USRE41656E1 - Method and system for reducing effects of sea surface ghost contamination in seismic data - Google Patents

Method and system for reducing effects of sea surface ghost contamination in seismic data Download PDF

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USRE41656E1
USRE41656E1 US11/501,195 US50119500A USRE41656E US RE41656 E1 USRE41656 E1 US RE41656E1 US 50119500 A US50119500 A US 50119500A US RE41656 E USRE41656 E US RE41656E
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particle motion
location
vertical
data
acoustic energy
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Johan Robertsson
Julian Edward Kragh
James Edward Martin
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Westerngeco LLC
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Westerngeco LLC
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/38—Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
    • G01V1/3808—Seismic data acquisition, e.g. survey design
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G01V1/36—Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
    • G01V1/364—Seismic filtering
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/50—Corrections or adjustments related to wave propagation
    • G01V2210/56—De-ghosting; Reverberation compensation

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  • the present invention relates to the field of reducing the effects of sea-surface ghost reflections in seismic data.
  • the invention relates an improved de-ghosting method that utilises measurements or estimates of multi-component marine seismic data recorded in a fluid medium.
  • Removing the ghost reflections from seismic data is for many experimental configurations equivalent to up/down wavefield separation of the recorded data.
  • the down-going part of the wavefield represents the ghost and the up-going wavefield represents the desired signal.
  • Exact filters for up/down separation of multi-component wavefield measurements in Ocean Bottom Cable (OBC) configurations have been derived by Amundsen and Ikelle, and are described in U.K. Patent Application Number 9800741.2.
  • An example of such a filter corresponding to de-ghosting of pressure data at a frequency of 50 Hz for a seafloor with P-velocity of 2000 m/s, S-velocity of 500 m/s and density of 1800 kg/m3 is shown in FIG. 2 .
  • the OBC de-ghosting filters have been shown to work very well on synthetic data. However, apart from the difficulty with poles and zeros at critical wave numbers, they also require knowledge about the principles of the immediate sub-bottom locations as well as hydrophone/geophone calibration and coupling compensation.
  • a method for sea surface ghost correction through the application of spatial filters to the case of marine seismic data acquired in a fluid medium.
  • both pressure and vertical velocity measurements are acquired along the streamer.
  • the invention takes advantage of non-conventional velocity measurements taken along a marine towed streamer, for example.
  • New streamer designs are currently under development and are expected to become commercially available in the near future. For example, the Defense Evaluation and Research Agency (DERA), based in Dorset, U.K., claim to have successfully built such a streamer for high frequency sonar applications.
  • DPA Defense Evaluation and Research Agency
  • the invention is also applicable to seismic data obtained with configurations of multiple conventional streamers.
  • the filters make use of vertical pressure gradient measurements, as opposed to velocity measurements.
  • an estimate of the vertical pressure gradient can be obtained from over/under twin streamer data, or more generally from streamer data acquired by a plurality of streamers where the streamers are spatially deployed in a manner analogous to that described in U.K Patent Application Number 9820049.6, by Robertsson, entitled “Seismic detection apparatus and related method” filed in 1998 (hereinafter “Robertsson (1998)”).
  • three streamers can be used, forming a triangular shape cross-section along their length.
  • Vertical pressure gradient data can also be obtained from pressure gradient measuring devices.
  • the filters fully account for the rough sea perturbed ghost, showing improvement over other techniques based on normal incidence approximations (see e.g., White (1965)), which have been applied to data recorded at the sea floor.
  • the results are not sensitive to streamer depth, allowing the streamer(s) to be towed at depths below swell noise contamination, hence opening up the acquisition weather window where shallow towed streamer data would be unusable.
  • Local streamer accelerations will be minimised in the deep water flow regime, improving resolution of the pressure, multi-component velocity and pressure gradient measurements.
  • the filter is not critically dependent on detailed knowledge of the physical properties of the surrounding fluid medium.
  • the filters can be simple spatial convolutions, and with the regular geometry of typical towed streamer acquisition the filters are efficient to apply in the frequency-wavenumber wavenumber (FK) domain.
  • the filters can also be formulated for application in other domains, such as time-space and intercept time-slowness ( ⁇ -p)
  • a method of reducing the effects is seismic data of downward propagating reflected and scattered acoustic energy travelling in a fluid medium.
  • the method advantageously makes use of two types of data: pressure data, that represents the pressure in the fluid medium, such as sea water, at a number of locations; and vertical particle motion data, that represents the vertical particle motion of the acoustic energy propagating in the fluid medium at a number of locations within the same spatial area as the pressure data.
