Spatial filtering of marine seismic data

Geophysics ◽  
1983 ◽  
Vol 48 (12) ◽  
pp. 1611-1630 ◽  
Author(s):  
Bjørn Ursin

Extended source and receiver arrays have proved to be an effective tool for improving the data quality in marine seismic exploration. The extended arrays may be implemented in the field, or in a computer by the summation of traces with a common receiver coordinate or a common source coordinate, respectively. A tilted source or receiver array may be used to enhance reflectors with a specific dip. A tilted source array can be implemented in the field by delaying the pulses at the source subarrays, or in the computer by time‐shifting the traces before implementing the long source array. A tilted receiver array can approximately be implemented in the computer by time‐shifting the traces before implementing the long receiver array. In areas with complex geologic structure, the data can be corrected for normal moveout prior to implementing the extended arrays. The theoretical response of reflected waves from dipping reflectors for different extended array filters is given. Vertical and horizontal stacking constitute a spatial filter which is similar to an extended array filter. Vertical stacking with linear time shifts between the traces can be used to enhance reflectors with a specific dip. The theoretical response of reflected waves from dipping reflectors for different vertical and horizontal stacking filter is given. In order to discriminate against coherent noise travelling in the cross‐line direction, areal arrays must be used. The theoretical responses of three‐dimensional spatial filters are derived in the appendices. These responses are based on quadratic traveltime approximations for reflections in inhomogeneous layered media. A data example is presented which demonstrates the practical use of extended array filters, both implemented in the field and in the computer. From this example and others have come the following conclusions. In areas with strong coherent noise, a field‐implemented extended source array gives a signal‐to‐coherent noise improvement which cannot be obtained in data processing. In other areas, computer implementation of the extended arrays gives signal‐to‐coherent noise improvement as effectively as a field‐implemented extended source array. In such cases, the extended array filters should be implemented in the computer due to greater flexibility in testing on data and to the possibility of producing different stacked sections. Noise reduction is done more effectively by extended array filtering than by vertical and horizontal stacking prior to CDP stacking (weighted or unweighted full‐fold horizontal stacking).

Geophysics ◽  
2002 ◽  
Vol 67 (6) ◽  
pp. 1853-1868 ◽  
Author(s):  
Brian H. Hoffe ◽  
Gary F. Margrave ◽  
Robert R. Stewart ◽  
Darren S. Foltinek ◽  
Henry C. Bland ◽  
...  

This paper uses an experimental seismic line recorded with three‐component (3C) receivers to develop a case history demonstrating very little benefit from receiver arrays as compared to point receivers. Two common array designs are tested; they are detrimental to the P‐S wavefield and provide little additional benefit for P‐P data. The seismic data are a 3C 2‐D line recorded at closely spaced (2 m) point receivers over the Blackfoot oil field, Alberta. The 3C receiver arrays are constructed by summing five (one group interval) and ten (two group intervals) point receivers. The shorter array emphasizes signal preservation while the longer array places priority on noise rejection. The effectiveness of the arrays versus the single geophones is compared in both the t−x and f−k domains of common source gathers. The quality of poststack data is also compared by analyzing the f−x spectra for signal bandwidth on both the vertical receiver component (P‐P) and radial receiver component (P‐S) structure stacks produced using these two array design philosophies. The prestack analysis shows that the two arrays effectively suppress coherent noise on both the vertical and radial geophone data and perform reasonably as spatial antialias filters. The poststack analysis reveals that, for both the P‐P and P‐S data, neither of the two arrays significantly improves the quality of the final seismic image over that obtained from point receiver data. For the P‐P data there are subtle differences between the final stacked sections, while for the P‐S data there is a significant deterioration in image quality from the application of the arrays. This P‐S image deterioration is attributed to significant variation of shear‐wave statics across the array. For this specific survey area and acquisition parameters, 3C receiver arrays are unnecessary for P‐P data and are detrimental to P‐S data.


1989 ◽  
Vol 20 (2) ◽  
pp. 219
Author(s):  
B.J. Evans

Three dimensional (3D) marine seismic surveying is expensive and often a lengthy and technically difficult survey to perform. It is therefore only executed when an economically viable discovery is made. An alternative technique is offered which may be used when a marginally economic discovery is made. The technique is inexpensive compared to the conventional full 3D marine survey; it is cheaper than reconnaissance surveying and two boat operations, and provides a 3D migrated annular volume just over 3 kilometres in diameter for the approximate price of a single offset vertical seismic profile (VSP).The technique uses the exploration drilling rig as the energy source platform, the rig supply vessel as the receiver, and the site location system as the 3D navigation network. In using equipment conventionally mobilized with each drilling rig relocation, costs are substantially reduced and a larger portion of the 3D seismic exploration budget may be transferred to the engineering/drilling budget.Failure of the technique to be trialled is due to the conservatism found within the industry rather than technical considerations.


