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US-20260126559-A1 - SONIC THROUGH TUBING CEMENT EVALUATION

US20260126559A1US 20260126559 A1US20260126559 A1US 20260126559A1US-20260126559-A1

Abstract

An acoustic logging tool may comprise a center load carrying pipe, a receiver module connected to the center load carrying pipe, one or more transmitter modules connected to the center load carrying pipe, and one or more mass modules connected to the center load carrying pipe.

Inventors

  • Chung Chang
  • Qingtao Sun
  • Randolph S. Coles
  • Federico Lucas, JR.

Assignees

  • HALLIBURTON ENERGY SERVICES, INC.

Dates

Publication Date
20260507
Application Date
20251229

Claims (20)

  1. 1 . A through tubing cement evaluation (TTCE) method comprising: disposing an acoustic logging tool into tubing, wherein the acoustic logging tool comprises: a center load carrying pipe; a receiver module connected to the center load carrying pipe; one or more transmitter modules connected to the center load carrying pipe; one or more mass modules in contact with the center load carrying pipe, the one or more mass modules disposed along a circumference of the center load carrying pipe; and a void positioned beneath each of the one or more mass modules, wherein each void is defined by an interior circumferential portion of each mass module and an exterior circumferential portion of the center load carrying pipe; and transmitting one or more waveforms from a transmitter on the one or more transmitter modules; receiving one or more received waveforms with a receiver on the receiver module; and detecting changes in cement thickness along the tubing and in azimuthal directions, with the one or more received waveforms.
  2. 2 . The method of claim 1 , further comprising transmitting the one or more waveforms and receiving the one or more received waveforms at one or more depths in a wellbore, the tubing disposed in the wellbore.
  3. 3 . The method of claim 2 , further comprising subtracting adjacent received waveforms from the one or more depths.
  4. 4 . The method of claim 1 , wherein the transmitter is a unipolar transmitter.
  5. 5 . The method of claim 4 , further comprising rotating the unipolar transmitter to perform one or more transmitter firings.
  6. 6 . The method of claim 1 , wherein the transmitter is a monopole transmitter, and the acoustic logging tool further comprises a cover disposed over each of the one or more transmitter modules.
  7. 7 . The method of claim 1 , wherein the tubing is disposed in casing.
  8. 8 . The method of claim 7 , wherein the casing is disposed in a wellbore.
  9. 9 . A through tubing cement evaluation (TTCE) method comprising: disposing an acoustic logging tool into at least one pipe, wherein the acoustic logging tool comprises: a center load carrying pipe; a receiver module connected to the center load carrying pipe; one or more transmitter modules connected to the center load carrying pipe; one or more mass modules connected to the center load carrying pipe; and a void positioned beneath each of the one or more mass modules, wherein each void is defined by an interior circumferential portion of each mass module and an exterior circumferential portion of the center load carrying pipe; transmitting a first waveform in a first phase from a first transmitter on a first transmitter modules into the wellbore; receiving a first reflected waveform with a receiver on the receiver module; transmitting a second waveform in a second phase that is opposite the first phase from a second transmitter on a second transmitter module; receiving a second reflected waveform with the receiver on the receiver module; transmitting an in-phase waveform from the first transmitter and the second transmitter; receiving a reflected in-phase waveform with the receiver on the receiver module; and detecting changes in cement thickness along the at least one pipe and in azimuthal directions, with the reflected waveforms.
  10. 10 . The method of claim 9 , further comprising performing an inversion on the first reflected waveform, second reflected waveform, and the reflected in phase waveform to extract a cement impedance.
  11. 11 . The method of claim 9 , further comprising identifying an amplitude from the inversion to determine one or more cement conditions.
  12. 12 . The method of claim 9 , wherein the at least one pipe includes layers of multiple pipes.
  13. 13 . The method of claim 12 , wherein the at least one pipe includes concentric pipes.
  14. 14 . A through tubing cement evaluation (TTCE) method comprising: disposing an acoustic logging tool into tubing and/or layers of pipe, wherein the acoustic logging tool comprises: a center load carrying pipe; a receiver module connected to the center load carrying pipe; one or more transmitter modules connected to the center load carrying pipe; one or more mass modules in contact with the center load carrying pipe, the one or more mass modules disposed along a circumference of the center load carrying pipe; and a void positioned beneath each of the one or more mass modules, wherein each void is defined by an interior circumferential portion of each mass module and an exterior circumferential portion of the center load carrying pipe; and transmitting one or more waveforms from a transmitter on the one or more transmitter modules into the wellbore; receiving one or more received waveforms with a receiver on the receiver module; and detecting changes in cement thickness along the tubing and/or the layers of pipe, in azimuthal directions, with the one or more received waveforms.
  15. 15 . The method of claim 14 , further comprising transmitting the one or more waveforms and receiving the one or more received waveforms at one or more depths in a wellbore, the tubing and/or the layers of pipe disposed in the wellbore.
  16. 16 . The method of claim 15 , further comprising subtracting adjacent received waveforms from the one or more depths.
  17. 17 . The method of claim 14 , wherein the transmitter is a unipolar transmitter.
  18. 18 . The method of claim 17 , further comprising rotating the unipolar transmitter to perform one or more transmitter firings.
  19. 19 . The method of claim 14 , wherein the transmitter is a monopole transmitter, and the acoustic logging tool further comprises a cover disposed over each of the one or more transmitter modules.
  20. 20 . The method of claim 14 , wherein the tubing and/or the layers of pipe are disposed in a wellbore.