  • the distance between the locations that are represented by the pressure data and the vertical particle motion data in each case is preferably less than the Nyquist spatial sampling criterion.
  • the vertical particle motion data can be in various forms, for example, velocity, pressure gradient, displacement, or acceleration.
  • the spatial filter is created by calculating a number of coefficients that are based on the velocity of sound in the fluid medium and the density of the fluid medium.
  • the spatial filter is designed so as to be effective at separating up and down propagating acoustic energy over substantially the entire range of non-horizontal incidence angles in the fluid medium.
  • the spatial filter is applied to either the vertical particle motion data or to the pressure data, and then combined with the other data to generate pressure data that has its up and down propagating components separated.
  • the separated data are then processed further and analysed. Ordinarily the down-going data would be analysed, but the up going data could be used instead if the sea surface was sufficiently calm.
  • a method of reducing the effects of downward propagating reflected and scattered acoustic energy travelling in a fluid medium wherein the pressure data and vertical particle motion data represent variations caused by a first source event and a second source event.
  • the source events are preferably generated by firing a seismic source at different locations at different times, and the distance between the locations is preferably less than the Nyquist spatial sampling criterion.
  • the present invention is also embodied in a computer-readable medium which can be used for directing an apparatus, preferably a computer, to reduce the effects in seismic data of downward propagating reflected and scattered acoustic energy travelling in a fluid medium as otherwise described herein.
  • FIG. 1 shows examples of simple seismic ray paths for primary events, and ghosts that are last reflected from the rough sea-surface;
  • FIG. 2 shows an exact pressure de-ghosting filter for OBC data for a seafloor with P-velocity of 2000 m/s, S-velocity of 500 m/s and density of 1800 kg/m3; the upper panel shows the Real part of exact filter; and the lower panel shows the Imaginary part of exact filter;
  • FIG. 3 shows the Real part of the exact OBC de-ghosting filter (in the solid line) shown in FIG. 2 , the first order Taylor approximation filter (in the plus line), and the first four fractional expansion approximations filters (in the dash-dotted lines);
  • FIG. 4 illustrates the potential impact of 3D rough sea surface ghost reflection and scattering on consistency of the seismic data waveform
  • FIG. 5 illustrates the potential impact of the rough sea surface ghost perturbation on time-lapse seismic data quality
  • FIGS. 6a-6f show various embodiments for data acquisition set-ups and streamer configurations according to preferred embodiments of the invention.
  • FIG. 8 is a flow chart illustrating some of the steps of the de-ghosting method for the combination of pressure and vertical velocity data to achieve separated pressure data, according to a preferred embodiment of the invention.
  • FIG. 9 schematically illustrates an example of a data processor that can be used to carry out preferred embodiments of the invention.
  • FIG. 10 shows an example of a shot record computed below a 4 m significant wave height (SWH) rough sea surface, the left panel shows pressure, and the right panel shows vertical velocity scaled by water density and the compressional wave speed in water;
  • SWH significant wave height
  • FIG. 11 illustrates de-ghosting results of the shot record in FIG. 10 , the left panel shows results using the vertical incidence approximation, and the right panel illustrates the exact solution;
  • FIG. 12 illustrates an example of de-ghosting results in detail for a single trace at 330 m offset corresponding to an arrival angle of about 37 degrees, the upper panel shows the vertical incidence approximation, and the lower panel shows the Exact solution;
  • FIGS. 12a-b illustrate two possible examples of multi-component streamer design.
  • FIG. 1 is a schematic diagram showing reflections between a sea surface (S), sea floor (W) and a target reflector (T).
  • S sea surface
  • W sea floor
  • T target reflector
  • Various events that will be recorded in the seismogram are shown and are labelled according to the series of interfaces they are reflected at.
  • the stars indicate the seismic source and the arrowheads indicate the direction of propagation at the receiver.
  • Events ending with ‘S’ were last reflected at the rough sea surface and are called receiver ghost events.
  • Down-going sea-surface ghost reflections are an undesirable source of contamination, obscuring the interpretation of the desired up-going reflections from the earth's sub-surface.
  • Rough seas are a source of noise in seismic data. Aside from the often-observed swell noise, further errors are introduced into the reflection events by ghost reflection and scattering from the rough sea surface. The rough sea perturbed ghost events introduce errors that are significant for time-lapse seismic surveying and the reliable acquisition of repeatable data for stratigraphic inversion.
