SYSTEM AND METHOD FOR PIPE AND CEMENT INSPECTION USING BOREHOLE ELECTRO-ACOUSTIC RADAR

• US 20160069842A1
• Filed: 05/21/2013
• Published: 03/10/2016
• Est. Priority Date: 05/21/2013
• Status: Abandoned Application

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Bonavides, Clovis, Donderici, Burkay
• Application Number:
  US14/786,007
• Publication Number:
  US 20160069842A1
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 47/005 Monitoring or checking of cementation quality or level
• CPC Class Codes: G01N 2291/0258 Structural degradation, e.g. fatigue of composites, ageing of oils
• CPC Class Codes: G01N 2291/2636 cylindrical from inside
• CPC Class Codes: G01N 29/225 Supports, positioning or alignment in moving situation
• CPC Class Codes: G01N 29/2418 using optoacoustic interaction with the material, e.g. laser radiation, photoacoustics photoacoustic cells G01N21/1702; measuring characteristics of vibrations by using radiation-sensitive means G01H9/00; acousto-optical conversion techniques for short-range imaging G01S15/8965; sound-producing devices using laser bundle G10K15/046
• CPC Class Codes: G01N 29/2431 using other means for acoustic excitation, e.g. heat, microwaves, electron beams sound producing devices not otherwise provided for G10K15/04
• CPC Class Codes: G01N 29/4454 Signal recognition, e.g. specific values or portions, signal events, signatures
• CPC Class Codes: G01V 3/12 operating with electromagnetic waves operating with millimetre waves G01V8/005
• CPC Class Codes: G01V 3/30 operating with electromagnetic waves

Abstract

An example method for pipe inspection in a subterranean formation using borehole electro-acoustic radar may include emitting mechanical energy from a mechanical energy source disposed in a pipe, which may cause the pipe to vibrate. Electromagnetic (EM) energy from an electromagnetic energy source disposed in the borehole may then be transmitted and received. A vibration signature of the medium may be identified by comparing the transmitted EM energy to the received EM energy. This may include determining the phase difference between the transmitted and received EM energy, which can be correlated to the vibration of the pipe.

Claims

1. A method for pipe inspection in a subterranean formation, comprising:

emitting mechanical energy from a mechanical energy source disposed in a borehole, wherein the mechanical energy causes a medium within the borehole to vibrate according to a first vibration signature; and

transmitting first electromagnetic (EM) energy from an EM energy source disposed in the borehole;

receiving the first EM energy; and

identifying the first vibration signature of the medium by comparing the transmitted first EM energy to the received first EM energy.

2. The method of claim 1, wherein the EM energy source comprises an array of antennae.

3. The method of claim 1, wherein the EM energy source comprises electric or magnetic dipoles.

4. The method of claim 3, wherein the electric or magnetic dipoles comprise at last one of a Horn antenna, a phase array, and a parabolic antenna.

5. The method of claim 1, wherein the EM energy source comprises a microwave source, and the transmitted first EM energy comprises microwave energy pulses.

6. The method of claim 1, wherein the EM energy source comprises an optical source, and the transmitted first EM energy comprises laser pulses.

7. The method of claim 1, wherein identifying the first vibration signature of the medium by comparing the transmitted first EM energy to the received first EM energy comprises identifying at least one of a phase shift, an arrival time, and an amplitude ratio between the transmitted first EM energy and the received first EM energy.

8. The method of claim 6, wherein identifying the first vibration signature of the pipe comprises solving for d_vib in the following equation:

ω

_eq=ω

_em−

k*d_vib*ω

_ac*cos(t₀*ω

_ac),

where ω

_em comprises the transmitted optical frequency of the laser pulses, ω

_eq comprises the received optical frequency of the laser pulses, ω

_ac comprises the acoustic frequency at the pipe, d_vib comprises the pipe vibration amplitude, and k comprises spatial frequency of the first EM energy.

9. The method of claim 1, further comprising introducing a downhole tool into the borehole, wherein the mechanical energy source and the EM energy source are coupled to the downhole tool.

10. The method of claim 9, wherein at least one of the EM energy source and the mechanical energy source is positioned on a rotating portion of the tool.

11. The method of claim 9, further comprising positioning the mechanical source and the EM energy source proximate to a pipe installed within the bore using a cement layer.

12. The method of claim 11, further comprising determining at least one geometrical or mechanical property of the cement layer or the pipe using the first vibration signature.

13. The method of claim 12, wherein determining at least one geometrical or mechanical property of the cement or the pipe using the first vibration signature comprises the use of at least one of an analytical expression or an optimized modeling function.

14. The method of claim 1, further comprising:

transmitting second EM energy from the EM energy source;

receiving the second EM energy; and

identifying a second vibration signature of the medium by comparing the transmitted second EM energy to the received second EM energy, wherein the second vibration signature identifies at least one flow of fluid proximate to the medium.

15. An apparatus for pipe inspection in a subterranean formation, comprising:

a downhole tool;

at least one mechanical energy source coupled to the downhole tool;

at least one electromagnetic (EM) energy source coupled to the downhole tool;

at least one EM energy receiver coupled to the downhole tool;

at least one processor in communication with the at least one mechanical energy source and the at least one EM energy source, wherein the processor is coupled to at least one memory element containing a set of instruction that when executed by the at least one processor cause the processor to;

signal the at least one mechanical energy source to emit mechanical energy into a pipe, wherein the mechanical energy causes the pipe to vibrate according to a first vibration signature;

signal the at least one EM energy source to transmit first EM energy;

signal the at least one EM energy receiver to receive the transmitted first EM energy; and

determine the first vibration signature of the pipe by comparing the transmitted first EM energy to the received first EM energy.

16. The system of claim 15, wherein the EM energy source comprises an array of antennae.

17. The system of claim 15, wherein the EM energy source comprises electric or magnetic dipoles.

18. The system of claim 17, wherein the electric or magnetic dipoles comprise at last one of a Horn antenna, a phase array, and a parabolic antenna.

19. The system of claim 15, wherein the EM energy source comprises a microwave source, and the transmitted EM energy comprises microwave energy pulses.

20. The system of claim 15, wherein the EM energy source comprises an optical source, and the transmitted first EM energy comprises laser pulses.

21. The system of claim 15, wherein comparing the transmitted first EM energy to the received first EM energy comprises identifying at least one of a phase shift, an arrival time, and an amplitude ratio between the transmitted first EM energy and the received first EM energy.

22. The system of claim 20, wherein the vibration signature of the pipe is determined by solving for d_vib in the following equation:

ω

_eq=ω

_em−

k*d_vib*ω

_ac*cos(t₀*ω

_ac),

where ω

_em comprises the transmitted optical frequency of the laser pulses, ω

_eq comprises the received optical frequency of the laser pulses, ω

_ac comprises the acoustic frequency at the pipe, d_vib comprises the pipe vibration amplitude, and k comprises spatial frequency of the first EM energy.

23. The system of claim 15, wherein at least one of the EM energy source and the mechanical energy source is positioned on a rotating portion of the downhole tool.

24. The system of claim 15, wherein the set of instruction that when executed by the at the processor further cause the processor to determine at least one geometrical or mechanical property of the borehole using the first vibration signature.

25. The system of claim 15, wherein the set of instruction further cause the processor

cause the at least one EM energy source to transmit second EM energy;

cause the at least one EM energy receive the transmitted second EM energy; and

determine a second vibration signature of the pipe by comparing the transmitted second EM energy to the received second EM energy, wherein the second vibration signature identifies at least one flow of fluid proximate to the pipe.