Formation acoustic property measurement with beam-angled transducer array

Patent metadata

Field	Value
Publication number	US-2018372902-A1
Application number	US-201715632024-A
Country	US
Kind code	A1
Filing date	Jun 23, 2017
Priority date	Jun 23, 2017
Publication date	Dec 27, 2018
Grant date	—

Abstract

Methods and apparatus for performing formation evaluation in a borehole intersecting an earth formation. Methods may include exciting at a first borehole depth at least one critical refraction wave by steering an acoustic beam transmitted by at least one ultrasonic transmitter to an interface in the formation to intercept the interface at a critical angle; receiving an acoustic signal comprising critical refraction wave data at a logging tool in the borehole; and obtaining a wave property measurement from the critical refraction wave data. The interface may be the borehole wall in an open-hole well or behind casing. Methods include using ultrasonic transmitter(s) to generate the plurality of acoustic beams, identifying critical refraction wave data within the response signal corresponding to the at least one critical refraction wave, and obtaining the wave property measurement from the critical refraction wave data.

First claim

What is claimed is:

1 . A method for performing formation evaluation in a borehole intersecting an earth formation, the method comprising:
exciting at a first borehole depth at least one critical refraction wave by steering an acoustic beam transmitted by at least one ultrasonic transmitter to an interface in the formation to intercept the interface at a critical angle; receiving an acoustic signal comprising critical refraction wave data at a logging tool in the borehole; and obtaining a wave property measurement from the critical refraction wave data.

2 . The method of claim 1 wherein the interface lies at a radial distance from a longitudinal axis of the tool equal to at least one of: i) a distance from the longitudinal axis of the tool to a wall of the borehole; and ii) a second distance greater than the distance from the longitudinal axis of the tool to the wall of the borehole.

3 . The method of claim 1 wherein the acoustic beam is one of a plurality of acoustic beams, and wherein exciting the at least one critical refraction wave comprises:
using the at least one ultrasonic transmitter to generate the plurality of acoustic beams on a single trip in the borehole, each acoustic beam of the plurality having an effective angle of incidence with the interface;
generating a response signal at at least one acoustic receiver on the logging tool responsive to the acoustic signal, the acoustic signal resulting from the plurality of acoustic beams, wherein the acoustic signal comprises at least one critical refraction wave excited by the acoustic beam of the plurality of acoustic beams; and
identifying critical refraction wave data within the response signal corresponding to the at least one critical refraction wave; and
obtaining the wave property measurement from the critical refraction wave data.

4 . The method of claim 3 wherein identifying critical refraction wave data comprises:
separating formation acoustic wave signals and compressional and shear wave signals; and
identifying optimal signals using signal quality factors.

5 . The method of claim 1 wherein the at least one critical refraction wave excited by the acoustic beam comprises at least one of: i) a compressional head wave; ii) a shear head wave; iii) a borehole guided wave; iv) a reflection wave from a discontinuity boundary within the formation.

6 . The method of claim 1 wherein the interface comprises a fluid-solid interface.

7 . The method of claim 1 wherein the wave property measurement comprises at least one of: i) a compressional velocity measurement; ii) a shear velocity measurement; iii) a compressional wave attenuation measurement; iv) a shear wave attenuation measurement; v) a borehole guided wave velocity measurement; and vi) a borehole guided wave attenuation measurement.

8 . The method of claim 1 wherein a first beam of the plurality of acoustic beams has a first angle of incidence and a second beam of the plurality of acoustic beams has a second angle of incidence different than the first angle of incidence.

9 . The method of claim 1 further comprising estimating a location in the formation for the interface.

10 . The method of claim 1 further comprising performing at least one of: i) estimating a formation porosity from the wave property measurement; ii) detecting a fracture with the wave property measurement; iii) estimating a fracture location with the wave property measurement; iv) estimating a fracture orientation with the wave property measurement; v) estimating Poisson's ratio of the formation with the wave property measurement; vi) estimating Young's modulus of the formation with the wave property measurement; vii) estimating a bulk modulus of the formation with the wave property measurement; viii) estimating a shear modulus of the formation with the wave property measurement; ix) conduct fluid typing of a fluid in the formation with the wave property measurement; and x) estimate a fluid saturation for a fluid of the formation with the wave property measurement.

11 . The method of claim 1 further comprising:
exciting at a second borehole depth different than the first borehole depth another critical refraction wave by steering a second acoustic beam transmitted by the at least one ultrasonic transmitter to the interface to intercept the interface at a second critical angle different than the first critical angle;
receiving a second acoustic signal comprising additional critical refraction wave data at the logging tool; and
obtaining a second wave property measurement from the additional critical refraction wave data.

12 . The method of claim 1 further comprising:
exciting a second critical refraction wave at the first borehole depth by steering a second acoustic beam transmitted by the at least one ultrasonic transmitter to the interface to intercept the interface at a second critical angle different than the first critical angle;
obtaining a second wave property measurement from additional critical refraction wave data representing the second critical refraction wave at the first borehole depth, wherein the acoustic signal comprises the additional critical refraction wave data.

13 . The method of claim 1 further comprising:
exciting a second critical refraction wave at the first borehole depth by steering a second acoustic beam transmitted by the at least one ultrasonic transmitter to the interface to intercept the interface at the first critical angle at a frequency different than the frequency of the first critical refraction wave;
obtaining a second wave property measurement from additional critical refraction wave data representing the second critical refraction wave at the first borehole depth, wherein the acoustic signal comprises the additional critical refraction wave data.

14 . The method of claim 1 further orienting one or more of the at least one ultrasonic transmitter at an angle with respect to a longitudinal axis of the logging tool resulting in flexural wave energy sufficient to produce a shear head wave in an acoustically slow formation.

15 . The method of claim 1 comprising
exciting at least one additional critical refraction wave at each of a plurality of additional azimuths at a plurality of borehole depths;
receiving an acoustic signal comprising critical refraction wave data at the logging tool at each of the plurality of additional azimuths at the plurality of borehole depths in the borehole; and
obtaining a plurality of wave property measurements from the critical refraction wave data; and
generating a full-resolution two-dimensional image of the property for the borehole.

16 . The method of claim 1 wherein a center of mass of the logging tool is eccentered in the borehole.

17 . The method of claim 1 further comprising conducting further operations in dependence upon the wave property measurement.

18 . The method of claim 17 wherein the further operations comprise at least one of: i) geosteering; ii) drilling additional boreholes in the formation; iii) performing additional measurements on the formation; iv) estimating additional parameters of the formation; v) installing equipment in the borehole; vi) evaluating the formation; vii) optimizing present or future development in the formation or in a similar formation; viii) optimizing present or future exploration in the formation or in a similar formation; ix) drilling the borehole; and x) producing one or more hydrocarbons from the formation information.

19 . The method of claim 1 wherein the at least one c

Assignees

• Baker Hughes Inc

Inventors

• Han Wei
• Harris Jason M
• Patterson Douglas J
• Dymmock Stephen
• Dahl John

Classifications

• G01V1/50 Primary

  Analysing data · CPC title

• G01V2210/6242

  Elastic parameters, e.g. Young, Lamé or Poisson · CPC title

• G01V2210/74

  Visualisation of seismic data · CPC title

• G01V2210/1299

  Subsurface, e.g. in borehole or below weathering layer or mud line · CPC title

• G01V1/42 Primary

  using generators in one well and receivers elsewhere or vice versa (G01V1/52 takes precedence) · CPC title