  • the effect of the rough sea is to perturb the amplitude and arrival time of the sea surface reflection ghost and add a scattering coda, or tail, to the ghost impulse.
  • the impulse response can be calculated by finite difference or Kirchhoff methods (for example) from a scattering surface which represents statistically typical rough sea surfaces.
  • a directional form of the Pierson-Moskowitz spectrum described by Pierson, W. J. and Moskowitz, L., 1964 ‘A proposed Spectral Form for Fully Developed Wind Seas Based on the Similarity Theory of S. A. Kitaigorodskii’ J. Geo. Res., 69, 24, 5181-5190, (hereinafter “Pierson and Moskowitz (1964)”), and Hasselmann, D. E., Dunckel, M.
  • SWH Significant Wave Height
  • FIG. 4 shows an example of rough sea impulses along a 400 m 2D line (e.g. streamer) computed under a 2 m SWH 3D rough sea surface.
  • the streamer shape affects the details of the impulses, and in this example the streamer is straight and horizontal.
  • FIG. 4 shows, from top to bottom: The ghost wavelet (white trough) arrival time, the ghost wavelet maximum amplitude, a section through the rough sea realisation above the streamer, and the computed rough sea impulses.
  • the black peak is the upward travelling wave, which is unperturbed; the white trough is the sea ghost reflected from the rough sea surface.
  • the latter part of the wavelet at each receiver is the scattering coda from increasingly more distant parts of the surface.
  • the arrival time perturbations are governed by the dominant wavelengths in the sea surface, which are 100-200 m for 2-4 m SWH seas, and the amplitude perturbations are governed by the curvature of the sea surface which has an RMS radius of about 80 m and if fairly independent of sea state.
  • the diffraction coda appear as quasi-random noise following the ghost pulse.
  • the rough sea perturbations cause a partial fill and a shift of the ghost notch in the frequency domain. They also add a small ripple to the spectrum, which amounts to 1-2 dB of error for typical sea states. In the post stack domain this translates to an error in the signal that is about ⁇ 20 dB for a 2 m SWH sea.
  • FIG. 5 shows an example of how such an error can be significant for time-lapse surveys.
  • the panel on the top left shows a post-stack time-migrated synthetic finite difference seismic section.
  • the top middle panel shows the same data but after simulating production in the oil reservoir by shifting the oil water contact by 6 m and introducing a 6 m partial depletion zone above this.
  • the small difference is just noticeable on the black leg of the reflection to the right of the fault just below 2 s two-way travel-time.
  • the panel on the right (top) shows the difference between these two sections multiplied by a factor of 10. This is the ideal seismic response from the time-lapse anomaly.
  • the left and middle bottom panels show the same seismic sections, but rough sea perturbations of a 2 m SWH (as described above) have been added to the raw data before processing. Note that different rough sea effects are added to each model to represent the different seas at the time of acquisition. The difference obtained between the two sections is shown on the bottom right panel (again multiplied by a factor of 10).
  • the errors in the reflector amplitude and phase introduce noise of similar amplitude to the true seismic time-lapse response. To a great extent, the true response is masked by these rough sea perturbations.
  • a method for correcting these types of error is clearly important in such a case, and with the increasing requirement for higher quality, low noise-floor data, correction for the rough sea ghost becomes necessary even in modest sea states.
  • Equation (1) gives the frequency domain expression for a preferred filter relating the up-going pressure field, p u (x), to the total pressure, p(x), and vertical particle velocity, v z (x).
  • p u ⁇ ( x ) 0.5 ⁇ [ p ⁇ ( x ) + ⁇ k z * v z ⁇ ( x ) ] ( 1 )
  • k z is the vertical wavenumber for compressional waves in the water
  • ⁇ is the density of water
  • * denotes spatial convolution.
  • c the compressional wave speed in the water
  • k x is the horizontal wavenumber for compressional waves in the water.
  • Equation (1) can also be formulated in terms of the vertical pressure gradient (dp(x)/dz).
  • FIGS. 6a-6f show various embodiments for data acquisition set-ups and streamer configurations according to preferred embodiments of the invention.
  • FIG. 6a shows a seismic vessel 120 towing a seismic source 110 and a seismic streamer 118 .
  • the sea surface is shown by reference number 112 .
  • the depth of streamer 118 is about 60 meters, however those of skill in the art will recognise that a much shallower depth would ordinarily be used such as 6-10 meters.
  • the dashed arrows 122 a-d show paths of seismic energy from source 110 .
