WAVSEIS sourcing

Patent metadata

Field	Value
Publication number	US-10379236-B2
Application number	US-201615215229-A
Country	US
Kind code	B2
Filing date	Jul 20, 2016
Priority date	Jul 22, 2015
Publication date	Aug 13, 2019
Grant date	Aug 13, 2019

Abstract

Improved methods of providing acoustic source signals for seismic surveying, wherein a plurality of signals can be easily separated from one another after data acquisition, wherein the source signals are not sweep based.

First claim

The invention claimed is:

1. A method of acquiring seismic survey data for a reservoir, the method comprising:
providing one or more vibratory sources, each of the one or more vibratory sources being electric or hydraulic and providing a different seismic source signal pattern p (p 1 , p 2 . . . p n ), having a length t (t 1 , t 2 . . . t n ), each of the different seismic source signal patterns (p 1 , p 2 . . . p n ) comprising a plurality of frequencies and a plurality of amplitudes, wherein the plurality of frequencies and the plurality of amplitudes do not vary sequentially;
confirming that the different seismic source signal patterns (p 1 , p 2 . . . p n ) do not substantially overlap such that the different seismic source signal patterns can be separated from each other;
changing at least a portion of the different seismic source signal patterns if the different seismic source signal patterns cannot be separated from each other and repeating confirmation that the different seismic source signal patterns do not substantially overlap;
delivering acoustic energy into the reservoir using the one or more vibratory sources, the acoustic energy delivered according to the different seismic source signal patterns;
acquiring reflected and refracted seismic signal data at one or more receivers following delivery of the acoustic energy;
separating the reflected and refracted seismic signal data according to each of the different seismic source signal patterns into separated seismic data; and
processing the separated seismic data to create a seismic survey.

2. The method of claim 1 , wherein confirming that the different seismic source signal patterns do not substantially overlap includes cross-correlating pairs of the different seismic source signal patterns.

3. The method of claim 2 , wherein changing at least a portion of the different seismic source signal patterns includes changing one of the different seismic source signal patterns within each of the pairs to maximize separability.

4. The method of claim 1 , wherein the reflected and refracted seismic signal data is separated using inversion.

5. The method of claim 1 , wherein the reflected and refracted seismic signal data is separated using an iterative adaptive subtraction method.

6. A method of surveying a reservoir, the method comprising:
providing one or more electric vibratory sources near a reservoir, each of the electric vibratory sources providing a different acoustic signal pattern p (p 1 , p 2 . . . p n ), having a length t (t 1 , t 2 . . . t n ), each of the different acoustic signal patterns (p 1 , p 2 . . . p n ) comprising a plurality of frequencies and a plurality of amplitudes having a rhythm, wherein the plurality of frequencies and the plurality of amplitudes do not vary sequentially for more than 6 notes over length t;
confirming by cross correlation that the different acoustic signal patterns (p 1 , p 2 . . . p n ) do not substantially overlap such that the different acoustic signal patterns can be separated from each other
altering at least one of the different acoustic signal patterns to maximize a separability of the different acoustic signal patterns;
delivering acoustic energy into the reservoir using the one or more electric vibratory sources, the acoustic energy delivered according to the different acoustic signal patterns;
acquiring reflected and refracted signal data at one or more receivers following delivery of the acoustic energy;
separating the reflected and refracted signal data according to the different acoustic signal patterns to produce separated data;
processing the separated data to produce processed data; and
displaying a graphical representation of the reservoir based on the processed data.

7. The method of claim 6 , wherein the reflected and refracted signal data is separated using inversion.

8. The method of claim 6 , wherein the reflected and refracted signal data is separated using an iterative adaptive subtraction method.

9. The method of claim 6 , wherein the different acoustic signal patterns are applied to the reservoir simultaneously during delivery of the acoustic energy.

10. The method of claim 6 , wherein the different acoustic signal patterns are applied to the reservoir sequentially during delivery of the acoustic energy.

11. A method of acquiring seismic survey data for a reservoir, the method comprising:
obtaining reflected and refracted seismic signal data, the reflected and refracted seismic signal data captured using one or more receivers following a delivery of acoustic energy into the reservoir using one or more vibratory sources, each of the one or more vibratory sources providing a different seismic source signal pattern having a length, each of the different seismic source signal patterns comprising a plurality of non-sequentially varying frequencies, the different seismic source signal patterns not substantially overlapping such that the different seismic source signal patterns are separable from each other;
separating the reflected and refracted seismic signal data according to each of the different seismic source signal patterns into separated seismic data; and
processing the separated seismic data to create a seismic survey.

12. The method of claim 11 , wherein pairs of the different seismic source signal patterns are cross correlated to confirm that the different seismic source signal patterns are not substantially overlapping.

13. The method of claim 12 , wherein at least a portion of the different seismic source signal patterns is changed if the different seismic source signal patterns are not substantially overlapping.

14. The method of claim 13 , wherein changing at least a portion of the different seismic source signal patterns includes changing one of the different seismic source signal patterns within each of the pairs to maximize separability.

15. The method of claim 11 , wherein the reflected and refracted seismic signal data is separated using inversion.

16. The method of claim 11 , wherein the reflected and refracted seismic signal data is separated using an iterative adaptive subtraction method.

17. The method of claim 11 , wherein the different seismic source signal patterns are applied to the reservoir simultaneously during delivery of the acoustic energy.

18. The method of claim 11 , wherein the different seismic source signal patterns are applied to the reservoir sequentially during delivery of the acoustic energy.

19. The method of claim 11 , wherein the plurality of non-sequentially varying frequencies includes a frequency of the different seismic source signal patterns not varying over more than 6 notes.

20. The method of claim 11 , wherein the different seismic source signal patterns not substantially overlapping includes the different seismic source signal patterns not substantially overlapping in at least one of: timbre, amplitude, phase, or harmonics for a plurality of notes.

21. The method of claim 20 , wherein the plurality of notes is 4 notes.

22. A method of acquiring seismic survey data for a reservoir, the method comprising:
obtaining a plurality of different seismic source signal patterns having a length, each of the plurality of different seismic source signal patterns simultaneously deliverable into the reservoir as acoustic energy using a respective vibratory source, each of the plurality of different seismic source signal patterns comprising a plurality of non-sequentially varying frequencies;
changing

Assignees

• Conocophillips Co

Inventors

• Eick Peter M
• Brewer Joel D

Classifications

• G01V1/37

  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} · CPC title

• G01V1/143

  using mechanical driving means {, e.g. motor driven shaft}(G01V1/104, G01V1/133 take precedence) · CPC title

• G01V1/005 Primary

  with exploration systems emitting special signals, e.g. frequency swept signals, pulse sequences or slip sweep arrangements · CPC title

• G01V2210/1295

  Land surface · CPC title

• G01V2210/1214

  Continuous · CPC title