Anisotropic depth velocity model estimation above the receiver array in walkaway or 3D VSP data

• US 8,407,007 B2
• Filed: 11/24/2009
• Issued: 03/26/2013
• Est. Priority Date: 12/02/2008
• Status: Expired due to Fees

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Blias, Emanouil
• Primary Examiner(s): Barbee, Manuel L
• Application Number:
  US12/625,152
• Publication Number:
  US 20100133010A1
• Time in Patent Office: 1,218 Days
• Field of Search: 702/6, 702 11-134, 181/108, 181/11, 181/112, 367/14, 367/25, 367/27, 367/36, 367/38, 367/68
• US Class Current: 702/11
• CPC Class Codes: G01V 1/42 using generators in one well and receivers elsewhere or vice versa G01V1/52 takes precedence

Abstract

A walkaway VSP survey is carried out using a receiver array. Using a vertical VSP survey and arrival times of surface multiples on the walkaway VSP, vertical interval velocities and the anisotropy parameters δ and ε are estimated. This may then be used to process surface seismic data to do a prestack depth migration of surface seismic data and used for interpretation. For multi-azimuthal walkaway or 3D VSP data, we determine two VTI parameters ε and δ for multi-azimuth vertical planes. Then we determine five anisotropic interval parameters that describe P-wave kinematics for orthorhombic layers. These orthorhombic parameters may then be used to process surface seismic data to give a stacked image in true depth and for the interpretation purposes.

Claims

1. A method of evaluating an earth formation, the method comprising:

deploying an array of seismic receivers in a borehole and recording seismic signals in the array of receivers responsive to an activation of at least one seismic source on the surface of the earth at at least one location offset from the borehole;

estimating, using at least one processor, from travel times of seismic waves from the at least one location that have been reflected at an interface in the earth formation and the surface of the earth to the plurality of receivers, a velocity model including velocities of vertically propagating seismic waves in a plurality of intervals, and an anellipticity parameter related to a normal moveout velocity of compressional waves for the plurality of intervals; and

using the estimated velocity model for producing an image of the earth formation above the array of seismic receivers.

2. The method of claim 1 wherein the at least one location further comprises at least one additional location close to the borehole, the method further comprising:

using travel times of seismic waves to the plurality of receivers from at least one additional location and the velocity model to provide an updated velocity model including at least two anisotropy parameters related to a normal moveout curve of compressional waves for the plurality of intervals.

3. The method of claim 2 further comprising:

using the updated velocity model for producing an image of the earth formation; and

using the produced image for drilling operations.

4. The method of claim 2 wherein the at least one location comprises a plurality of locations defining a multi-azimuthal walkaway geometry, and the at least two anisotropy parameters further comprise five orthorhombic anisotropy parameters ε

₁, ε

₁, δ

₁, δ

₂ and δ

₃ related to a normal moveout velocity of compressional waves for the plurality of intervals.

5. The method of claim 2 further comprising estimating one of the at least two anisotropy parameters by approximating a moveout function representing the travel times by a shifted parabola.

6. The method of claim 1 further comprising using the produced image for drilling operations.

7. The method of claim 1 further comprising, using, for at least one of the plurality of seismic receivers, 3-component receivers.

8. The method of claim 1 further comprising deploying the plurality of seismic receivers on a conveyance device selected from:

(i) a wireline, (ii) a pipe, and (iii) coiled tubing.

9. A system configured to evaluate an earth formation, the system comprising:

a plurality of seismic receivers configured to be conveyed in a borehole and recording seismic signals responsive to an activation of at least one seismic source on the surface of the earth at at least one location offset from the borehole; and

at least one processor configured to;

(i) estimate, from travel times of seismic waves from the at least one location that have been reflected at an interface in the earth formation and the surface of the earth to the plurality of receivers, a velocity model including velocities of vertically propagating seismic waves in a plurality of intervals, and an anellipticity parameter related to a normal moveout velocity of compressional waves for the plurality of intervals; and

(ii) use the estimated velocity model for producing an image of the earth formation above the plurality of seismic receivers.

10. The system of claim 9 wherein the at least one location further comprises at least one additional location close to the borehole, and wherein the at least one processor is further configured to:

use travel times of seismic waves to the plurality of receivers from the at least one additional location and the velocity model to provide an updated velocity model including at least two anisotropy parameters related to a normal moveout curve of compressional waves for the plurality of intervals.

11. The system of claim 10 wherein the at least one processor is further configured to:

use the updated velocity model to produce an image of the earth formation; and

use the produced image for drilling operations.

12. The system of claim 10 wherein the at least one location comprises a plurality of locations defining a multi-azimuthal walkaway geometry, and the at least two anisotropy parameters further comprise five orthorhombic anisotropy parameters ε

₁, ε

₁, δ

₁, δ

₂ and δ

₃ related to a normal moveout velocity of compressional waves for the plurality of intervals.

13. The system of claim 10 wherein the at least one processor is further configured to estimate at least one of the at least two anisotropy parameters by approximating a moveout function representing the travel times by a shifted parabola.

14. The system of claim 9 wherein the at least one processor is further further configured to use the produced image for drilling operations.

15. The system of claim 9 wherein at least one of the plurality of seismic receivers further comprises a 3-component receiver.

16. The system of claim 9 further comprising a conveyance device configured to deploy the plurality of seismic receivers, the conveyance device selected from:

(i) a wireline, (ii) a pipe, and (iii) coiled tubing.

17. A non-transitory computer-readable medium product having stored thereon instructions that when read by at least one processor cause the at least one processor to execute a method, the method comprising:

estimating, from first travel times of seismic waves from at least one location offset from a borehole that have been reflected at an interface in the earth formation and the surface of the earth to a plurality of receivers in the borehole and second travel times of seismic waves to the plurality of receivers from at least one additional location near the borehole, a velocity model including at least two anisotropy parameters related to a normal moveout curve of compressional waves for the plurality of intervals; and

using the estimated velocity model for producing an image of the earth formation above the plurality of seismic receivers.

18. The non-transitory computer-readable medium product of claim 17 further comprising at least one of:

(i) a ROM, (ii) an EPROM, (iii) an EAROM, (iv) a flash memory, and (v) an optical disks.