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NARROW
GeoRef Subject
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all geography including DSDP/ODP Sites and Legs
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EAEG
Three dimensional SEG/EAEG models; an update
A national laboratory industry collaboration to use SEG/EAEG model data sets
SEG/EAEG 3-D modelling project; 2nd update
Report on the Joint SEG/EAEG Summer Research Workshop: How useful is AVO analysis?
SEG/EAEG reservoir geophysics workshop
SEG/EAEG Research Workshop on Reservoir Geophysics; participant perspectives
Abstract HolberG, O. 1988. Towards optimum one-way wave propagation. Geophysical Prospecting 36,99-114. Numerical wavefield extrapolation represents the backbone of any algorithm for depth migration pre- or post-stack. For such depth imaging techniques to yield reliable and inter-prétable results, the underlying wavefield extrapolation algorithm must propagate the waves through inhomogeneous media with a minimum of numerically induced distortion, over a range of frequencies and angles of propagation. A review of finite-difference (FD) approximations to the acoustic one-way wave equation in the space-frequency domain is presented. A straightforward generalization of the conventional FD formulation leads to an algorithm where the wavefield is continued downwards with space-variant symmetric convolutional operators. The operators can be precomputed and made accessible in tables such that the ratio between the temporal frequency and the local velocity is used to determine the correct operator at each grid point during the downward continuation. Convolutional operators are designed to fit the desired dispersion relation over a range of frequencies and angles of propagation such that the resulting numerical distortion is mini-mized. The optimization is constrained to ensure that evanescent energy and waves propagating at angles higher than the maximum design angle are attenuated in each extrapolation step. The resulting operators may be viewed as optimally truncated and bandlimited spatial versions of the familiar phase shift operator. They are unconditionally stable and can be applied explicitly. This results in a simple wave propagation algorithm, eminently suited for implementation on pipelined computers and on large parallel computing systems.
The P-wave velocity component from the SEG/EAEG 3D Overthrust model. The 3C...
Comparison of the prestack depth-migration results of 3D SEG/EAEG overthrus...
Compressional velocity distribution of the modified anisotropic SEG/EAEG sa...
Zero-offset section for the modified anisotropic SEG/EAEG salt model. Peak ...
A common offset gather with offset = 100 m computed from the SEG/EAEG overt...
The salt body and several reflecting horizons from the SEG/EAEG three-dimen...
Introduction to this special section: TLE 's 30th anniversary
3D wavefield extrapolation with optimum split-step Fourier method
Abstract At Big Sky, Montana, in 1992, the SEG/EAEG Joint Research Committee held the summer workshop, “How useful is amplitude-versus-offset (AVO) analysis?” From the worldwide exploration examples shown during this six-day conference, the answer could clearly be stated that AVO was an integral part of recognizing and high-grading prospects and well locations. During the Big Sky Conference, Revoir et al. (1992) and Russell et al. (1992) presented evaluations of AVO through seismic processing, modeling, and inversion utilizing the same data set from a Pliocene-trend gas field in the Gulf of Mexico. The field is located offshore in a fault basin bounded by major growth faults, and is near several salt and shale diapirs. The structure is broken up into several reservoirs by small (50–150-ft) (15-50-m) faults ( Fig. 7.A.1 ). A 2-D amplitude analysis was performed from a 3-D seismic data sail line. A directional well that was parallel to the 2-D line provided borehole control. The expanded sedimentary section consists of regressive sequences of deep marine deposits (including slope fans) overlain by shallower deltaic deposits (shelf, delta front and lower delta-plain deposits). The major productive sands are between 5000 and 12,000 ft (1500 and 3700 m) in depth and range in thickness from 20 to 180 ft (6 to 50 m) ( Fig. 7.A.2 ). The high amplitudes in the figure characterize the major sand pays. In addition, flat spots and phase reversals were dominant HCI’s for recognizing the gas/water contacts. Overall, the amplitude anomalies from the three productive sands showed excellent fit to structure.
Abstract We have designed two 3-D geologic models and simulated realistic 3-D surveys based on those models. This has been a collaborative effort of the Society of Exploration Geophysicists (SEG), the European Association of Exploration Geophysicists, and the United States Department of Energy National Laboratories. The project is usually referred to as the SEG/EAEG Modeling, or SEM, project. The two salt and overthrust 3-D models and the respective synthetic datasets will be made available to both the oil industry and academia. This SEM project has been a sizable undertaking, with computational requirements of several million dollars. By the end of 1995, about 800 gigabytes of data had been generated, completing Phase A and Phase B of the project. “Classic datasets” containing subsets of calculations conducted for Phases A and B have been defined. Any other subsets of data could be extracted from the whole dataset using a procedure devised at Lawrence Livermore National Laboratory (LLNL). Additional calculations of about three terabytes, Phase C, will be carried out as the project is completed around mid-1997. These datasets have already been used by many for testing and validating processing algorithms and aiding in survey design. Their use as standard 3-D datasets is expected to increase for many years.