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Summary In this work, a raytrace modeling was performed in an area of the Eastern Venezuela Basin, characterized by the presence of mud diapirs. From the interpretation of 2D seismic data, previously acquired in the area, a geological model was generated, and these data were analyzed in terms of illumination and CRP-CMP displacements, in order to study the possible acquisition of a 3D survey. The poor illumination and large CMP-CRP displacements of these 2D seismic data suggest the need of acquiring the 3D survey. A 3D raytrace modeling was accomplished and from this ray-tracing, attribute maps were generated in order to analyze the illumination of target horizons; particularly the Miocene top and base were studied, as during this period arcilokinesis took place (Giraldo, C., 1999).
- Geology > Structural Geology > Tectonics (0.51)
- Geology > Sedimentary Basin (0.41)
- South America > Venezuela > North Atlantic Ocean > Eastern Venezuela Basin (0.99)
- North America > Mexico > Veracruz > Papaloapan Basin > Topila Field (0.99)
Mode Converted Waves In Exploration For Deeper Pays of North Cambay Basin, India: Evaluation With Modeling
Harilal, _ (Oil and Natural Gas Corporation Limited, India.) | Kale, A.S. (Oil and Natural Gas Corporation Limited, India.) | Kuara, D.K. (Oil and Natural Gas Corporation Limited, India.) | Goel, A.D. (Oil and Natural Gas Corporation Limited, India.)
Summary The deeper sedimentary sequences of North Cambay Basin, India, are difficult to explore with P-wave surveys alone. Very high acoustic impedance contrast in sand-coal-shale sequences at shallower levels and low acoustic impedance contrast in sand-silt-shale sequences at deeper levels cause feeble deeper reflections contaminated with multiples and mode converted events. The S-wave responses of the deeper formations are more favorable than P-wave responses. The deeper hydrocarbon bearing sand/silts layers have higher S-wave velocity, lower velocity ratio, and lower Poisson’s ratio while the enclosing shales have higher Poisson’s ratio. Shear-wave reflection coefficients and Poisson’s ratio contrasts are higher at top and bottom interfaces. A realistic horizontally layered earth model was prepared with integration of the geologic and log data of the area.
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.82)
- Asia > India > Rajasthan > Cambay Basin (0.99)
- Asia > India > Gujarat > Cambay Basin > North Cambay Basin (0.99)
- Asia > India > Gujarat > Cambay Basin > Kalol Formation (0.99)
Summary Figure 1. Fluid dynamic map of example line from Vrezovskaya 3D survey. {Color indicates relative overpressure (blue) to relative underpressure (red). Producing well at location A. Zonal boundaries indicated along right side of section. This is a classical example that provides confirmation of the dynamic fluid method of oil field generation. The seismic signal is shown to contain information that illustrates the migration of hydrocarbons, and the pressure regimes that currently control them. An example from the Tatarstan Republic is shown that outlines the source and the migration pathways for a Carboniferous reservoir. Introduction The dynamic fluid method (or DFM) is based on the theory that no basin is actually static. While this is derived from plate tectonics on the macro scale, it also is applicable to meso-scale structures, such as basins. Expression of this movement can be found in faulting and fracturing.
- Europe > Russia > Volga Federal District > Republic of Tatarstan (0.27)
- North America > United States > Utah (0.20)
A Case Study Of Fluid Modulus Inversion For Miocene Sandstone Reservoir, Gulf of Mexico
Fouad, Khaled (Institute for Exploration and Development Geosciences, U. of Oklahoma) | Castagna, John P. (Institute for Exploration and Development Geosciences, U. of Oklahoma) | Lamb, William (Institute for Exploration and Development Geosciences, U. of Oklahoma) | White, Luther (Institute for Exploration and Development Geosciences, U. of Oklahoma) | Siegfried, Bob (Gas Technology Institute)
Summary In this paper, we apply the stochastic inversion technique described in White et al. (2002), which uses seismic amplitudes and statistical rock properties information, to generate probability distributions of the fluid modulus and fluid density in a prospective reservoir. A case study on a deep Gulf of Mexico Miocene sandstone reservoir shows that valuable stochastic estimations of fluid modulus can be achieved from compressional-wave reflectivities, even without well control. Introduction Measuring the fluid modulus and density in a prospective reservoir from seismic amplitude is a challenging task. Although seismic amplitudes contain information related to properties of fluids saturating rocks adjacent to a reflection boundary, they are strongly affected by rock frame properties of the reservoir and seal impedance among other perturbing factors (Castagna et al. 1993).
