Separation and noise removal for multiple vibratory source seismic data

• US 8,248,886 B2
• Filed: 03/19/2008
• Issued: 08/21/2012
• Est. Priority Date: 04/10/2007
• Status: Active Grant

• Current Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Original Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Inventors: Neelamani, Ramesh, Krohn, Christine, Deffenbaugh, Max, Krebs, Jerry, Anderson, John
• Primary Examiner(s): Keith, Jack W
• Assistant Examiner(s): Murphy, Daniel L
• Application Number:
  US12/531,271
• Publication Number:
  US 20100097888A1
• Time in Patent Office: 1,616 Days
• Field of Search: 367/46, 367/48, 367/21, 367/23, 367/41, 367/49, 367/189, 181/111, 702/14, 702/17, 702/97, 702/179
• US Class Current: 367/73
• CPC Class Codes: G01V 1/005 with exploration systems emitting special signals, e.g. frequency swept signals, pulse sequences or slip sweep arrangements
• CPC Class Codes: G01V 1/37 specially adapted for seismic systems using continuous agitation of the ground , e.g. using pulse compression of frequency swept signals for enhancement of received signals
• CPC Class Codes: G01V 2210/127 Cooperating multiple sources
• CPC Class Codes: G01V 2210/32 Noise reduction

Abstract

The invention discloses a way to recover separated seismograms with reduced interference noise by processing vibroseis data recorded (or computer simulated) with multiple vibrators shaking simultaneously or nearly simultaneously (200). A preliminary estimate of the separated seismograms is used to obtain improved seismograms (201). The preliminary estimate is convolved with the vibrator signature and then used to update the seismogram. Primary criteria for performing the update include fitting the field data and satisfying typical criteria of noise-free seismograms (202). Alternative ways to update are disclosed, including signal extraction, modeled noise extraction, constrained optimization based separation, and penalized least-squares based separation. The method is particularly suited for removing noise caused by separating the combined record into separate records for each vibrator, and is advantageous where the number of sweeps is fewer than the number of vibrators (200).

Claims

1. A method for separating multiple-vibrator seismic data and reducing separation-related noise, said seismic data being recorded in an actual or simulated survey with N vibrators (N>

1) operating simultaneously, with the number of sweeps per vibrator being fewer than N and the sweeps for each vibrator being different from the sweeps for the other vibrators in some manner, a sweep being defined as a period of continuous source energy radiation terminated by a listening time or other cessation of vibration for a time period at least as long as the two-way travel time of a seismic wave traveling from a vibrator down to a pre-selected deepest target of interest and back up to a seismic receiver, said method comprising;

(a) separating the survey data to obtain a preliminary estimate of N seismograms, one per vibrator; and

(b) adjusting the seismograms to match the survey data and to satisfy selected characteristics of noise-free seismograms, thereby producing N updated seismograms;

wherein said adjusting comprises extracting that part of each seismogram that corresponds to signal, and using the extracted signal parts to generate an updated set of separated seismograms; and

wherein the set of updated seismograms is generated by convolving each extracted signal part with its corresponding vibrator signature, then stacking all N results, subtracting that from the survey data, separating the result of that by vibrator, and for each vibrator adding that to the corresponding extracted signal part.

2. The method of claim 1, further comprising:

(c) testing the updated seismograms to determine a measure of error in fit compared to the survey data and the selected characteristics of noise-free seismograms; and

(d) repeating steps (b)-(d) as necessary until the error is less than a pre-selected value or another stopping point is reached.

3. The method of claim 1, wherein the number of sweeps per vibrator is one.

4. The method of claim 1, wherein the separation steps use a technique selected from a group consisting of damped inversion, HFVS (High Fidelity Vibratory Seismic) inversion, and cross correlation.

5. The method of claim 4, wherein the separation technique is damped inversion wherein inversion parameters are chosen such that the separated seismograms match the survey data in a weighted least-squares sense.

6. The method of claim 1, wherein the signal extraction is based on typical characteristics of noise-free seismograms.

7. The method of claim 6, wherein the typical characteristics of noise-free seismograms include at least one of a group consisting of (i) the amplitude of seismic events observed on a seismogram decay with increasing time, and (ii) seismic reflectors that appear on a group of adjacent seismogram traces are coherent.

8. The method of claim 7, wherein the typical characteristics of noise-free seismograms further include that the separated seismograms should not contain signal related to sources at the locations of the other vibrators by time of arrivals or dips.

9. The method of claim 6, wherein the signal extraction is performed either on a trace-by-trace basis in the time domain, or on a trace-by-trace basis after transforming each trace or collectively a group of traces to a different domain.

