Acoustic logging while drilling tool to determine bed boundaries

• US 5,678,643 A
• Filed: 10/18/1995
• Issued: 10/21/1997
• Est. Priority Date: 10/18/1995
• Status: Expired due to Term

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Minear, John Wesley, Mallett, A. J., Mandal, Batakrishna, Linyaev, Eugene Joseph, Birchak, James Robert, Robbins, Carl Arthur
• Primary Examiner(s): Neuder, William P.
• Application Number:
  US08/544,723
• Time in Patent Office: 734 Days
• Field of Search: 175/26, 175/45, 175/61, 166/255.2, 166/250.16, 166/254.2
• US Class Current: 175/45
• CPC Class Codes: E21B 47/0224 using seismic or acoustic means
• CPC Class Codes: E21B 7/04 Directional drilling
• CPC Class Codes: G01V 1/46 Data acquisition

Abstract

A LWD tool is disclosed for detecting the existence of and distance to adjacent bed boundaries. A transmitter assembly generates either a short acoustic pulse or a swept frequency signal that is detected by an associated receiver assembly. The received signal(s) are conditioned and converted to high precision digital signals by an A/D converter. The digitized signals are accumulated and transferred to a digital signal processor via a high speed data bus. The digital signal processor also receives a digital signal representing the transmission signal and compares the transmission signal and the received signals together to enable a downhole microprocessor to derive a time lag for the received signals. The microprocessor can transmit the time lag signal to the surface via a mud pulse for real-time control, or can operate as part of a closed loop drilling system to automatically control inclination of the drilling assembly to stay within, or to enter, a pay zone based upon the time lag associated with the received signals, and the measured speed of sound of the formation. In one embodiment, the receivers in the receiver array are steered to investigate various volume cells in the formation. A time delay is determined based on the volume cell, which is used to align and sum the received signals. The maximum sum value then is used as indicative of a bed boundary in that particular volume call.

Claims

1. A logging while drilling acoustic tool for a bottomhole drilling assembly, comprising:

a transmitter assembly in said bottom hole assembly for generating an acoustic wave signal that is transmitted into the formation;

a receiver assembly in said bottomhole assembly for receiving acoustic wave reflections from a bed boundary, and generating an electrical signal indicative of the received acoustic reflections;

a processor receiving said electrical signal from said receiver, and correlating said received electrical signal to the signal transmitted by said transmitter to determine distance to a bed boundary and the orientation angle of the bed boundary; and

wherein said processor generates a transmission signal that is applied to said transmitter assembly.

2. A tool as in claim 1, wherein said transmission signal comprises a swept frequency signal.

3. A tool as in claim 1, wherein the transmission signal comprises a short acoustic pulse.

4. A tool as in claim 1, wherein the receiver assembly is steered and collimated in a particular direction by providing a sufficient receiver aperture and particular time delays used to align the received signals for summing by said processor.

5. A tool as in claim 2, wherein the processor comprises a digital signal processor.

6. A tool as in claim 5, wherein said swept frequency transmission signal also is transmitted to said digital signal processor.

7. A tool as in claim 6, wherein said digital signal processor cross-correlates the swept frequency transmission signal with the electrical signal indicative of the received reflections.

8. A tool as in claim 7, wherein the cross-correlation implements transform domain multiplication.

9. A tool as in claim 7, wherein the cross-correlation implements time domain summations.

10. A tool as in claim 1, wherein said receiver assembly includes a plurality of receivers that are aligned axially along the exterior of the tool.

11. A system as in claim 1, wherein the transmitter assembly includes a first transmitter at one end of said tool and a second transmitter at the opposite end of said tool.

12. A system as in claim 5, wherein said electrical signal indicative of the received reflections comprises an analog signal, and said logging while drilling system includes a high precision analog-to-digital converter for converting said analog signal to a digital signal.

13. A system as in claim 12, further comprising a first in, first out buffer for accumulating the digital signals from said analog-to-digital converter.

14. A system as in claim 13, wherein said first in, first out buffer provides a digital output signal to said digital signal processor via a high speed data bus.

15. A system as in claim 13, further comprising a flash memory array connected to said processor for goring the digital output signals from said first in, first out buffer.

16. A system as in claim 7, wherein said processor determines a time lag signal from said cross-correlation indicative of a bed boundary.

17. A system as in claim 16, wherein said processor determines multiple time lag signals representative of different boundaries.

18. A system as in claim 16, wherein said processor generates a signal to a mud pulser unit indicative of said time lag signal.

19. A system as in claim 16, wherein said processor automatically controls the inclination of said bottomhole assembly in response to said time lag signal.