Description

CROSS REFERENCE TO RELATED APPLICATIONS This application is a continuation of U.S. patent application Ser. No. 18/196,398, filed May 11, 2023, which is a continuation of U.S. patent application Ser. No. 16/909,479, filed Jun. 23, 2020, U.S. Pat. No. 11,662,495, issued May 30, 2023, which claims benefits from U.S. Provisional Application No. 62/927,232, filed Oct. 29, 2019, which is incorporated by reference in its entirety. BACKGROUND In order to obtain hydrocarbons such as oil and gas, boreholes are drilled through hydrocarbon-bearing subsurface formations. Eventually, the boreholes are plugged and abandoned. Plugging and abandoning wells is controlled by local governments which place liability on companies for environment contamination. Therefore, ensuring proper integrity of the plugged well may prevent future litigation. Government regulations of placing a well barrier for permanent abandonment are often strenuous. For example, a cement barrier may have to be placed adjacent to an impermeable formation with sufficient formation integrity and extend across several hundreds of feet. The cement barrier may need to be verified, however, production tubing within the well may lead to unsatisfactory measurements from current tools and measurement methods. BRIEF DESCRIPTION OF THE DRAWINGS These drawings illustrate certain aspects of some examples of the present disclosure and should not be used to limit or define the disclosure. FIG. 1 illustrates an example of a wellbore acoustic logging system; FIG. 2 illustrates a graph of a receiver array response; FIG. 3 illustrates a cut away view of an example of an acoustic logging tool; FIG. 4A illustrates a cut away view of an example of a receiver module and a transmitter module; FIG. 4B illustrates an example of an operative flow chart; FIG. 4C illustrates another example of an operative flow chart; FIG. 5A illustrates constant offset measurements along a downhole tubular; FIG. 5B illustrates monopole mode responses corresponding with the constant offset measurements of FIG. 5A; FIG. 6 illustrates a graph of dipole mode responses with neighbor subtraction; FIG. 7 illustrates a cross-sectional view of a cement channel with production tubing and casing; FIG. 8 illustrates a graph of an angular waveform; FIG. 9 illustrates a graph of a processed angular waveform of FIG. 8; FIG. 10 illustrates a graph of a laboratory off-center monopole measurement; FIG. 11 illustrates a graph of processed results, after removing a monopole component; FIG. 12 illustrates a graph of simulated dipole measurements in a wellbore with a vertical cement channel; and FIG. 13 illustrates a graph of processed results of FIG. 12 to identify one or more cement channels. DETAILED DESCRIPTION This disclosure may generally relate to systems and methods for an acoustic logging tool that measures and provides cement conditions for zonal isolation through production tubing. This may be advantageous as pulling production tubing from a well may not be required. As discussed below, the acoustic logging tool may be configured at a low frequency to minimize an acoustic effect created by the reflection of acoustic waves transmitted from the acoustic logging tool and reflected off the production tubing. The frequencies may range from 5 to 35 kHz. The acoustic logging tool may further preserve high fidelity waveform measurements without tool wave interferences. This may allow for the acoustic logging tool to measure an amplitude difference between a cemented and non-cemented annulus, which may range from 1% to 10%. In certain examples, cement conditions may change along a length of the wellbore as well as along the wellbore's azimuthal direction. For angular measurement coverages, the acoustic logging tool may utilize inversion solutions to detect cement azimuthal changes. For example, to address azimuthal detectability, techniques may be employed to utilize an off-centered monopole, a dipole, and a uni-pole. In some examples, azimuthal detectability solutions may rotate the transmitter, a transmitter cover, or a tool body of the acoustic logging tool. FIG. 1 illustrates an operating environment for an acoustic logging tool 100 as disclosed herein. The acoustic logging tool 100 may comprise a transmitter 102 and/or a receiver 104. In examples, there may be any number of transmitters 102 and/or any number of receivers 104, which may be disponed on the acoustic logging tool 100. A diameter of the acoustic logging tool 100 may range from 1 and 11/16 inches (4.3 centimeters) to 4 and ½ l inches (11.4 centimeters). The acoustic logging tool 100 may be operatively coupled to a conveyance 106 (e.g., wireline, slickline, coiled tubing, pipe, downhole tractor, and/or the like) which may provide mechanical suspension, as well as electrical connectivity, for the acoustic logging tool 100. The conveyance 106 and the acoustic logging tool 100 may extend within a casing string 108 to a desired depth within a wellbore 110. T