Seismic surveying

• US 5,260,911 A
• Filed: 05/28/1991
• Issued: 11/09/1993
• Est. Priority Date: 05/25/1990
• Status: Expired due to Term

• Current Assignee: Atlantic Richfield Company Incorporated (BP PLC)
• Original Assignee: Charles C. Mosher, David S.R. Campbell, Geoffrey M. Jackson, Lee, Delman, Mason, Iain M.
• Inventors: Jackson, Geoffrey M., Lee, Delman, Mosher, Charles C., Mason, Iain M., Campbell, David S. R.
• Primary Examiner(s): Lobo, Ian J.
• Application Number:
  US07/706,577
• Time in Patent Office: 896 Days
• Field of Search: 367/56, 367/57, 367/58, 367/54, 367/36
• US Class Current: 367/57
• CPC Class Codes: G01V 1/003 Seismic data acquisition in general, e.g. survey design G01V1/3808, G01V1/42 take precedence
• CPC Class Codes: G01V 1/286 Mode conversion

Abstract

A method of seismic surveying uses seismic waveguides in the earth. Seismic energy is transmitted from outside the waveguide and detected within the waveguide or vice-versa. Coupling of energy between the outside and the inside of the waveguide is effected by energy leakage at coupling sites where the waveguide departs from planarity. The method analyzes seismic signals to determine the position and nature of coupling sites and the propagation characteristics of the waveguide.

Claims

1. A method of seismic surveying which utilizes a seismic waveguide in the earth wherein a first region is defined as the region within the waveguide and a second region is defined as the region outside of the waveguide, the method consisting of generating seismic energy by means of one or more energy sources situated in one of said regions;

detecting seismic energy which leaks by energy coupling from one of said regions to the other of said regions;

detecting seismic energy by means of one or more transducers in the other of said regions and analyzing the detected seismic energy to locate localized deviations in the planarity of the waveguide which give rise to said energy coupling.

2. The method claimed in claim 1 wherein said one region is the region outside the waveguide and said other region is the region inside the waveguide, the seismic energy being generated by one or more sources at or near the surface of the earth and being detected by one or more geophones in one or more boreholes within the waveguide.

3. The method claimed in claim 1 wherein said one region is the region inside the waveguide and said other region is the region outside the waveguide, the seismic energy being generated by one or more sources in one or more boreholes within the waveguide and being detected by one or more geophones at or near the surface of the earth.

4. A method of seismic surveying as claimed in any one of the preceding claims wherein a plurality of seismic traces is derived, each being in respect of seismic energy transmitted between a position in the waveguide and a respective position outside the waveguide, and wherein a model is applied to the traces to determine energy transmitted by said energy coupling, the model assuming that coupled energy has a transmission time comprising two components consisting of a constant time component within the waveguide and a variable downgoing time component outside the waveguide, wherein the downgoing time component is a function of the horizontal offset of the respective position outside the waveguide from an energy coupling site at the waveguide.

5. A method of seismic surveying is claimed in claim 4 wherein the position of the energy coupling site is determined by analysis of the time components for the different seismic traces.

6. A method of seismic surveying as claimed in claim 5 wherein frequency analysis of the received seismic energy is performed to determine the relationship between phase velocity and frequency for propogation within the waveguide.

7. A method of seismic surveying as claimed in claim 6 wherein the said relationship between phase velocity and frequency is determined for different waveguide modes to or from the same coupling site.

8. A method as claimed in claim 6 wherein the said relationship between phase velocity and frequency is determined for different coupling sites.

9. A method of seismic surveying as claimed in claim 6 wherein a characterization of the guided mode propogation in the waveguide is obtained from the relationship between phase velocity and frequency and the nature of the coupling site is determined from the said guided mode propagation characterization and from the nature of the wavefield outside the waveguide at the coupling site.

10. A method of seismic surveying as claimed in any one of claims 1-3 wherein when a particular fault line is to be investigated, the fault line having distributed energy coupling sites thereon, the method includes arranging the geometry of the seismic source or sources, and the geophone or geophones in relation to the coupling sites in such a manner that there is a wavenumber match between the waveguide modes and the wave energy outside the

11. A method of seismic surveying as claimed in any one of claims 1-3 wherein when energy coupling sites are mapped from data derived from the detected seismic energy by an interactive modelling computer program, the method includes applying the data as input to the program and deriving as output a trial hypothesis display which is a map of the waveguide with a movable coupling segment and a field data display onto which the seismic arrival times corresponding to the trial hypothesis is superimposed for the purpose of comparison, and the method further includes the step of manipulating the trial hypothesis to determine a fitting of the data.

12. A method of seismic surveying as claimed in any one of claims 1 to 3 wherein when energy coupling sites are mapped from data derived from the detected seismic energy by inversion of the data, a seismic process of migration is employed.

13. A method of seismic surveying as claimed in claim 12 wherein a migration image of the waveguide is obtained by a summation of the data samples which correspond to the travel time which would be associated with a scatterer at each of a number of points which are prospective energy coupling sites taken in turn, the travel times being calculated by adding the waveguide propogation time to the site to surface travel time.

14. A method of seismic surveying as claimed in claim 13 wherein summation of data is effected in a partially coherent manner, coherent summation of data being effected for seismic sources less than a predetermined distance apart and incoherent summation of data being effected for sources more than said predetermined distance apart, incoherent summation being by conversion of the real seismic traces to complex analytic signals by a Hilbert transformation and summation of the amplitudes of the said complex signals, whereas coherent summation of data is effected by summation of the real seismic traces.

15. A method as claimed in claim 7 wherein the said relationship between phase velocity and frequency is determined for different coupling sites.

16. A method of seismic surveying as claimed in claim 7 wherein a characterization of the guided mode propagation in the waveguide is obtained for the relationship between phase velocity and frequency and the nature of the coupling site is determined from the said guided mode propagation characterization and from the nature of the wavefield outside the waveguided at the coupling site.

17. A method of seismic surveying as claimed in claim 8 wherein a characterization of the guided mode propagation in the waveguide is obtained for the relationship between phase velocity and frequency and the nature of the coupling site is determined from the said guided mode propagation characterization and from the nature of the wavefield outside the waveguide at the coupling site.