  • Arrow 122 a shows the initial down-going seismic energy.
  • Arrow 122 b shows a portion of the seismic energy that is transmitted through the sea floor 114 .
  • Arrow 122 c shows an up-going reflection.
  • Arrow 122 d shows a down-going ghost reflected from the surface.
  • the down-going rough sea receiver ghost 122 d can be removed from the seismic data.
  • FIGS. 6b-6f show greater detail of acquisition set-ups and streamer configurations, according to the invention.
  • FIG. 6b shows a multi-component streamer 124 .
  • the streamer 124 comprises multiple hydrophones (measuring pressure) 126 a, 126 b, and 126 c, and multiple 3C geophones (measuring particle velocity in three directions x, y, and z) 128 a, 128 b, and 128 c.
  • the spacing between the hydrophones 126 a and 126 b, and between geophones 128 a and 128 b is shown to be less than 12 meters. Additionally, the preferred spacing in relation to the frequencies of interest is discussed in greater detail below.
  • FIG. 6c shows a streamer 130 that comprises multiple hydrophones 132 a, 132 b, and 132 c, and multiple pressure gradient measuring devices 134 a, 134 b, and 134 c.
  • the spacing between the hydrophones 132 a and 132 b, and between pressure gradient measuring devices 134 a and 134 b is shown to be less than 12 meters.
  • FIG. 6d shows a multi-streamer configuration that comprises hydrophone streamers 140 a and 140 b.
  • the streamers comprise multiple hydrophones 142 a, 142 b, and 142 c in the case of streamer 140 a, and 142 d, 142 e, and 142 f in the case of streamer 140 b.
  • the spacing between the hydrophones is shown to be less than 12 meters.
  • the separation between streamers 140 a and 140 b in the example shown in FIG. 6d is less then 2 meters. Although the preferred separation is less than 2 meters, greater separations are contemplated as being within the scope of the invention.
  • FIG. 6e shows a cross sectional view of a dual streamer arrangement.
  • FIG. 6f shows a multi-streamer configuration comprising three hydrophone streamers 140 a, 140 b, and 140 c.
  • Adequate spatial sampling of the wavefield is highly preferred for the successful application of the de-ghosting filters.
  • a spatial sampling interval of 12 m is adequate for all incidence angles.
  • a spatial sampling interval of 6.25 meters is preferred. These spacings are determined according to the Nyquist spatial sampling criterion. Note that if all incidence angles are not required, a coarser spacing than described above can be used.
  • the filters can be applied equally to both group formed or point receiver data.
  • FIG. 8 is a flow chart illustrating some of the steps of the de-ghosting method for the combination of pressure and vertical velocity data to achieve separated pressure data, according to a preferred embodiment of the invention.
  • step 202 spatial filter coefficients are calculated. The coefficients are preferably dependent on the characteristics of the acquisition parameters 203 (such as the temporal sample interval of the pressure and particle motion data, the spatial separation of the vertical particle motion measuring devices, and the spatial aperture of the filter), the density of the fluid medium 206 , and the speed of the compressional wave in the fluid medium (or velocity of sound) 204 .
  • Vertical particle motion data 208 and pressure data 212 are received, typically stored as time domain traces on a magnetic tape or disk.
  • step 210 the vertical particle motion data 208 are convolved in with the spatial filter to yield filtered vertical particle motion data.
  • the filtered vertical particle motion data are added to pressure data 212 to give the downward propagating component of the separated pressure data.
  • step 216 the filtered vertical particle motion data are subtracted from pressure data 212 to give the upward propagating component of the separated pressure data.
  • step 218 the upward component is further processes and analysed.
  • FIG. 9 illustrates one possible configuration for such a data processor.
  • the data processor typically consists of one or more central processing units 350 , main memory 352 , communications or I/O modules 354 , graphics devices 356 , a floating point accelerator 358 , and mass storage devices such as tapes and discs 360 .
  • tapes and discs 360 are computer-readable media that can contain programs used to direct the data processor to carry out the processing described herein.
  • FIG. 10 shows a shot record example, computed under a 4 m Significant Wave Height (SWH) sea and using the finite-difference method described by Robertsson, J. O. A., Blanch, J. O. and Symes, W. W., 1994 ‘Viscoelastic finite-difference modelling’ Geophysics, 59, 1444-1456 (hereinafter “Robertsson et al. (1994)”) and Robertsson, J. O. A., 1996 ‘A Numerical Free-Surface Condition for Elastic/Viscoelastic Finite-difference modelling in the Presence of Topography’, Geophysics, 61, 6, 1921-1934 (hereinafter “Robertsson (1996)”).
