Adaptive visualization of deepwater turbidite systems in Campos Basin using 3-D seismic

• Published in: Leading edge (Tulsa, Okla.) Vol. 19; no. 5; pp. 512 - 517
• Main Authors: Santos, Rogerio A, Lopes, Marcos R. F, Cora, Carlos A. G, Bruhn, Carlos H. L
• Format: Journal Article
• Language: English
• Published: Society of Exploration Geophysicists 01-05-2000
• Subjects: acoustical methods; applied (geophysical surveys & methods); Atlantic Ocean; bathymetry; Brazil; Campos Basin; Carapebus Formation; Cenozoic; deep-water environment; directional drilling; drilling; Economic geology; energy sources; geophysical methods; Geophysics; horizontal drilling; immersion; lithologic controls; marine sediments; Miocene; Neogene; Oligocene; Paleogene; petroleum; petroleum engineering; petroleum exploration; reservoir properties; reservoirs; sedimentary structures; sediments; seismic methods; side-scanning methods; sonar methods; South America; South Atlantic; structural controls; Tertiary; theoretical studies; three-dimensional models; turbidite; turbidity current structures; visualization
• ISSN: 1070-485X; 1938-3789
• DOI: 10.1190/1.1438648

Oil accumulations in the deepwater Campos Basin offshore Brazil are found in Oligocene/Miocene sand-rich turbidites of contrasting architectural types. Reservoirs are sand lobes with thickness of 50 m, width of 1-5 km wide, and length of 2-10 km that display compensation stacking patterns. The reservoirs show bright reflections in a single amplitude trough corresponding to a relative decrease in impedance. In the study area, turbidite successions have high structural dips and complex spatial distribution. Their individual geometries are very difficult to map using conventional 3-D data.