Identification of multiples contamination in seismic images

Patent metadata

Field	Value
Publication number	US-9500759-B2
Application number	US-201314050750-A
Country	US
Kind code	B2
Filing date	Oct 10, 2013
Priority date	Mar 4, 2013
Publication date	Nov 22, 2016
Grant date	Nov 22, 2016

Abstract

Methods, systems, and computer-readable media for identifying multiples contamination in a stack are provided. The method includes identifying spatially an area of potential multiples contamination in the stack. The method also includes constructing, using a processor, a model of multiples contamination using well data, and evaluating a degree of contamination in the area of potential contamination using the model of multiples contamination. The method further includes attenuating multiples contamination in the areas of multiples contamination, and validating the stack after attenuating.

First claim

What is claimed is:

1. A method for identifying multiples contamination in a stack, comprising:
determining, based on a sectional representation of a seismic image including a first layer and a second layer that are located at different depths from one another, that a signal representing reflection at the first layer potentially generates a multiples contamination in a contaminated portion of a signal representing reflection at the second layer;
matching an area of potential multiples contamination in an areal representation of the second layer with the contaminated portion of the signal representing reflection at the second layer in the sectional representation, wherein matching the area in the areal representation comprises:
determining a characteristic of the contaminated portion of the signal representing reflection in the second layer; and
determining the area as being where a plurality of signals representing reflection in the second layer exhibit the characteristic;

constructing, using a processor, a model of multiples contamination using well data;
evaluating a degree of contamination in the area of potential multiples contamination based on the model of multiples contamination;
attenuating multiples contamination in the area of potential multiples contamination; and
validating the stack after attenuating.

2. The method of claim 1 , wherein validating the stack comprises comparing two or more partial stacks with multiples contamination attenuated.

3. The method of claim 1 , further comprising ruling out fluid effects using amplitude variation with offset (AVO) modeling.

4. The method of claim 1 , wherein validating the stack comprises comparing the area of potential multiples contamination with one or more areas expected to include multiples contamination.

5. The method of claim 1 , wherein constructing the model of multiples contamination further comprises determining whether one or more multiples interfere constructively or destructively with the signal representing the second layer.

6. The method of claim 1 , wherein constructing the model of multiples contamination further comprises modeling multiples generated in an overburden to determine expected characteristics of the signal representing the second layer.

7. The method of claim 1 , wherein matching the area of potential multiples contamination comprises:
flattening the first layer;
determining that flattening the first layer causes the contaminated portion of the signal representing the second layer to be flattened; and
marking areas spatially proximal to the portions of the signal representing the second layer that are flattened, in the areal view of the second layer.

8. The method of claim 7 , further comprising determining that the first and second layers are not seismically conformable.

9. The method of claim 8 , wherein determining that the first and second layers are not seismically conformable comprises establishing a tuning thickness, wherein determining that a depth difference between two layers that is less than the tuning thickness is indicative of the two layers being seismically conformable.

10. The method of claim 1 , wherein the characteristic is selected from the group consisting of: amplitude dimming, amplitude burst, and a change in polarity.

11. The method of claim 1 , further comprising extrapolating the area to a larger area, based at least partially on the characteristic.

12. The method of claim 11 , wherein the extrapolating is performed without repeating determining that the signal representing reflection in the first layer potentially generates the multiples contamination in the contaminated portion of the signal representing reflection at the second layer.

13. A computing system, comprising:
a processor; and
a memory system including one or more computer readable media storing instructions that, when executed by the processor, are configured to cause the computing system to perform operations, the operations comprising:
determining, based on a sectional representation of a seismic image including a first layer and a second layer that are located at different depths from one another, that a signal representing reflection at the first layer potentially generates a multiples contamination in a contaminated portion of a signal representing reflection at the second layer;
identifying an area of potential multiples contamination in an areal representation of the second layer based on the determination of the contaminated portion of the signal representing reflection at the second layer in the sectional representation, wherein identifying the area in the areal representation comprises:
determining a characteristic of the contaminated portion of the signal representing reflection in the second layer;
determining the area as being where a plurality of signals representing reflection in the second layer exhibit the characteristic; and
extrapolating the identified area to a larger area, based at least partially on the characteristic;

constructing a model of multiples contamination using well data;
evaluating a degree of contamination in the area of potential multiples contamination based on the model of multiples contamination;
attenuating multiples contamination in the area of potential multiples contamination; and
validating the stack after attenuating.

14. The system of claim 13 , wherein validating the stack comprises comparing results for two or more partial stacks.

15. The system of claim 13 , further comprising ruling out fluid effects using amplitude variation with offset (AVO) modeling.

16. The system of claim 13 , wherein validating the stack comprises comparing the area of potential multiples contamination with one or more areas expected to include multiples contamination.

17. The system of claim 13 , wherein constructing the model of multiples contamination further comprises determining whether one or more multiples interfere constructively or destructively with the signal representing the second layer.

18. The system of claim 13 , wherein constructing the model of multiples contamination further comprises modeling multiples generated in an overburden to determine expected characteristics of the signal representing the second layer.

19. The system of claim 13 , wherein identifying the area of potential multiples contamination comprises:
flattening the first layer;
determining that flattening the first layer causes the contaminated portion of the signal representing the second layer to be flattened; and
marking areas spatially proximal to the portions of the signal representing the second layer that are flattened, in the areal view of the second layer.

20. The system of claim 19 , further comprising determining that the first and second layers are not seismically conformable, wherein determining that the first and second layers are not seismically conformable comprises establishing a tuning thickness, wherein determining that a depth difference between two layers that is less than the tuning thickness is indicative of the two layers being seismically conformable.

21. A non-transitory computer-readable medium storing instructions that, when executed by a processor of a computing system, are configured to cause the computing system to perform operations, the operations comprising:
determining, based on a sectional representation of a seismic image including a first layer and a second layer that are located at different depths from one another, that a signal representing reflecti

Assignees

• Schlumberger Technology Corp

Inventors

• Srigiriraju Ramachandra

Classifications

• G01V1/362

  Effecting static or dynamic corrections; Stacking · CPC title

• G01V1/364 Primary

  Seismic filtering (G01V1/37 takes precedence) · CPC title

• G01V2210/56

  De-ghosting; Reverberation compensation · CPC title