2001 ◽  
Vol 41 (1) ◽  
pp. 671
Author(s):  
T. Brice ◽  
L. Larsen ◽  
S. Morice ◽  
M. Svendsun

A new concept for acquiring calibrated towed streamer seismic data is introduced through a new acquisition and processing system called ‘Q-Marine’. The specification of the new system has been defined by rigorous analysis of the factors that limit the sensitivity of seismic data in 4D studies and imaging. New sensor and streamer technology, new source technology and advances in positioning techniques and data processing have addressed these limitations.Sensitivity analysis revealed that the most significant perturbations to the seismic signal are swell noise and sensor sensitivity variations. Conventional analog groups of hydrophones are designed to suppress swell noise however a new technique for data-adaptive coherent noise attenuation delivers even greater noise suppression for densely spatially sampled single-sensor data.Although modern source controllers provide accurate airgun firing control, the signature of an airgun array may vary from shot to shot. This can be due to factors such as changes in the array geometry, air pressure variations, depth variations and wave action. A method for estimating the far-field signature of a source array is the Notional Source Method (proprietary to Schlumberger) which has been steadily refined since its first disclosure. A recent development compensates for variation in source array geometry by monitoring the position and azimuth of each subarray using GPS receivers mounted on the floats.New calibrated positioning and streamer control systems are part of the new acquisition system. Active vertical and lateral streamer control is achieved using steerable birds and positioning uncertainty is reduced through an in-built fully braced acoustic ranging system.Calibrated marine seismic data are achieved through quantifying the source output, the sensor responses and positioning uncertainty. The consequential improvements in seismic fidelity result in better imaging and more reliable 4D analysis.


Geophysics ◽  
1985 ◽  
Vol 50 (7) ◽  
pp. 1049-1060 ◽  
Author(s):  
K. A. Berteussen ◽  
O. J. Alstad

We describe a procedure for modeling the primary and multiple reflected seabed pulses as a function of distance. The assumption is made that the registered pulse can be constructed as a sum of elementary pulses, that is, the time and relative size of the arrivals are calculated for each source‐receiver position. This is done using both angle‐dependent and angle‐independent reflection coefficients at the seabottom. For each receiver channel on the cable, the predicted seismogram is calculated as the sum of the registrations in each hydrophone included in that channel. It is demonstrated first how the shape of the seabottom reflections changes with the sea depth and source‐receiver distance because of geometry effects, and because of the extended sources and receivers applied in marine seismic exploration. Next, We show that angle‐dependent reflection coefficients do introduce additional and sometimes quite drastic variations in the shape of the different pulses. Finally, we demonstrate that the predicted pulses can be matched quite well to observed data from the North Sea. This gives a possibility to estimate the geophysical characteristics of the seabed.


Geophysics ◽  
2011 ◽  
Vol 76 (1) ◽  
pp. SA35-SA49 ◽  
Author(s):  
Simon King ◽  
Andrew Curtis ◽  
Travis L. Poole

In controlled-source seismic interferometry, waves from a surrounding boundary of sources recorded at two receivers are crosscorrelated and summed to synthesize the interreceiver Green’s function. Deviations of physically realistic source and receiver geometries from those required by theory result in errors in the Green’s function estimate. These errors are manifested as apparent energy that could not have propagated between receiver locations — so-called nonphysical energy. We have developed a novel method of velocity analysis that uses both the physical and nonphysical wavefield energy in the crosscorrelated data generated between receiver pairs. This method is used to constrain the root-mean-square (rms) velocity and layer thickness of a locally 1D medium. These estimates are used to compute the piece-wise constant interval velocity. Instead of suppressing multiple energy as in conventional common midpoint velocity analysis, the method uses the multiply reflected wavefield to further constrain the rms velocity and layer-thickness estimates. In particular, we determined that the nonphysical energy contains useful physical information. By using the nonphysical energy associated with the truncation of the source boundary and the crosscorrelation of reflected waves, a better-defined estimate of the rms velocity and layer thickness is achieved. Because this energy is excited far from the receiver pair, the technique may be ideally suited to long-offset seismic reflection data. We found that interferometric velocity analysis works best to characterize the first few layers beneath a receiver array. We have considered an acquisition configuration that can be used in a marine seismic setting.


Geophysics ◽  
1983 ◽  
Vol 48 (7) ◽  
pp. 854-886 ◽  
Author(s):  
Ken Larner ◽  
Ron Chambers ◽  
Mai Yang ◽  
Walt Lynn ◽  
Willon Wai

Despite significant advances in marine streamer design, seismic data are often plagued by coherent noise having approximately linear moveout across stacked sections. With an understanding of the characteristics that distinguish such noise from signal, we can decide which noise‐suppression techniques to use and at what stages to apply them in acquisition and processing. Three general mechanisms that might produce such noise patterns on stacked sections are examined: direct and trapped waves that propagate outward from the seismic source, cable motion caused by the tugging action of the boat and tail buoy, and scattered energy from irregularities in the water bottom and sub‐bottom. Depending upon the mechanism, entirely different noise patterns can be observed on shot profiles and common‐midpoint (CMP) gathers; these patterns can be diagnostic of the dominant mechanism in a given set of data. Field data from Canada and Alaska suggest that the dominant noise is from waves scattered within the shallow sub‐buttom. This type of noise, while not obvious on the shot records, is actually enhanced by CMP stacking. Moreover, this noise is not confined to marine data; it can be as strong as surface wave noise on stacked land seismic data as well. Of the many processing tools available, moveout filtering is best for suppressing the noise while preserving signal. Since the scattered noise does not exhibit a linear moveout pattern on CMP‐sorted gathers, moveout filtering must be applied either to traces within shot records and common‐receiver gathers or to stacked traces. Our data example demonstrates that although it is more costly, moveout filtering of the unstacked data is particularly effective because it conditions the data for the critical data‐dependent processing steps of predictive deconvolution and velocity analysis.


1999 ◽  
Vol 18 (1) ◽  
pp. 36-38 ◽  
Author(s):  
D.D. Sternlicht

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