20. A logging while drilling system, as part of a bottomhole assembly which drills through downhole formations, for providing an indication of the distance to bed boundaries, comprising:

a transmitter assembly for generating acoustic signals into the formation;

a receiver assembly detecting reflected acoustic signals from bed boundaries;

a downhole processing unit for correlating the reflected signals received by said receiver assembly with the acoustic signals generated by said transmitter to remove extraneous noise and to determine a time lag for the reflected signals, said downhole processing unit using said time lag and speed of sound of the formation to determine the distance to bed boundaries.

21. A system as in claim 20, wherein said processing unit also determines the orientation of the bed boundary by steering and collimating the receiver assembly and summing the received reflected acoustic signals to determine the direction which provides the largest summed signal.

22. A system as in claim 21, wherein said transmitter assembly comprises a first transmitter and a second transmitter which fire acoustic pulses alternately.

23. A system as in claim 22, wherein said downhole processing unit determines a first waveform for each receiver for acoustic signals reflected from said first transmitter, and a second waveform for each receiver for acoustic signals reflected from said second transmitter.

24. A system as in claim 23, wherein said downhole processing unit performs a geometric correction on the first and second waveforms for each of the acoustic receivers to steer and collimate the acoustic waves by adjusting time delays between signals received by each receiver.

25. A system as in claim 24, wherein said downhole processing unit stacks the first and second waveform signals to produce a single waveform for a particular interval.

26. A system as in claim 20, wherein said receiver assembly comprises a plurality of receivers that are axially aligned with said transmitter assembly.

27. A system as in claim 26, further comprising a second receiver assembly that is positioned generally diametrically opposite the first receiver assembly.

28. A system as in claim 27, wherein said downhole processing unit compares the time at which the first receiver receives reflected acoustic signals with the time at which the second receiver assembly receives acoustic signals to determine the location of the bed boundary.

29. A system as in claim 28, wherein said downhole processing unit causes said bottomhole assembly to steer away from said bed boundary.

30. A system as in claim 20, wherein said downhole processing unit comprises a digital signal processor and a microprocessor.

31. A system as in claim 30, further comprising a flash memory array connected to said microprocessor for storing the reflected signals received by said receiver assembly.

32. A system as in claim 30, wherein said digital signal processor comprises a floating point processor.

33. A system as in claim 32, wherein said digital signal processor performs a Fourier transform on the transmission signal and a Fourier transform of the received signal, and multiplies the transformed signals together to obtain a product.

34. A system as in claim 33, wherein said digital signal processor performs an inverse Fourier transform on the product.

35. A system as in claim 34, wherein said microprocessor detects the peaks of the inverse Fourier transform of the product, to determine time lag for reflected signals.

36. A system as in claim 35, wherein said microprocessor connects to a mud pulser unit and transmits a signal indicative of said time lag to the mud pulser unit for transmission to the surface.

37. A system as in claim 35, wherein said microprocessor calculates a distance to the boundaries based upon the time lag.

38. A system as in claim 37 wherein the microprocessor determines the orientation of the bed boundaries by steering and collimating the direction of the acoustic wave, and summing the received acoustic signals to determine the optimal time delay Δ

t for the receivers.

39. A method for geosteering a bottomhole assembly, comprising the steps of:

transmitting acoustic signals into the formation;

receiving reflected acoustic signals;

generating an electrical signal representative of the received signals;

correlating the transmitted and received reflected acoustic signals;

determining the time lag for the received reflected acoustic signals;

determining the formation speed of sound;

identifying bed boundaries based upon the time lag determination and the speed of sound determination; and

steering the bottomhole assembly based upon the identification of bed boundaries.

40. A method as in claim 39, wherein the received acoustic signals are steered and collimated in a radial/axial plane relative to the bottomhole assembly and the steering direction giving maximum reflection amplitude is considered to be perpendicular to the bed boundary.

41. A method as in claim 39, wherein the transmitted acoustic signals comprise a swept frequency signal.

42. A method as in claim 41, wherein the step of correlating the transmitted and received reflected acoustic signals comprises implementation of transform domain techniques.

43. A method as in claim 42, wherein said transform domain techniques includes the steps of;

taking the Fourier transform of the transmitted signal;

taking the Fourier transform of the received signal;

multiplying together the transformed transmitted signal with the transformed received signal to obtain a product;

taking the inverse Fourier transform of the product.

44. A method as in claim 43, wherein the step of determining the time lag for the received reflected acoustic signals includes performing a peak search of the inverse Fourier transform of the product.

45. A method as in claim 39, wherein the step of correlating the transmitted and received reflected acoustic signals comprises implementation of time domain summation.

46. A method as in claim 39, wherein the transmitted acoustic signal comprises a short acoustic pulse.

47. A method as in claim 46, wherein the short acoustic pulse has a positive amplitude wave and a negative amplitude wave.

48. A method as in claim 47, wherein the negative amplitude wave is greater than the positive amplitude wave.

49. A method as in claim 48, wherein the negative amplitude wave has approximately twice the amplitude of the positive amplitude wave.

