Fracture monitoring

• US 8,950,482 B2
• Filed: 05/27/2010
• Issued: 02/10/2015
• Est. Priority Date: 05/27/2009
• Status: Active Grant

• Current Assignee: Optasense Holdings Limited (Luna Innovations, Inc.)
• Original Assignee: Optasense Holdings Limited (Luna Innovations, Inc.)
• Inventors: Hill, David John, McEwen-King, Magnus, Tindell, Patrick
• Primary Examiner(s): Neuder, William P
• Application Number:
  US13/320,882
• Publication Number:
  US 20120111560A1
• Time in Patent Office: 1,720 Days
• Field of Search: 166/250.1, 166/308.1, 166/177.5
• US Class Current: 166/250.1
• CPC Class Codes: E21B 43/11857 firing indication systems
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• CPC Class Codes: E21B 47/107 using acoustic means
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: E21B 47/16 through the drill string or casing , e.g. by torsional acoustic waves
• CPC Class Codes: G01H 9/004 using fibre optic sensors light guides per se G02B6/00, acousto-optical devices specially adapted for gating or modulating in optical wave guides G02F1/125
• CPC Class Codes: G01V 1/50 Analysing data
• CPC Class Codes: G01V 2210/1429 Subsurface, e.g. in borehole or below weathering layer or mud line
• CPC Class Codes: G01V 2210/646 Fractures

Abstract

This application relates to methods and apparatus for monitoring hydraulic fracturing during oil/gas well formation. A fiber optic cable (102) deployed down a well bore (106), which may be the well bore in which fracturing is performed, is interrogated to provide a distributed acoustic sensor. Data is sampled from at least one longitudinal sensing portion of the fiber and processed to provide at least fracturing characteristic. The fracturing characteristic may comprise the characteristics of high frequency transients indicative of fracturing events (606). The intensity, frequency, duration and signal evolution of the transients may be monitored to provide the fracturing characteristic. Additionally or alternatively the fracturing characteristic may comprise the longer term acoustic noise generated by fracture fluid flow to the fracture sites. The intensity and frequency of the noise may be analyzed to determine the fracturing characteristic. The method allows real-time control of the fracturing process.

Claims

1. A method of downhole monitoring of hydraulic fracturing comprising the steps of:

interrogating an optic fibre arranged down the path of a well bore to provide a distributed acoustic sensor,

sampling data from a plurality of longitudinal portions of the fibre; and

processing said data to provide an indication of at least one fracturing characteristic wherein the indication of at least one fracturing characteristic comprises an indication of at least of;

(a) intensity levels;

(b) frequencies; and

(c) spread of frequencies of acoustic disturbances in at least one longitudinal sensing portion of the fibre in a vicinity of the fracture site, and wherein said indication(s) are used to provide an indication of the flow of proppant and fluid into a fracture.

2. A method as claimed in claim 1 wherein the method provides a real-time indication of said at least one fracturing characteristic.

3. A method as claimed in claim 1 wherein said optic fibre is arranged in the well bore in which hydraulic fracturing is performed.

4. A method as claimed in claim 1 wherein the indication of at least one fracturing characteristic comprises an audible signal representing the acoustic signals detected by at least one longitudinal portion of fibre in the vicinity of a fracturing site.

5. A method as claimed in claim 1 wherein the indication of the intensity levels is used to control flow conditions of proppant and fluid into the wellbore.

6. A method as claimed in claim 1 wherein the indication of at least one fracturing characteristic comprises a comparison of the intensity levels of acoustic disturbances from at least one longitudinal sensing portion of the fibre in the vicinity of each of a plurality of different fracture sites.

7. A method as claimed in claim 6 wherein the indication of at least one fracturing characteristic comprises a display of acoustic energy for each of the separate longitudinal sensing portions being monitored.

8. A method as claimed in claim 6, wherein said indication(s) are used to indicate the relative flow of proppant and fluid into each of the plurality of different fracture sites.

9. A method as claimed in claim 1 wherein the measured acoustic disturbances from at least one longitudinal sensing portion in the vicinity of a fracturing site are divided into one or more spectral bands and an average intensity determined for each of said spectral bands.

10. A method as claimed in claim 9 wherein the indication of at least one fracture characteristic comprises a display, for at least one longitudinal sensing portion of the fibre for each fracturing site, of the acoustic intensity from a selected spectral band.

11. A method as claimed in claim 9 comprising the step of analysing data from a plurality of spectral bands to identify a spectral band of interest.

12. A method as claimed in claim 11 wherein said analysing step comprises determining a spectral band in which the intensity of acoustic disturbances in that spectral band in the longitudinal sensing portions of fibre corresponding to the fracture sites are significantly higher than the intensity in other nearby longitudinal sensing portions.

