Methods for simultaneous source separation

Patent metadata

Field	Value
Publication number	US-11294088-B2
Application number	US-202016833975-A
Country	US
Kind code	B2
Filing date	Mar 30, 2020
Priority date	Dec 18, 2014
Publication date	Apr 5, 2022
Grant date	Apr 5, 2022

Abstract

A multi-stage inversion method for deblending seismic data includes: a) acquiring blended seismic data from a plurality of seismic sources; b) constructing an optimization model that includes the acquired blended seismic data and unblended seismic data; c) performing sparse inversion, via a computer processor, on the optimization model; d) estimating high-amplitude coherent energy from result of the performing sparse inversion in c); e) re-blending the estimated high-amplitude coherent energy; and f) computing blended data with an attenuated direct arrival energy.

First claim

The invention claimed is:

1. A method for seismic data acquisition, the method comprising:
obtaining blended seismic data, the blended seismic data acquired by a plurality of seismic receivers deployed in a survey area based on seismic energy emitted by one or more seismic sources;
generating an approximation of deblended seismic data using at least one processor, the approximation of deblended seismic data generated by performing a first stage of sparse inversion in a multi-stage inversion on an optimization model relating the blended seismic data to deblended seismic data;
generating first-break attenuation data by attenuating a portion of energy from the approximation of deblended seismic data; and
generating the deblended data by performing a second stage of sparse inversion in the multi-stage inversion on the first-break attenuation data.

2. The method of claim 1 , wherein the multi-stage inversion is iteratively repeated.

3. The method of claim 1 , wherein the blended seismic data is acquired through non-uniform optimal sampling.

4. The method of claim 1 , wherein the one or more seismic sources have non-uniform spacing.

5. The method of claim 1 , wherein the plurality of seismic receivers are non-uniformly spaced in the survey area.

6. The method of claim 1 , wherein the optimization model relates a continuous record containing the blended seismic data from all of the one or more seismic sources over a period of time to a set of traces of the deblended seismic data each recording the seismic energy from a single seismic source of the one or more seismic sources.

7. The method of claim 1 , wherein the optimization model relates the blended seismic data to the deblended seismic data using a blending operator containing timing information describing overlap of the one or more seismic sources.

8. The method of claim 7 , wherein the optimization model further includes a restriction operator relating irregular locations of the one or more seismic sources in the survey area to regular locations of the one or more seismic sources after the multi-stage inversion.

9. The method of claim 8 , wherein the restriction operator is constructed based on spatial information using interpolated comprehensive sensing.

10. The method of claim 1 , wherein the portion of energy attenuated from the approximation of deblended seismic data includes high-amplitude coherent energy.

11. A method for seismic data acquisition, the method comprising:
obtaining blended seismic data, the blended seismic data acquired by a plurality of seismic receivers deployed in a survey area based on seismic energy emitted by a plurality of seismic sources, the plurality of seismic sources being deployed in the survey area at irregular locations according to a non-uniform survey;
generating an approximation of deblended seismic data using at least one processor, the approximation of deblended seismic data generated by performing a first stage of sparse inversion in a multi-stage inversion on an optimization model relating the blended seismic data to deblended seismic data and relating the irregular locations of the plurality of seismic sources in the survey area to regular locations of the plurality of seismic sources after the multi-stage inversion; and
generating the deblended data by performing a second stage of sparse inversion in the multi-stage inversion on the approximation of deblended seismic data with attenuated energy.

12. The method of claim 11 , wherein the attenuated energy includes high-amplitude coherent energy, the high-amplitude coherent energy being estimated and re-blended based on source time information prior to an attenuation of the high-amplitude coherent energy from the approximation of deblended seismic data, the second stage of sparse inversion in the multi-stage inversion performed after the attenuation of the high-amplitude coherent energy from the approximation of deblended seismic data.

13. The method of claim 11 , wherein the multi-stage inversion is iteratively repeated.

14. The method of claim 11 , wherein the first stage of sparse inversion utilizes a nonmonotone alternating direction method.

15. The method of claim 11 , wherein the non-uniform survey further includes at least one of the plurality of seismic receivers or the plurality seismic sources being deployed with non-uniform spacing.

16. The method of claim 11 , wherein the optimization model relates the blended seismic data to the deblended seismic data using a blending operator that blends the seismic energy from the plurality of seismic sources into one trace for each seismic receiver of the plurality of seismic receivers, the blending operator being constructed based on timing information.

17. A method for seismic data acquisition, the method comprising:
obtaining blended seismic data, the blended seismic data acquired by a plurality of seismic receivers deployed in a survey area based on seismic energy emitted by a plurality of seismic sources in a simultaneous source survey, the blended seismic data including blending noise from the simultaneous source survey;
obtaining an optimization model relating the blended seismic data to deblended seismic data using a blending operator containing timing information describing overlap of the plurality of seismic sources in the simultaneous survey; and
generating the deblended seismic data by jointly deblending and reconstructing the blended seismic data through a sparse inversion on the optimization model and an attenuation of high-amplitude coherent energy, the sparse inversion and the attenuation removing at least a portion of the blending noise.

18. The method of claim 17 , wherein the sparse inversion involves a multi-stage inversion that is iteratively repeated.

19. The method of claim 17 , wherein the blended seismic data is acquired through non-uniform optimal sampling.

20. The method of claim 17 , wherein the high-amplitude coherent energy includes at least one of direct arrival energy, ground roll, mud roll, multiples, near-surface scattering, topographic scattering, permafrost noise, platform noise, or nearby survey noise.

Assignees

• Conocophillips Co

Inventors

• Li Chengbo
• Mosher Chuck
• Ji Leo
• Brewer Joel

Classifications

• G01V1/364 Primary

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

• G01V2210/127

  Cooperating multiple sources · CPC title

• G01V2210/57

  Trace interpolation or extrapolation, e.g. for virtual receiver; Anti-aliasing for missing receivers · CPC title

• G01V1/282

  Application of seismic models, synthetic seismograms · CPC title

• G01V1/368 Primary

  Inverse filtering · CPC title