- North America > United States > Utah (0.19)
- North America > United States > Oklahoma > Cleveland County > Norman (0.16)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.89)
Summary A recent seismic survey, shot over a mature gas field in the Veracruz Basin, provides a unique opportunity to investigate rock properties in deepwater reservoirs, which consist of turbidite lobes and channel complexes. Reservoir geometries were successfully imaged using conventional interval and windowed attribute-extraction techniques. Numerous tested and candidate DHIs were delineated and mapped from several stratigraphic units. Gas sands on well logs are associated with an abrupt decrease in impedance. In this study, a multiattribute analysis was used to predict P-wave (pseudosonic) from seismic data. Two techniques were used to measure statistics: linear regression and probabilistic neural network (PNN), (Hampson et al., 2001; Leiphart and Hart, 2001). Both techniques produced good predictions, with the trained PNN yielding a better match at the targeted zones. P-wave velocity was generated for porosity calculations on the basis of the Raymer, Hunt & Gardner equation.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.96)
- North America > United States > Gulf of Mexico > Gulf Coast Basin (0.99)
- North America > Mexico > Veracruz > Veracruz Basin (0.99)
- North America > Mexico > Gulf of Mexico > Veracruz Basin (0.99)
Summary Over the last decade significant exploration for diamonds has expanded beyond the traditional Kaapvaal and Siberian Cratons. However, the globe is a large place, and area selection is clearly key to efficient and effective exploration. Whilst diamond companies traditionally use mainly geochemical methods for area selection, the recent results from deep probing electromagnetic (EM) studies on the Slave craton and western Superior Province indicate that such studies can aid area selection considerably. EM surveys can define the base of the lithosphere-asthenosphere boundary, they can contribute to knowledge about a region''s tectonic history, and they can identify whether a region is likely to contain high concentrations of carbon in its sub-continental lithospheric mantle.
- Geology > Structural Geology > Tectonics > Plate Tectonics (1.00)
- Geology > Mineral > Native Element Mineral > Diamond (1.00)
Summary This paper studied the rock physics properties and AVO sensitivities in a gas field in Mackenzie Delta, Northwest Territory, Canada. The study was based on wire-line well log data and used modeling techniques. It aims at providing the feasibility analysis for the interpretation of AVO and AVO derived attributes from field seismic data. The rock physical properties of the reservoirs were analyzed to observe the trends between elastic parameters and reservoir rock properties, especially, gas saturation, shale volume, and porosity. LMR (Goodway et al., 1997) attributes were emphasized in the study. The ability of LMR attributes to describe reservoir properties, such as gas saturation and net-to-gross ratio, was investigated using the modeling technique.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.57)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.51)
Estimation of Fracture Orientation And Relative Intensity Using Azimuthal Variation of P-wave AVO Responses And Oriented Core Data In the Tacata Field, Venezuela.
Montoya, Patricia (University of Texas) | Fisher, William (University of Texas) | Marrett, Randall (University of Texas) | Tatham, Robert (University of Texas)
Summary At present, several methods can be used to describe and analyze natural fractures in the subsurface. One method uses cores as direct geological samples of fractures. Microfractures are imaged and describe with a scanning electron microscope (SEM) and cathodoluminescence detectors. However, the most conductive fractures typically are larger than core and too sparse to be adequately sampled with core, so indirect methods such as azimuthally dependent 3D P-wave amplitude responses can be used to identify fracture orientation and relative intensity. For this study, a fractured Tertiary, sandstone reservoir located in the northeastern part of Maturin Basin in Venezuela was chosen.
