High Resolution Estimation of Attenuation from Vertical Seismic Profiles

Patent metadata

Field	Value
Publication number	US-2016178772-A1
Application number	US-201414892667-A
Country	US
Kind code	A1
Filing date	May 27, 2014
Priority date	May 27, 2013
Publication date	Jun 23, 2016
Grant date	—

Abstract

A method of obtaining an attenuation model estimate for a vertical seismic profile (VSP). The method may include the steps of receiving a vertical seismic profile dataset, the VSP dataset having been generated by recording a wavefield at a number of depth levels, building an estimate of a number of changes in an attribute of the wavefield sensitive to attenuation between respective pairs of depth levels based on the VSP dataset, producing a number of corrected changes in the attribute between the respective pairs of depth levels by modeling local interference of the wavefield from interfaces near each of the depth levels using information including measured well log and/or borehole information and correcting the estimated changes in the attribute for this interference, choosing and fitting an attenuation law to the corrected transfer functions, and outputting an attenuation model.

First claim

I claim:

1 . Method of obtaining an attenuation model estimate for a vertical seismic profile (VSP), comprising:
receiving a vertical seismic profile dataset, the VSP dataset having been generated by recording a wavefield at a plurality of depth levels; building an estimate of a plurality of changes in an attribute of the wavefield sensitive to attenuation between respective pairs of depth levels based on the VSP dataset; producing a plurality of corrected changes in the attribute between the respective pairs of depth levels by modeling local interference of the wavefield from interfaces near each of the depth levels using information comprising measured well log and/or borehole information and correcting the estimated changes in the attribute for this interference; choosing and fitting an attenuation law to the corrected transfer functions; and outputting an attenuation model.

2 . Method according to claim 1 , comprising separating upgoing and downgoing wavefields of the wavefield, and correcting the estimated changes in the attribute of the wavefield for the downgoing wavefield.

3 . Method according to claim 1 , wherein modeling local interference of the wavefield from interfaces near each of the depth levels comprises removing reflections of the wavefield from the interfaces within a user-specified distance or travel time of each depth level, but not removing scattering losses of the wavefield.

4 . Method according to claim 1 , wherein the attenuation law is an effective attenuation law and the attenuation model is an effective attenuation model.

5 . Method according to claim 1 , comprising:
producing the plurality of corrected changes in the attribute by also modeling scattering effects of the wavefield between the respective pairs of depth levels using the information comprising well log and/or borehole information, and correcting the estimated changes in the attribute for these scattering effects.

6 . Method according to claim 5 , wherein modeling local interference of the wavefield from interfaces near each of the depth levels comprises removing reflections from the interfaces within a user-specified distance or travel time of each depth level, and modeling scattering effects of the wavefield between the respective pairs of depth levels comprises removing scattering losses of the wavefield between the respective pairs of depth levels.

7 . Method according to claim 5 , wherein the attenuation law is an intrinsic attenuation law and the attenuation model is an intrinsic attenuation model.

8 . Method according to claim 1 , wherein the corrected changes in the attribute are produced by:
producing a plurality of modeled changes in the attribute between the respective pairs of depth levels using the information, and correcting the estimated changes in the attribute with the modeled changes in the attribute.

9 . Method according to claim 8 , wherein the corrected changes in the attribute are produced by estimating and applying a correction factor from the modeled changes in the attribute to each of the estimated changes in the attribute.

10 . Method according to claim 9 , wherein the correction factor is applied to the amplitude and/or phase spectra of each of the estimated changes in attribute to produce corrected change in attribute amplitude and/or phase spectra.

11 . Method according to claim 9 , wherein the correction factor is a stabilized correction factor.

12 . Method according to claim 10 , comprising:
comparing the corrected changes in attribute amplitude and/or phase spectra with expectations from the Kramers-Kronig relations.

13 . Method according to claim 8 , wherein
outputting the attenuation model comprises outputting the attenuation model with uncertainties estimated from the model fit for amplitude and/or phase spectra.

14 . Method according to claim 9 , further comprising, when the VSP data has been gathered by receivers placed at the depth levels, correcting for receiver coupling by:
separating the upgoing and downgoing wavefields of the wavefield, estimating a change due to receiver coupling in an attribute sensitive to receiver coupling of the downgoing and upgoing wavefields respectively, calculating and applying modified correction factors for upgoing and downgoing wavefields, and estimating the attenuation model based on using modified correction factors to correct estimated changes due to receiver coupling in the attribute sensitive to receiver coupling.

15 . Method according to claim 1 , comprising:
applying VSP pre-processing, including a broad bandpass filter, appropriate deconvolution of signatures, trace editing, and stacking for each depth level; choosing time windows to include first arrivals; processing VSP with standard processing for velocity and time-depth relation estimation; calibrating sonic and density well logs; and editing and infilling well logs to build a detailed elastic model from the start of the first time window to the end of the last time window prior to building said estimate of the transfer functions.

16 . Method according to claim 15 , comprising:
removal of multiples and ghosts from said VSP during pre-processing, wherein said removal comprises deconvolution.

17 . Method according to claim 1 , comprising:
estimating the transfer functions by match filtering.

18 . Method according to claim 1 , wherein the change in an attribute of the wavefield sensitive to attenuation is a transfer function, a change in instantaneous frequency, a change in rise time, a change in peak amplitude, a spectral ratio, a change in centroid frequency, a time-domain attribute, a frequency-domain attribute, or a time-frequency-domain attribute.

19 . Method of obtaining an attenuation model estimate for a vertical seismic profile (VSP), comprising:
receiving a vertical seismic profile dataset; building an estimate of the transfer function between levels based on the VSP dataset; inputting information for modeling local interference and correcting the estimated transfer function; choosing and fitting an effective attenuation law to the corrected transfer functions; outputting an effective attenuation model; characterized in that said input information comprises measured well log and/or borehole information to model interference from interfaces near the receiver levels and choosing and fitting an attenuation law to transfer functions corrected for this interference.

20 . A data processing apparatus configured to perform the method of any preceding claim 1 .

21 . A computer program product comprising instructions that when executed on a data processing apparatus will configure the data processing apparatus to perform the method of claim 1 .

Assignees

• Statoil Petroleum As

Inventors

• Carter Andrew James

Classifications

• G01V1/36

  Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy · CPC title

• G01V2210/614

  Synthetically generated data · CPC title

• G01V1/42

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

• G01V2210/584

  Attenuation · CPC title

• G01V2210/56

  De-ghosting; Reverberation compensation · CPC title