10. The method of claim 6, wherein the signal extraction is performed using a template for a noise-free seismogram.

11. The method of claim 1, wherein each vibrator'"'"'s signature is either measured, or estimated, or the vibrator'"'"'s pilot signal is used.

12. The method of claim 1, wherein the selected characteristics of noise-free seismograms comprise at least one of a group consisting of:

(a) the seismograms'"'"' amplitudes decay with time;

(b) reflections are coherent across adjacent seismogram traces; and

(c) reflection times and dips are constrained by seismic source location.

13. A method for producing hydrocarbons from a subsurface region, comprising:

(a) conducting a multiple vibrator seismic survey of the subsurface region with N vibrators (N>

1) operating simultaneously, with the number of sweeps per vibrator being fewer than N and the sweeps for each vibrator being different from the sweeps for the other vibrators in some manner, a sweep being defined as a period of continuous source energy radiation terminated by a listening time or other cessation of vibration for a time period at least as long as the two-way travel time of a seismic wave traveling from a vibrator down to a pre-selected deepest target of interest and back up to a seismic receiver;

(b) obtaining N separated seismograms wherein separation-caused noise has been reduced by a method of claim 1;

(c) drilling a well to a formation interpreted in the N updated seismograms as potentially hydrocarbon bearing; and

(d) producing hydrocarbons from the well.

14. A method for separating multiple-vibrator seismic data and reducing separation-related noise, said seismic data being recorded in an actual or simulated survey with N vibrators (N>

1) operating simultaneously, with the number of sweeps per vibrator being fewer than N and the sweeps for each vibrator being different from the sweeps for the other vibrators in some manner, a sweep being defined as a period of continuous source energy radiation terminated by a listening time or other cessation of vibration for a time period at least as long as the two-way travel time of a seismic wave traveling from a vibrator down to a pre-selected deepest target of interest and back up to a seismic receiver, said method comprising;

(a) separating the survey data to obtain a preliminary estimate of N seismograms, one per vibrator; and

(b) adjusting the seismograms to match the survey data and to satisfy selected characteristics of noise-free seismograms, thereby producing N updated seismograms;

wherein said adjusting comprises extracting parts of each seismogram, based on a model of the way in which noise is manifested in the survey data and using the extracted parts to generate an updated set of separated seismograms; and

wherein the set of updated seismograms is generated by convolving each extracted part with its corresponding vibrator signature, then stacking all N results, performing an operation on the stacked results, and subtracting that from the survey data, then separating the result of that by vibrator using the noise-reduced record to obtain improved separation of the seismograms.

15. The method of claim 14, wherein the operation is a time shift or a filter.

16. The method of claim 14, wherein each vibrator'"'"'s signature is either measured, or estimated, or the vibrator'"'"'s pilot signal is used.

17. The method of claim 14, wherein the selected characteristics of noise-free seismograms comprise at least one of a group consisting of:

(i) the seismograms'"'"' amplitudes decay with time;

(ii) reflections are coherent across adjacent seismogram traces; and

(iii) reflection times and dips are constrained by seismic source location.

18. A method for separating multiple-vibrator seismic data and reducing separation-related noise, said seismic data being recorded in an actual or simulated survey with N vibrators (N>

1) operating simultaneously, with the number of sweeps per vibrator being fewer than N and the sweeps for each vibrator being different from the sweeps for the other vibrators in some manner, a sweep being defined as a period of continuous source energy radiation terminated by a listening time or other cessation of vibration for a time period at least as long as the two-way travel time of a seismic wave traveling from a vibrator down to a pre-selected deepest target of interest and back up to a seismic receiver, said method comprising;

(a) separating the survey data to obtain a preliminary estimate of N seismograms, one per vibrator; and

(b) adjusting the seismograms to match the survey data and to satisfy selected characteristics of noise-free seismograms, thereby producing N updated seismograms;

wherein the adjusting comprises using the preliminary estimate of the separated seismograms in conjunction with the survey data and each vibrator'"'"'s signature to determine an updated set of updated seismograms using constrained optimization theory.

19. The method of claim 18, wherein the constrained optimization theory uses L1 minimization under quadratic constraint.

20. The method of claim 18, wherein the constrained optimization theory employs a log-barrier method which is used to perform seismogram separation formulated as a second-order cone program.

21. The method of claim 18, wherein each vibrator'"'"'s signature is either measured, or estimated, or the vibrator'"'"'s pilot signal is used.

22. The method of claim 18, wherein the selected characteristics of noise-free seismograms comprise at least one of a group consisting of:

(i) the seismograms'"'"' amplitudes decay with time;

(ii) reflections are coherent across adjacent seismogram traces; and

(iii) reflection times and dips are constrained by seismic source location.