas adjacentes

Fundação de Amparo à Pesquisa do Estado de São Paulo (FAPESP)

Modelo tectono-estrutural dos campos de petróleo Namorado, Cherne e Albacora

The main goal in this research is a tectono-estructural characterization of the Cherne, Albacora and Namorado Fields, located at Campos Basin, in order to investigate the relationship between the geologic evolution and the rock´s physical properties of the reservoir, and how they affect the hydrocarbon accumulation in those fields. Well correlations show that the inferior turbidites have a regional lateral continuity. Basic petrophysics analysis, calculated here, shows that the three fields present porosity values that range from 15 to 20%, shale volume range from 26 to 30% and formation water saturation range from 23 to 45%, based on formation water resistivity dada from Albacora Field. Petrophysics maps feature a trend in Albacora Field that increase the porosity values to SE, and in Cherne and Namorado Field the trend increase towards N. Seismic horizons where interpreted between the first appearance of the Namorado Sandstone and the top of Quissamã Formation. This interval presents normal listric faulting, in Cherne and Namorado Field with NWSE and NE-SW direction, and sedimentation trend to NW-SE, in Albacora Field the faulting presents a NNE-SSW and N-S direction, with a sedimentation trend to NE-SW. Seismic attribute maps present amplitude anomalies close to the producing wells, and on Namorado Field, it indicates a potential hydrocarbon accumulation in the NE region. For each field is indicated laboratory tests for a better characterization of the petrophysical properties, since that they don’t form the same reservoir level, therefore, not influencing the water saturation calculation

Caracterização estrutural do Lineamento de Piúma e sua influência na porção norte da Bacia de Campos

The detailed study of the Brazilian continental margin basins became possible with the advancement of geophysical tools, with emphasis on seismic reflection. Characterizing the structural and stratigraphic elements of Brazil’s marginal basins they realized that there was a relationship with structures present on the adjacent continental basement. So many works began to be made to understand this relationship and know the major factors that influenced the evolution of the continental margin. The study area of this work includes the northern portion of the Campos Basin and the continental outcropping adjacent areas, which corresponds to the northern of Rio de Janeiro state and the southern of Espirito Santo state. This area stands an important structural feature of NW-SE direction with a projection to the Campos Basin called Lineamento de Piúma. The outcropping basement rocks belongs to the Ribeira Belt which was bonded to other mobile bands forming the continent Western Gondwana during the Brasiliano Cycle, which later fragmented giving rise to the Atlantic Ocean. The opening of the ocean results on the formation of the marginal basins of Brazil. These basins have continental, transitional and marine facies. On Campos Basin the continental phase resulted on the formation of horsts and grabens bounded by synthetic and antithetic faults. Continuing rifting formed the saline lakes that deposited siliciclastic and carbonate sediments. The transitional phase resulted on thick packages consist of evaporites (halite and anhydrite) that was deposited in lagoon environment, tectonically quiet arid and semi-arid. The marine phase it deposited siliciclastic and carbonate in the Campos Basin resulting in shales, marls, limestones, ritmito, turbidites, sandstones and others. The objective of this study is to investigate the possible continuation... (Complete abstract click electronic access below)

Interpretação tectono-estratigráfica do reservatório Quissamã (Eo-meso-albiano) nos campos de Pampo, Bicudo e Bonito, Bacia de Campos

Hydrocarbon accumulations occur in marine carbonate reservoirs of Quissamã Formation (early to midlle Albian), southwest Campos Basin. We investigated Pampo, Bicudo and Bonito fields, in order to understand the tectono-structural framework of oncolite/bioclast coarse-grained calcarenite reservoir and the calcilutite-marl-shale sealing interval (Late Albian to Turonian). The database of eleven wells from those fields allowed to elaborate structural sections correlating the Macaé Group – both Quissamã reservoir and Outeiro seal, the latter corresponding to the tectonic deepening phase of basin evolution. Based on density and electric logs, it was prepared structural sections of the carbonate reservoirs with consequent identification of porous zones and oil-water contacts. An extensive 3-D seismic database (~300 Km2) allowed to map three reflectors which represent the limiting units of Macaé Group