Coding and decoding: Seismic data modeling, acquisition and processing

Ikelle, Luc T.

doi:10.1190/1.2792383

Cited by 55 publications

(34 citation statements)

References 2 publications

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“…The operator of Helmholtz equations, we can use the Born approximate,then the forward modeling is a linear inversion, when we do not use the Born approximation, the seismic inversion is a quasi linear inversion [5]. …”

Section: Domainmentioning

confidence: 99%

The least squares reverse time migration in frequency domain

Lv¹,

Xu²

2015

Proceedings of the 2015 International Conference on Mechatronics, Electronic, Industrial and Control Engineering

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Section: Domainmentioning

confidence: 99%

The least squares reverse time migration in frequency domain

Lv¹,

Xu²

2015

Proceedings of the 2015 International Conference on Mechatronics, Electronic, Industrial and Control Engineering

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“…For the marine case, where impulsive sources do not easily allow for signal coding, Beasley et al (1998) propose to fire such sources simultaneously with large distances between them. See also Vaage (2002), Ikelle (2007), Hampson et al (2008), and Howe et al (2008), where temporal jitter between the sources is added optionally. Note that for a densely sampled source configuration, jitter-free simultaneous shooting (equal firing times) becomes plane wave acquisition (Taner, 1976).…”

Section: Introductionmentioning

confidence: 99%

Multiscattering illumination in blended acquisition

2012

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In traditional seismic surveys, the firing time between shots is such that the shot records do not interfere in time. However, in the concept of blended acquisition, the records do overlap, allowing denser source sampling and wider azimuths in an economic way. A denser shot sampling and wider azimuths make that each subsurface gridpoint is illuminated from a larger number of angles and will therefore improve the image quality in terms of signal-to-noise ratio and spatial resolution. We show that -even with very simple blending parameters like time delays -the incident wavefield at a specific subsurface gridpoint represents a dispersed time series with a "complex code". For shot-record migration purposes, this time series must have a stable inverse. In a next step, we show that the illumination can be further improved by utilizing the surface-related multiples. This means that these multiples can be exploited to improve the incident wavefield by filling angle gaps in the illumination and/or by extending the range of angles. In this way, the energy contained in the multiples now contributes to the image, rather than decreasing its quality. One remarkable consequence of this property is that the benefits to be obtained from the improved illumination depend on the detector locations in acquisition geometries as well. We show how to quantify the contribution of the blended surface multiples to the illuminating wavefield for a blended source configuration. Results confirm that the combination of blending and multiple scattering increases the illumination energy and, therefore, will improve the quality of shot-record migration results beyond today's capability.

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“…On the other hand, in blended-source seismic data acquisition (also called simultaneous source acquisition), the time interval between firing two or more shots is relatively small, and therefore, the wavefields recorded have interference noise. Blended acquisition (Beasley et al, 1998;Bagaini, 2006;Ikelle, 2007;Stefani et al, 2007;Berkhout, 2008;Berkhout et al, 2008;Blacquiere et al, 2009) in the surface seismic case is slowly becoming a routine practice in the oil and gas industry. Blending in surface seismic has made huge 3D surveys possible within economical survey times.…”

Section: Introductionmentioning

confidence: 99%

Imaging blended vertical seismic profiling data using full-wavefield migration in the common-receiver domain

Soni

Verschuur

2015

GEOPHYSICS

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For vertical-seismic-profiling (VSP) measurements, the use of blended acquisition, with time-overlapping shot records, can greatly reduce the downtime and, thereby, provide large cost savings. For directly imaging blended VSP measurements, we have used full-wavefield migration (FWM). FWM is an inversion-based imaging scheme that enables us to use any kind of complex source wavefield to estimate the subsurface reflectivity, using all the multiples (surface and internal) in the recorded data. The multiple scattering helps in improving the illumination as well as the vertical resolution of the image. In this scheme, active deblending is not required because the imaging process itself acts as a deblending procedure. We tested the potential of FWM to image blended VSP data, using simple and complex synthetic models. We clearly determined that using the primaries, surface multiples, and internal multiples enhanced the illumination away from the well trajectory, in which blending noise was suppressed due to the inversion scheme. We observed that some blending crosstalk noise leaked into the images with large blending factors. Such noise could be further reduced with additional constraints in the involved least-squares inversion process.

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Coding and decoding: Seismic data modeling, acquisition and processing

Cited by 55 publications

References 2 publications

The least squares reverse time migration in frequency domain

The least squares reverse time migration in frequency domain

Multiscattering illumination in blended acquisition

Imaging blended vertical seismic profiling data using full-wavefield migration in the common-receiver domain

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