13. A method as claimed in claim 11 wherein said analysing step comprises detecting any spectral band in which the intensity at one or more longitudinal sensing portions corresponding to a fracture site is significantly lower than the intensity at longitudinal sensing portions corresponding to one or more other fracture sites.

14. A method as claimed in claim 11 wherein said indication of at least one fracture characteristic comprises a display of the intensity of acoustic disturbances from at least one longitudinal sensing portion in the vicinity of the fracture site in said spectral band of interest.

15. A method as claimed in claim 11 wherein said spectral band of interest comprises an indication of a fracture characteristic.

16. A method as claimed in claim 1 comprising the step of monitoring evolution of intensities of the longitudinal sensing portions of the fibre corresponding to the fracture sites during the fracturing process.

17. A method as claimed in claim 16 comprising the step of determining any significant change in an average intensity in any relevant longitudinal sensing portion changes and/or the relative intensities in the longitudinal sensing portions of the fibre corresponding to the fracture sites.

18. A method as claimed in claim 1 wherein the steps of interrogating the fibre and sampling data comprises launching a series of optical pulses into said fibre and detecting radiation Rayleigh backscattered by the fibre;

and processing the detected Rayleigh backscattered radiation to provide a plurality of discrete longitudinal sensing portions of the fibre.

19. A method as claimed in claim 1 wherein said fibre is single mode fibre which is, absent any external stimulus, free of any substantial change of optical properties along the fibre length.

20. A method as claimed in claim 1 where the longitudinal sensing portions of fibre are 10 m or less in length.

21. A method according to claim 1 wherein fibre is sampled at a sampling rate is greater than or equal to 5 kHz.

22. A method according to claim 1, wherein at least 250 channels are sampled simultaneously.

23. A computer program product which, when run on a suitably programmed computer connected to or embodied within a controller for an optical interrogator or a downhole fibre optic, performs the method of claim 1.

24. A method as claimed in claim 1 wherein the indication of at least one fracture characteristic comprises an indication of proppant wash-out.

55. A method of hydraulic fracturing of a well bore comprising the steps of:

flowing a fracture fluid down the well bore under pressure,

performing the method of monitoring as claimed in any preceding claim; and

adjusting flow parameters of the fracture fluid in response to said indication of at least one fracturing characteristic.

56. A method of hydraulic fracturing as claimed in claim 55 wherein the step of adjusting the flow parameters comprises at least one of:

stopping the flow, adjusting the flow rate and adding additional solid material to the fracture fluid.

57. A method as claimed in claim 55 wherein the method comprises determining characteristics of transients in the detected acoustic signals and adjusting the flow parameters to achieve a desired transient characteristic.

58. A method as claimed in claim 55 wherein the method comprises automatically adjusting flow parameters based on the fracturing characteristic.

25. A method of downhole monitoring of hydraulic fracturing comprising the steps of:

interrogating an optic fibre arranged down the path of a well bore to provide a distributed acoustic sensor;

sampling data from a plurality of longitudinal portions of the fibre; and

processing said data to provide an indication of at least one fracturing characteristic, wherein the indication of at least one fracturing characteristic comprises an indication of proppant wash-out.

26. A method as claimed in claim 25 wherein the method comprises analysing data from sensing portions of the fibre along a length of the well bore during hydraulic fracturing to detect any signals indicative flow of fluid out of a well casing which do not correspond to a fracturing site.

27. A method as claimed in claim 25 further comprising the step of identifying any potential points of failure of the casing and/or surrounding cement prior to hydraulic fracturing.

28. A method as claimed in claim 27 comprising the step of monitoring an acoustic disturbance from a plurality of sensing portions of the fibre to generate an acoustic profile of the well bore and analysing said profile to detect any anomalies.

29. A method as claimed in claim 28 wherein said acoustic profile is acquired by monitoring the acoustic disturbances in response to a perforation charge being fired.

30. A method as claimed in claim 25 wherein the method provides a real-time indication of said at least one fracturing characteristic.

31. A method as claimed in claim 25 wherein said optic fibre is arranged in the well bore in which hydraulic fracturing is performed.

32. A method as claimed in claim 25 wherein the indication of at least one fracturing characteristic comprises an audible signal representing the acoustic signals detected by at least one longitudinal portion of fibre in the vicinity of a fracturing site.

33. A method as claimed in claim 25 comprising the step of monitoring evolution of intensities of the longitudinal sensing portions of the fibre corresponding to the fracture sites during the fracturing process.

34. A computer program product which, when run on a suitably programmed computer connected to or embodied within a controller for an optical interrogator or a downhole fibre optic, performs the method of claim 25.

35. A method of downhole monitoring of hydraulic fracturing comprising the steps of:

interrogating an optic fibre arranged down the path of a well bore to provide distributed acoustic sensing;

sampling data from a plurality of longitudinal portions of the fibre; and

processing said data to provide an indication of at least one fracturing characteristic comprising the step of performing transient detection to determine at least one of a direction to, a range to or a location of the origin of the transient.