- South America > Venezuela > Anzoátegui (0.42)
- South America > Venezuela > Monagas > Maturin (0.26)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.55)
- Geology > Structural Geology (0.47)
- South America > Venezuela > Monagas > Eastern Venezuela Basin > Maturin Basin > Carapita Formation (0.99)
- South America > Venezuela > Anzoátegui > Eastern Venezuela Basin > Oriental Basin > Maturín Basin > Tacata Field (0.99)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Mission Canyon Formation (0.99)
- (3 more...)
Seismic Data As Input to Detailed Hydrocarbon Migration Modeling
Sollie, Roger (Statoil Research Centre) | Hansen, Hans Peder (Ødegaard) | Østmo, Svend (SINTEF Petroleum Research) | Zweigel, Janine (SINTEF Petroleum Research) | Sylta, Øyvind (SINTEF Petroleum Research) | Hamborg, Martin (SINTEF Petroleum Research) | Zweigel, Peter (SINTEF Petroleum Research) | Maver, Kim Gunn (Ødegaard) | Kjennerud, Tomas (SINTEF Petroleum Research)
Summary The major result of this project is the demonstration of a method that uses the geophysical and geological data available in an exploration target area directly in the modeling of hydrocarbon migration. This has been done by establishing a working environment that provides a seamless interface between the geological model and interpretation, the seismic inversion and the modeling of secondary migration of hydrocarbons. Thus, an optimal utilization of all existing data is achieved. The geological model building serves as a tool for a consistent seismic interpretation, as well as providing an input and initial model for the seismic inversion. The inversion provides models for petrophysical parameters, such as porosity, as well as the lithofacies distribution in the area.
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.51)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.32)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling > Seismic Inversion (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Seismic Surveying > Seismic Processing > Seismic Migration (0.95)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 418 > Viking Formation > Heather Formation (0.99)
- Europe > Norway > North Sea > Draupne Formation (0.99)
- Europe > Norway > North Sea > Central North Sea > South Viking Graben > PL 046 > Block 15/9 > Volve Field > Shetland Group > Åsgard Formation (0.99)
- (19 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
Radar Stratigraphy of Large Active Dunes On a Coastal Spit, Parengarenga Harbour, New Zealand: a First Assessment
Van Dam, Remke L. (School of Geography and Environmental Science, University of Auckland) | Nichol, Scott L. (School of Geography and Environmental Science, University of Auckland) | Augustinus, Paul C. (School of Geography and Environmental Science, University of Auckland) | Parnell, Kevin E. (School of Geography and Environmental Science, University of Auckland) | Hosking, Peter L. (School of Geography and Environmental Science, University of Auckland) | McLean, Roger F. (School of Geography and Oceanography, Australian Defense Force Academy, University of New South Wales)
Summary Ground-penetrating radar was used to study the stratigraphy and mode of development of a large solitary dune on a sandspit. Both dune and interdune flats are underlain by a Late Pleistocene paleosol. Radar images reveal three phases of dune development and together with the dune morphology point towards a combined star and transverse dune origin. Introduction The Parengarenga sandspit (Fig. 1) is New Zealand''s only coastal source of silica sand for glass manufacturing and concerns about the environmental effects of sand extraction from the harbor mouth in the last two decades led the extraction companies to instigate a monitoring program. The Parengarenga beach-dune-monitoring program started in 1982, subsequent to which cross-profiles have been surveyed from below Chart Datum (CD) to landward of the foredune system twice a year.
- Oceania > New Zealand (0.72)
- North America > United States > Utah (0.17)