50. A method as in claim 47, wherein the pulse has a frequency in the range of 5 kHz to 20 kHz.

51. A method as in claim 50, wherein the frequency is approximately 12 kHz.

52. A method as in claim 46, wherein bed boundaries are determined in each of the separate directions and the step of steering the bottomhole assembly is based upon the location of bed boundaries in each of the separate directions.

53. A method as in claim 39, wherein the received acoustic signals are obtained from discrete, separate directions.

54. A method as in claim 53, wherein bed boundaries are determined in each of the discrete, separate directions and the step of steering the bottomhole assembly is based upon the location of bed boundaries in each of the discrete, separate directions.

55. A method for automatically steering a drill bit which is drilling through a downhole formation, comprising the steps of:

transmitting an acoustic signal into the formation;

receiving reflected acoustic signals;

cross-correlating said received reflected signals with the transmitted acoustic signals;

determining a time lag for a bed boundary based upon the time difference between transmitting the acoustic signal and receiving the reflected acoustic signal;

changing the direction in which said drill bit drills based upon the time lag signal.

56. A system for a bottomhole drilling assembly, comprising:

a transmitter assembly for transmitting acoustic signals into a formation;

a receiver assembly for detecting reflected acoustic signals;

a digital signal processor receiving signals indicative of the transmitted acoustic signals and the received acoustic signals, said digital signal processor cross-correlating the received signal to obtain a cross-correlated product; and

a microprocessor connected to said digital signal processor, said microprocessor analyzing said cross-correlated product to determine time lag for the received signals.

57. A system as in claim 56, wherein the time lag indicates the time for the reflected signal to reflect from a boundary.

58. An acoustic logging while drilling system for determining bed boundaries ahead of the drill bit, comprising:

a section of tubing;

an acoustic transmitter assembly located in said tubing section for transmitting a relatively low frequency signal into the formation ahead of the drill bit, said relatively low frequency signal have a wavelength (λ

);

an acoustic receiver array located in said tubing section for receiving reflections of said relatively low frequency signal, said receiver assembly including a first receiver and a second receiver, and said first and second receivers are separated a distance equal to or greater than the wavelength (λ

) of the transmitted wave.

59. A system as in claim 58, wherein said first and second receiver are separated a distance of 1-5 wavelengths (λ

).

60. A system as in claim 58, wherein the frequency of said low frequency signal is in the range of 100 Hz-1000 Hz.

61. A system as in claim 60, wherein the transmission signal comprises a swept frequency signal.

62. A system as in claim 60, wherein said transmission signal comprises a short acoustic pulse signal.

63. A system as in claim 58, wherein said section of tubing comprises a plurality of collars.

64. An acoustic logging while drilling system for determining bed boundaries in the vicinity of a borehole, comprising:

a section of tubing;

an acoustic transmitter assembly located in said tubing section for transmitting an acoustic signal into the formation ahead of the drill bit, said transmitter assembly including a first transmitter located on one face of the tubing section, and a second transmitter assembly located on an opposite face of said tubing section for acoustic steering in the plane perpendicular to the tubing axis;

an acoustic receiver array located in said tubing section for receiving reflections of the acoustic signal, said receiver assembly including a first receiver and a second receiver and said first and second receivers are separated a predetermined distance; and

a processor for performing geometric corrections on the reflections received by the acoustic receiver array based upon a time delay that is selected to investigate a particular volume cell external to the borehole.

65. A system as in claim 64, wherein said first receiver is aligned axially with said first transmitter, and said second receiver is aligned axially with said second transmitter.

66. A system as in claim 65, further comprising a first receiver array positioned between said first and said second receivers.

67. A system as in claim 66, further comprising a second receiver array positioned between said first and said second receivers.

68. A system as in claim 67, wherein said first and said second receiver arrays comprise a configuration of receivers positioned around the exterior of said tubing section.

69. A system as in claim 68, wherein each of said first and said second receiver arrays include three acoustic transducers.

70. A system as in claim 64, wherein the processor selects a time delay for each volume cell to achieve a maximum summed amplitude for the reflected signals.

71. A system as in claim 70, wherein the processor selects the volume cell with the maximum summed amplitude as indicating the location of the bed boundary.

72. A system as in claim 71, wherein the processor compares the maximum summed amplitude with a threshold value to determine if a bed boundary is present.

73. A system as in claim 71, wherein the processor uses the time delay associated with the volume cell with the maximum summed amplitude to calculate a path distance to the bed boundary.

74. A system as in claim 73, wherein the processor used the path distance to calculate a transit time.

75. A system as in claim 71, wherein the processor periodically determines bed boundary location during the drilling of the borehole, and associates each bed boundary location with depth.