36. A method as claimed claim 35 where the indication of at least one fracture characteristic comprises an indication of a number and/or rate of transients in the acoustic signal.

37. A method as claimed in claim 36 wherein the indication comprises a comparison of the number and/or rate of transients to an expected number/rate.

38. A method as claimed in claim 35 where the indication of at least one fracture characteristic comprises an indication of an intensity of transients in the acoustic signal.

39. A method as claimed in claim 35 where the indication of at least one fracture characteristic comprises an indication of a duration of transients or a series of transient in the acoustic signal.

40. A method as claimed in claim 35 where the indication of at least one fracture characteristic comprises an indication of a frequency of transients in the acoustic signal.

41. A method as claimed in claim 40 comprising analysing a frequency spread of detected transients.

42. A method as claimed in claim 35 comprising analysing an evolution of the transient signal or a series of transient signals.

43. A method according to claim 35, wherein transient detection includes maintaining a measure of mean absolute deviation.

44. A method according to claim 43, wherein said measure of mean absolute deviation is updated by exponential averaging using a decay term, N.

45. A method according to claim 44 wherein said decay term N is adaptively varied.

46. A method according to claim 35 comprising using a time-of-arrival technique to determine at least one of a direction to, a range to or a location of the origin of the transient.

47. A method as claimed in claim 46 further comprising the step of analysing data from at least one other sensor at another location.

48. A method as claimed in claim 47 wherein said at least one additional sensor comprises at least one other fibre optic distributed acoustic sensor.

49. A method as claimed in claim 35 wherein said indication of at least one fracture characteristic comprises a fracture map.

50. A method as claimed in claim 35 wherein the method provides a real-time indication of said at least one fracturing characteristic.

51. A method as claimed in claim 35 wherein said optic fibre is arranged in the well bore in which hydraulic fracturing is performed.

52. A method as claimed in claim 35 wherein the indication of at least one fracturing characteristic comprises an audible signal representing the acoustic signals detected by at least one longitudinal portion of fibre in the vicinity of a fracturing site.

53. A method as claimed in claim 35 comprising the step of monitoring evolution of intensities of the longitudinal sensing portions of the fibre corresponding to the fracture sites during the fracturing process.

54. A computer program product which, when run on a suitably programmed computer connected to or embodied within a controller for an optical interrogator or a downhole fibre optic, performs the method of claim 35.

59. A system for downhole monitoring, said system comprising:

a fibre optic interrogator adapted to provide distributed acoustic sensing on an optic fibre arranged along the path of a well bore;

a sampler arranged to sample a plurality of channels output from said interrogator to provide acoustic data from a plurality of portions of said fibre at each of a plurality of times; and

a data analyser adapted to process said sampled data to detect fracture characteristics and provide indications of said fracture characteristics wherein the indication of at least one fracturing characteristic comprises an indication of at least one of;

(a) the intensity levels;

(b) the frequencies, and (c) the spread of the frequencies of acoustic disturbances in at least one longitudinal sensing portion of the fibre in the vicinity of a fracture site, and wherein said indication(s) are used to provide an indication of the flow of proppant and fluid into a fracture.

60. A system as claimed in claim 59 wherein the optic fibre is deployed along an exterior of the well casing.

61. Use of a distributed acoustic sensor system according to claim 59 downhole in a well bore in which hydraulic fracturing is being performed to provide information about the fracturing process for controlling the hydraulic fracturing process.

62. A system for downhole monitoring, said system comprising:

a fibre optic interrogator adapted to provide distributed acoustic sensing on an optic fibre arranged along the path of a well bore;

a sampler arranged to sample a plurality of channels output from said interrogator to provide acoustic data from a plurality of portions of said fibre at each of a plurality of times; and

a data analyser adapted to process said sampled data to detect fracture characteristics and provide indications of said fracture characteristics, wherein the indication of at least one fracture characteristic comprises an indication of proppant wash-out.

63. Use of a distributed acoustic sensor system according to claim 62 downhole in a well bore in which hydraulic fracturing is being performed to provide information about the fracturing process for controlling the hydraulic fracturing process.

64. A system for downhole monitoring, said system comprising:

a fibre optic interrogator adapted to provide distributed acoustic sensing on an optic fibre arranged along the path of a well bore;

a sampler arranged to sample a plurality of channels output from said interrogator to provide acoustic data from a plurality of portions of said fibre at each of a plurality of times; and

a data analyser adapted to process said sampled data to detect fracture characteristics, provide indications of said fracture characteristics, to perform a transient detection, and to determine at least one of a direction to, a range to, or a location of the origin of the transient.

65. Use of a distributed acoustic sensor system according to claim 64 downhole in a well bore in which hydraulic fracturing is being performed to provide information about the fracturing process for controlling the hydraulic fracturing process.