Migration velocity analysis method for VSP data

Patent metadata

Field	Value
Publication number	US-9804281-B2
Application number	US-201414651909-A
Country	US
Kind code	B2
Filing date	Feb 28, 2014
Priority date	Mar 22, 2013
Publication date	Oct 31, 2017
Grant date	Oct 31, 2017

Abstract

Vertical Seismic Profile (VSP) analysis is a technique commonly used to conduct geophysical surveys of subterranean features. The processing of a VSP includes several steps, usually including a final step of depth migration. In order to properly process and image VSP data using depth migration, a velocity model of the subsurface must be known or derived. A variety of criteria can be used to ascertain whether the velocity used for migration is accurate.

First claim

What is claimed is:

1. A method of processing vertical seismic profile data comprising:
obtaining vertical seismic profile data for each of at least two geophones;
performing a depth migration to image the vertical seismic profile data, comprising:
migrating the vertical seismic profile data of each geophone using a velocity model to produce migrated data for each geophone;
stacking the migrated data of each geophone to produce a stacked migrated trace having one or more events for each geophone;
determining a first degree of accuracy of the velocity model based on at least one of the following characteristics:
a flatness of each event in the migrated traces,
a complexity of each event in the migrated traces, a curvature of each event in the migrated traces, and
an alignment of peak amplitudes of the events in the migrated traces; and

selecting at least a portion of the vertical seismic profile data based on the degree of accuracy determination;

performing a simulated time migration to estimate velocity updates, comprising:
deteanining data related to a residual moveout corresponding to the portion of the vertical seismic profile data, based on one or more arrival time values and a first trial velocity value;
detemiining a second degree of accuracy of the first trial velocity value;
selecting a second trial velocity value based on the second degree of accuracy of the first velocity value;
determining an interval velocity based on the second trial velocity value; and
updating the velocity model based on the second trial velocity value; and

repeating the depth migration and the simulated time migration until the first degree of accuracy exceeds a pre-determined value wherein the method is performed by a control module and the velocity model is used to create an accurate image of a subsurface reservoir proximate to a wellbore during drilling or operation of a well.

2. The method of claim 1 , further comprising iteratively determining the degree of accuracy of the second trial velocity value.

3. The method of claim 1 , wherein the arrival time value corresponds to the portion of the vertical seismic profile data.

4. The method of claim 1 , wherein determining the second degree of accuracy comprises determining one or more stationary phase points corresponding to the vertical seismic profile data migrated by the first velocity value.

5. The method of claim 4 , wherein the stationary phase points correspond to a depth prediction.

6. The method of claim 5 , wherein the second degree of accuracy is determined based on a similarity between two or more stationary phase points.

7. The method of claim 6 , wherein the one or more stationary phase points are determined based on a point of intersection between a trajectory of a migration sweep and a line corresponding to a common image gather location.

8. The method of claim 7 , wherein the trajectory of the migration sweep in two spatial dimensions is an ellipse.

9. The method of claim 7 , wherein the trajectory of the migration sweep in three spatial dimensions is an ellipsoid.

10. The method of claim 1 , wherein the first trial velocity value is a user selected value.

11. The method of claim 1 , wherein the first trial velocity value is based on pre-determined information about the vertical seismic profile data.

12. A system comprising:
at least one seismic source for directing seismic energy towards a subterranean region during operation of the system;
at least two geophones each for obtaining vertical seismic profile data during operation of the system; and
a control module programmed to:
perform a depth migration to image the vertical seismic profile data, comprising:
migrating the vertical seismic profile data of each geophone using a velocity model to produce migrated data for each geophone;
stacking the migrated data of each geophone to produce a stacked migrated trace having one or more events for each geophone;
determining a first degree of accuracy of the velocity model based on at least one of the following characteristics:
a flatness of each event in the migrated traces,
a complexity of each event in the migrated traces,
a curvature of each event in the migrated traces, and
an alignment of peak amplitudes of the events in the migrated traces; and

selecting at least a portion of the vertical seismic profile data based on the degree of accuracy estimation;

perform a simulated time migration to estimate velocity updates, comprising:
determining data related to a residual moveout corresponding to the portion of the vertical seismic profile data, based on one or more arrival time values and a first trial velocity value;
determining a second degree of accuracy of the first trial velocity value;
selecting a second trial velocity value based on the second degree of accuracy of the first velocity value;
determining an interval velocity based on the second trial velocity value; and
updating the velocity model based on the second trial velocity value; and

repeating the depth migration and simulated time migration until the first degree of accuracy exceeds a pre-determined value wherein the velocity model is used to create an accurate image of a subsurface reservoir proximate to a wellbore during drilling or operation of a well.

13. The system of claim 12 , wherein the at least one seismic source is disposed on a surface of the subterranean region.

14. The system of claim 12 , wherein the at least one seismic source is disposed beneath a surface of the subterranean region.

15. The system of claim 12 , wherein the geophones are disposed beneath a surface of the subterranean region.

16. The system of claim 15 , wherein the geophones are disposed within a wellbore defined in the subterranean region.

17. The system of claim 12 , where the geophones are disposed on a surface of the subterranean region.

Assignees

• Halliburton Energy Services Inc

Inventors

• Willis Mark E
• Du Yue

Classifications

• G01V1/303 Primary

  for determining velocity profiles or travel times · CPC title

• G01V1/42

  using generators in one well and receivers elsewhere or vice versa (G01V1/52 takes precedence) · CPC title

• G01V2210/161

  Vertical seismic profiling [VSP] · CPC title

• G01V2210/51

  Migration · CPC title