  • SWH Significant Wave Height
  • the streamer depth in this example is 60 m.
  • the left panel shows the pressure response and the right panel shows the vertical velocity response scaled by the water density and the compressional wave speed in water.
  • a point source 50 Hz Ricker wavelet was used and the streamer depth was 60 m in this example.
  • the choice of streamer depth allows a clear separation of the downward travelling ghost from the upward travelling reflection energy for visual clarity of the de-ghosting results.
  • the trace spacing on the plot is 24 m. A single reflection and its associated ghost are shown, along with the direct wave travelling in the water layer. Perturbations in the ghost wavelet and scattering noise from the rough sea surface are evident.
  • FIG. 11 shows the results of de-ghosting the shot record shown in FIG. 10 .
  • the left panel shows the result using the normal incidence approximation and the right panel shows the result using the exact solution.
  • the exact solution shows a consistent response over all offsets, whereas the normal incidence approximation starts to break down at incident angles greater than about 20 degrees, and shows a poorer result at the near offsets.
  • the direct wave is not amplified by the exact filter application even though the poles of the filter lie close to its apparent velocity.
  • the exact filter is tapered before application such that it is has near unity response for frequencies and wavenumbers corresponding to apparent velocities of 1500 m/s and greater.
  • the weak event just below the signal reflection is a reflection from the wide absorbing boundary of the model. It is upward travelling and hence untouched by the filter.
  • FIG. 12 shows details of the de-ghosted results for a single trace from FIG. 11 .
  • the trace offset is 330 m corresponding to a 37 degree incidence angle.
  • the upper panel shows the normal incidence approximation, and the lower panel shows the exact solution. Not only does the exact solution provide a superior result in terms of the de-ghosting, but also in terms of amplitude preservation of the signal reflection—the upper panel shows loss of signal amplitude after the de-ghosting.
  • the filters described herein are applicable to, for example, measurements of both pressure and vertical velocity along the streamer.
  • pressure measurements are commercially available. Therefore, engineering of streamer sections that are capable of commercially measuring vertical velocity is preferred in order to implement the filters.
  • FIGS. 13a-b illustrate two possible examples of multi-component streamer design.
  • FIG. 13a shows a coincident pressure and single 3-component geophone. In this design, the 3-component geophone is perfectly decoupled from the streamer.
  • FIG. 13b shows a coincident pressure and twin 3-component geophones. In this design, one of the 3-component geophones is decoupled from the streamer, the other is coupled to the streamer, measurements from both are combined to remove streamer motion from the data.
  • the filters make use of vertical pressure gradient measurements.
  • An estimate of vertical pressure can be obtained from over/under twin streamers (such as shown in FIGS. 6d and 6e ) and multiple streamers (such as shown in FIG. 6f ) deployed in configurations analogous to that described in Robertsson (1998), allowing the filters to be directly applied to such data.
  • the streamers should not be vertically separated by more than 2 m for seismic frequencies below approximately 80 Hz.
  • An important advantage of multiple streamer configurations such as shown in FIG. 6f is that their relative locations are less crucial than for over/under twin streamer geometries, where the two streamers are preferably directly above one another.
  • the filters described here are applied in 2D (along the streamer) to data modelled in 2D.
  • the application to towed streamer configurations naturally lends itself to this implementations, the cross-line (streamer) sampling to the wavefield being usually insufficient for a full 3D implementation.
  • Application of these filters to real data will give rise to residual errors caused by scattering of the wavefield from the cross-line direction. This error increases with frequency though is less than 0.5 dB in amplitude and 3.6° in phase for frequencies up to 150 Hz, for a 4 m SWH sea. These small residual noise levels are acceptable when time-lapse seismic surveys are to be conducted.
  • the filters can be applied in common receiver domain to remove the downward travelling source ghost. Reciprocity simply means that the locations of source and receiver pairs can be interchanged, (the ray path remaining the same) without altering the seismic response.
  • FIG. 1 can also be used to define the source ghost if the stars are now regarded as receivers and the direction of the arrows is reversed, with the source now being located at the arrow. This application is particularly relevant for data acquired using vertical cables, which may be tethered, for example, to the sea floor, or suspended from buoys.
  • FIG. 6a those of skill in the art will understand that as the seismic vessel 120 travels though the water, the firing position of source 110 will change. The different positions of source 110 can be then be used to construct data in the common receiver domain as is well known in the art.

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