Method and apparatus for measuring formation anisotropy while drilling
View Patent ↗A logging system for measuring anisotrophic properties of the materials penetrated by a borehole. A downhole or “logging tool” element of the system comprises a source section that comprises either a unipole or a dipole acoustic source. The receiver section comprises a plurality of receiver stations disposed at different axial spacings from the acoustic source. Each receiver station comprises one or more acoustic receivers. The system requires that the source and receiver sections rotate synchronously as the logging tool is conveyed along the borehole. Receiver responses are measured in a plurality of azimuthal angle segments and processed as a function of rotation angle of the tool. The logging system can be embodied as a logging-while-drilling system, a measurement-while-drilling system, and a wireline system that synchronously rotates source and receiver sections. All embodiments require that the acoustic source operate at a relatively high frequency.
1. An acoustic logging tool for determining an angular direction of minimum/maximum stress quantifying anisotropy of a formation penetrated by a borehole, said tool comprising:
a unipole acoustic source; and
a receiver section comprising a plurality of receiver stations at differing axial spacings from said acoustic source, wherein said source and said receiver section are configured to be synchronously rotatable within said borehole; and
a processor configured to:
measure responses of said receiver stations in azimuthal angular segments to refracted shear waves induced by said acoustic source;
process said responses to determine shear velocities of said formation as a function of azimuthal angle; and
determine said angular direction of minimum/maximum stress using said shear velocities as a function of said azimuthal angle.
2. The tool of claim 1 wherein:
said shear velocities as a function of azimuthal angle are used to determine a cross-over angle; and
said processor is further configured to combine said cross-over angle with measurements from a directional section of said tool to yield an absolute angular direction of said minimum/maximum stress.
3. The tool of claim 1 wherein said responses are processed with slowness time coherence maps and semblance projections or maximum likelihood method or slowness frequency coherence analysis.
4. The tool of claim 1 wherein said responses are processed with slowness time coherence maps and semblance projections.
5. The tool of claim 1 wherein said plurality of receiver stations comprises six or more receiver stations.
6. The tool of claim 1 wherein each said receiver station comprises two acoustic receivers.
7. The tool of claim 1 wherein said tool is a logging while drilling or measuring while drilling tool.
8. The tool of claim 7 wherein said source is operated at a frequency of approximately 4 KHz or greater.
9. The tool of claim 1 wherein said tool is a wireline tool.
10. The tool of 9 wherein said source is operated at a frequency of approximately 1 KHz or greater.
11. A method for determining a parameter quantifying anisotropy of a formation penetrated by a borehole, said method comprising:
operating a unipole acoustic source to emit an acoustic signal;
providing a receiver section comprising a plurality of receiver stations at differing axial spacings from said acoustic source;
rotating said source section and said receiver section synchronously within said borehole;
measuring responses of said receiver stations in azimuthal angular segments at a given depth within said borehole;
processing said responses to determine shear velocity of said formation as a function of azimuthal angle at said depth;
determining, from said shear velocity of said formation as a function of azimuthal angle at said depth, a relative angular direction of minimum/maximum stress of said formation; and
combining said relative angular direction of minimum/maximum stress with a measure of tool orientation to obtain an absolute angular direction of said minimum/maximum stress.
12. The method of claim 11 wherein said responses are processed with slowness time coherence maps and semblance projections or maximum likelihood method or slowness frequency coherence analysis.
13. The method of claim 11 wherein said responses are processed with slowness time coherence maps and semblance projections.
14. The method of claim 11 wherein said plurality of receiver stations comprises six or more receiver stations.
15. The method of claim 11 wherein each said receiver station comprises two acoustic receivers.
16. The method of claim 11 further comprising conveying said source and said receiver section along said borehole with a drill string.
17. The method of claim 16 wherein said source is operated at a frequency of approximately 4 KHz or greater.
18. The method of claim 11 further comprising conveying said source section and said receiver section along said borehole with a wireline.
19. The method of claim 18 wherein said source is operated at a frequency of approximately 1 KHz or greater.