Using seismic P and S arrivals to determine shallow velocity structure
Method for estimating a model of seismic velocity in a subsurface region from seismic data ( 31 ) recorded on 3-component instruments. The method measures the apparent incidence angle ( 32 ) of a seismic wave observed at a surface as a function of wave frequency. This apparent angle is converted to an effective velocity as a function of frequency ( 33 ), which is then inverted ( 34 ) to obtain a subsurface velocity model.
1. A method for estimating a depth-dependent model of seismic velocity in a subsurface region from seismic data recorded on 3-component instruments, comprising using a computer to:
determine a wave front incidence angle for a selected seismic event in the seismic data at a plurality of frequencies or frequency bands;
determine a frequency dependent velocity from the wave front incidence angle for each frequency or frequency band; and
estimate a depth-dependent model of seismic velocity by inverting the frequency-dependent velocity.
2. The method of claim 1 , wherein, in determining a frequency dependent velocity, a selected physical model is used to convert incidence angle to effective seismic velocity.
3. The method of claim 1 , wherein, in inverting the frequency dependent velocity, a selected sensitivity kernel is used to describe how waves of different frequencies sample the Earth.
4. The method of claim 3 , wherein the sensitivity kernel defines sensitivity as a function of depth for different frequencies.
5. The method of claim 1 , wherein the seismic data represent P-wave, S-wave or surface-wave arrivals.
6. The method of claim 1 , further comprising windowing the seismic data in arrival time to isolate the selected seismic event before determining the wave front incidence angle.
7. The method of claim 1 , further comprising using more than one seismic event to constrain the inversion.
8. The method of claim 7 , further comprising obtaining depth-dependent models for subsets of seismic events passing through different geographic regions, resulting in a 1D, 2D, or 3D velocity model.
9. The method of claim 1 , further comprising applying said method to seismic data from two or more receiver stations at different geographical locations, resulting in a 1D, 2D, or 3D velocity model.
10. The method of claim 1 , further comprising repeating the method for a plurality of seismic events recorded over a period of time, and grouping the seismic events according to arrival time, and identifying time-lapse differences in obtained velocity models.
11. The method of claim 6 , wherein the data windowing is performed with a Gaussian or box-car function with a width being a multiple of the wave's period.
12. The method of claim 6 , wherein a band pass filter is applied before data windowing.
13. The method of claim 1 , wherein the wave front incidence angle is found by determining a rotation angle that rotates a survey station reference frame seismogram into a wave front reference frame seismogram.
14. The method of claim 13 , wherein the rotation angle is determined either as an angle that maximizes P-wave or S-wave energy as determined by integration of a P or S component signal in the seismic data, or an angle that minimizes cross-correlation between P and S V components of the seismic data.
15. The method of claim 2 , wherein the selected physical model is either Snell's Law or is based on a free-surface transfer matrix or other stress or momentum surface boundary condition.
16. The method of claim 3 , wherein the sensitivity kernel is one of a group consisting of box-cars, decaying exponentials, and Gaussians with widths being multiples of wave period.
17. The method of claim 1 , wherein a non-linear iterative inversion solver is used to infer the seismic velocity model.
18. The method of claim 1 , further comprising using a model length constraint or a regularization constraint or another constraint in the inverting.
19. A method for migrating seismic reflection data to obtain a depth image of a subsurface region, comprising using a method of claim 1 to obtain a velocity model of the subsurface region, then using the velocity model to migrate the seismic reflection data.
20. A method for producing hydrocarbons, comprising:
conducting a seismic survey of a subsurface region using 3-component seismic receivers;
obtaining migrated seismic reflection data generated from the seismic survey using a depth-dependent model of seismic velocity for the subsurface region produced by steps comprising:
determining a wave-front incidence angle for a selected seismic event in the seismic reflection data at a plurality of frequencies or frequency bands;
determining a frequency-dependent velocity from the wave-front incidence angle for each frequency or frequency band; and
estimating a depth-dependent model of seismic velocity by inverting the frequency-dependent velocity;
interpreting the migrated seismic reflection data for presence of hydrocarbons, and drilling a well based at least partly on said interpretation, and producing hydrocarbons from the well.
21. A computer program product, comprising a non-transitory computer usable medium having a computer readable program code embodied therein, said computer readable program code adapted to be executed to implement a method for estimating a depth-dependent model of seismic velocity in a subsurface region from seismic data recorded on 3-component instruments, said method comprising:
determining a wave front incidence angle for a selected seismic event in the seismic data at a plurality of frequencies or frequency bands;
determining a frequency dependent velocity from the wave front incidence angle for each frequency or frequency band; and
estimating a depth-dependent model of seismic velocity by inverting the frequency-dependent velocity.
22. The method of claim 3 , further comprising using the frequency-dependent velocity and the sensitivity kernel as a constraint on inversion of other geophysical data.