Data acquisition and prestack migration based on seismic visibility analysis

• US 9,329,288 B2
• Filed: 01/19/2009
• Issued: 05/03/2016
• Est. Priority Date: 01/19/2009
• Status: Active Grant

• Current Assignee: Landmark Graphics Corporation (Halliburton Company)
• Original Assignee: Landmark Graphics Corporation (Halliburton Company)
• Inventors: Xu, Shiyong, Jin, Shengwin
• Primary Examiner(s): Ratcliffe, Luke
• Assistant Examiner(s): Ndure Jobe, Amienatta M
• Application Number:
  US13/142,478
• Publication Number:
  US 20110273959A1
• Time in Patent Office: 2,661 Days
• Field of Search: 345/419, 345/169, 356/437, 367/38, 367 50- 73, 606/182, 702 14- 18, 703/2
• US Class Current: 1/1
• CPC Class Codes: G01V 1/003 Seismic data acquisition in general, e.g. survey design G01V1/3808, G01V1/42 take precedence
• CPC Class Codes: G01V 1/30 Analysis G01V1/50 takes precedence
• CPC Class Codes: G01V 1/345 Visualisation of seismic data or attributes, e.g. in 3D cubes
• CPC Class Codes: G01V 20/00 Geomodelling in general
• CPC Class Codes: G01V 2210/67 Wave propagation modeling
• CPC Class Codes: G01V 2210/673 Finite-element; Finite-difference
• CPC Class Codes: G01V 2210/675 Wave equation; Green's functions
• CPC Class Codes: G01V 2210/679 Reverse-time modeling or coalescence modelling, i.e. starting from receivers

Abstract

Seismic visibility analysis of selected subsurface structures is employed to determine surface locations offering high visibility of target events. These locations can then be used as a basis for acquiring additional seismic survey data and/or selecting existing traces for re-migration with more sophisticated migration methods. With either usage, the newly migrated data is expected to offer enhanced images of the target event. In some embodiments, the visibility determination includes using a wave equation based propagator to find, for each of multiple simulated shots, a reflection wavefield from the target event in a seismic model; and to calculate, for each of multiple receiver positions, a contribution signal from each reflection wavefield. The visibility determination further includes converting each contribution signal into a source-receiver visibility value. Because data acquisition and/or re-migration is limited to the selected region, the imaging effort for the target event is significantly reduced.

Claims

1. A seismic survey method that comprises:

determining visibility values of a target event as a function of seismic source and receiver positions, wherein said determining the visibility values of a target event includes;

finding, for each of multiple simulated shots, a reflection wavefield from the target event in a seismic model;

calculating, for each of multiple receiver positions, a contribution signal from each reflection wavefield; and

converting each contribution signal into a source-receiver visibility value that indicates an energy intensity of a respective contribution signal;

acquiring seismic data using a source-receiver geometry selected at least in part to include source and receiver positions associated with visibility values above a threshold; and

imaging the target event based on the acquired seismic data.

2. The method of claim 1, wherein the seismic model is determined based at least in part on migrated data from a seismic survey.

3. The method of claim 1, wherein the target event is a subsurface feature that is selected by a user as being inadequately imaged.

4. The method of claim 1, wherein at least one of the visibility values is an integrated square of the contribution signal.

5. The method of claim 1, wherein the threshold is selected to capture a predetermined fraction of the area under a multidimensional visibility function associated with the visibility values.

6. A seismic migration method that comprises:

determining visibility values of a target event at the source and receiver positions of traces in an existing seismic survey, wherein said determining the visibility values of a target event includes;

finding, for each of multiple simulated shots, a reflection wavefield from said target event in a seismic model;

calculating, for each of multiple receiver positions, a contribution signal from each reflection wavefield; and

converting each contribution signal into a source-receiver visibility value that indicates an energy intensity of a respective contribution signal;

re-migrating traces associated with visibility values above a threshold to generate an image of the target event; and

displaying the image of the target event on a user interface.

7. The method of claim 6, wherein the seismic model is determined based at least in part on migrated data from the existing seismic survey, wherein said migrated data is obtained using a first migration method.

8. The method of claim 6, wherein said converting includes determining an integrated square of the contribution signal.

9. The method of claim 7, wherein said visibility values are determined using a second migration method different than the first migration method.

10. The method of claim 7, wherein said re-migration is performed using a second migration method different than the first migration method.

11. The method of claim 6, wherein the target event is a subsurface feature that is selected by a user as being inadequately imaged.

12. The method of claim 6, wherein the threshold is selected to capture a predetermined fraction of the area under a visibility function associated with the visibility values.

13. A visibility analysis system that comprises:

a memory that stores visibility analysis software; and

at least one processor coupled to the memory to execute the visibility analysis software, wherein the software configures the at least one processor to;

determine, for each of multiple shots, a reflection wavefield from at least one target event in a seismic model;

calculate, for each of multiple receiver positions, a contribution signal from each reflection wavefield;

convert each contribution signal into a source-receiver visibility value that indicates an energy intensity of a respective contribution signal;

process seismic data acquired using a source-receiver geometry selected at least in part to include source and receiver positions associated with source-receiver visibility values above a threshold to generate an image of the at least one target event, or re-migrate traces associated with source-receiver visibility values above a threshold to generate an image of the at least one target event; and

display an image of the target event on a user interface.

14. The system of claim 13, wherein the software further configures the processor to visually map visibility as a function of at least one of source position and receiver position.

15. The system of claim 13, wherein the seismic model is determined based at least in part on migrated data from a seismic survey, wherein said migrated data is obtained using a first migration method.

16. The system of claim 15, wherein said source-receiver visibility values are determined using a second migration method different than the first migration method.

17. The system of claim 13, wherein the software further configures the processor to identify traces from an existing seismic survey for re-migration with an enhanced migration method, wherein the traces are identified based at least in part on their source-receiver visibility values.

18. The system of claim 13, wherein the software further configures the processor to identify source and receiver positions for additional seismic data acquisition, wherein said positions are identified based at least in part on source-receiver visibility values.