High-frequency processing of seismic vibrator data

• US 20050122840A1
• Filed: 11/12/2004
• Published: 06/09/2005
• Est. Priority Date: 11/14/2003
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (SLB)
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Haldorsen, Jakob B. U.
• Granted Patent: US 7,508,733 B2
• Time in Patent Office: Days
• US Class Current: 367/57
• CPC Class Codes: G01V 1/37 specially adapted for seismic systems using continuous agitation of the ground , e.g. using pulse compression of frequency swept signals for enhancement of received signals

Abstract

A method of processing seismic data obtained using a seismic vibrator that includes estimating travel times of direct wave arrivals between the seismic vibrator and an array of seismic receiver locations and wavefield deconvolving the seismic data using the direct wave arrival travel times. Also a related method of producing a high-frequency geological subsurface image that includes acquiring seismic data having significant harmonic energy using a seismic vibrator, estimating direct wave arrival travel times between the seismic vibrator and an array of seismic receiver locations, wavefield deconvolving the seismic data using the estimated direct wave arrival travel times, and using the wavefield deconvolved seismic data to produce a high-frequency geological subsurface image. A further related computer useable medium having computer readable program code means embodied therein practicing the inventive method.

Claims

1. A method of processing seismic data obtained using a seismic vibrator, comprising:

estimating travel times of direct wave arrivals between said seismic vibrator and an array of seismic receiver locations; and

wavefield deconvolving said seismic data using said estimated direct wave arrival travel times.

2. A method in accordance with claim 1, wherein said travel times of direct wave arrivals between said seismic vibrator and said array of seismic receiver locations are estimated using said seismic data.

3. A method in accordance with claim 2, wherein estimating said travel times of direct wave arrivals between said seismic vibrator and said array of seismic receiver locations comprises correlating said seismic data with said seismic vibrator'"'"'s reference signal or an estimate of seismic vibrator'"'"'s actual source signature and picking first breaks/initial arrivals of seismic energy from said correlated seismic data.

4. A method in accordance with claim 1, wherein said wavefield deconvolution is semblance-weighted.

5. A method in accordance with claim 1, wherein said wavefield deconvolution comprises calculating an expectation value by a mean or a median operation.

6. A method in accordance with claim 5, wherein a median estimator is used having a spatial length of 7 traces.

7. A method in accordance with claim 1, wherein updated estimates of said travel times of direct wave arrivals between the seismic vibrator and an array of seismic receiver locations are obtained by picking first breaks/initial arrivals from said wavefield deconvolved seismic data and said updated estimates are used as input into a further wavefield deconvolving of said seismic data using said updated estimated direct wave arrival travel times.

8. A method in accordance with claim 1, further comprising removing direct wavefield energy from said wavefield deconvolved seismic data and displaying said data in two-way seismic travel time.

9. A method in accordance with claim 1, wherein said seismic data and surface seismic data are acquired simultaneously and a deconvolution operator determined during said wavefield deconvolving is used in processing said surface seismic data.

10. A method of producing a high-frequency geological subsurface image, comprising:

acquiring seismic data having significant harmonic energy using a seismic vibrator;

estimating direct wave arrival travel times between said seismic vibrator and an array of seismic receiver locations;

wavefield deconvolving said seismic data using said estimated direct wave arrival travel times; and

using said wavefield deconvolved seismic data to produce a high-frequency geological subsurface image.

11. A method in accordance with claim 10, wherein said travel times of direct wave arrivals between said seismic vibrator and said array of seismic receiver locations are estimated using said seismic data.

12. A method in accordance with claim 11, wherein estimating said travel times of direct wave arrivals between said seismic vibrator and said array of seismic receiver locations comprises correlating said seismic data with said seismic vibrator'"'"'s reference signal or an estimate of seismic vibrator'"'"'s actual source signature and picking first breaks/initial arrivals of seismic energy from said correlated seismic data.

13. A method in accordance with claim 10, wherein said wavefield deconvolution is semblance-weighted.

14. A method in accordance with claim 10, wherein said wavefield deconvolution comprises calculating an expectation value by a median operation and a median estimator is used having a spatial length of 7 traces.

15. A method in accordance with claim 10, wherein updated estimates of said travel times of direct wave arrivals between the seismic vibrator and an array of seismic receiver locations are obtained by picking first breaks/initial arrivals from said wavefield deconvolved seismic data and said updated estimates are used as input into a further wavefield deconvolving of said seismic data using said updated estimated direct wave arrival travel times.

16. A method in accordance with claim 10, further comprising removing direct wavefield energy from said wavefield deconvolved seismic data and displaying said data in two-way seismic travel time.

17. A method in accordance with claim 10, wherein said seismic data and surface seismic data are acquired simultaneously and a deconvolution operator determined during said wavefield deconvolving is used in processing said surface seismic data.

18. An article of manufacture, comprising:

a computer useable medium having computer readable program code means embodied therein for processing seismic data obtained using a seismic vibrator, the computer readable program code means in said article of manufacture comprising;

computer readable program means for estimating travel times of direct wave arrivals between said seismic vibrator and an array of seismic receiver locations; and

computer readable program means for wavefield deconvolving said seismic data using said estimated direct wave arrival travel times.