Multi-pole resonance based through tubing cement evaluation

Patent metadata

Field	Value
Publication number	US-12234716-B2
Application number	US-202117643259-A
Country	US
Kind code	B2
Filing date	Dec 8, 2021
Priority date	Dec 8, 2021
Publication date	Feb 25, 2025
Grant date	Feb 25, 2025

Abstract

A method comprising: conveying a downhole tool in a tubing that is positioned in a casing that is positioned to form an annulus between the casing and a wall of a wellbore formed in a subsurface formation, wherein a cement with unknown bonding condition exists in the annulus, wherein the downhole tool includes at least one transmitter and a receiver array physically positioned in different azimuthal directions; emitting, from the at least one transmitter, a first and second acoustic transmissions in a first and second azimuthal directions; detecting, by the receiver array, a first acoustic response and a second acoustic response that is derived from the first and second acoustic transmissions, wherein the second azimuthal direction is orthogonal to the first azimuthal direction; determining a dipole wellbore resonance based on the first and acoustic responses; and evaluating a property of the cement based on the dipole wellbore resonance.

First claim

What is claimed is:

1. A method comprising:
conveying a downhole tool in a tubing that is positioned in a casing that is positioned to form an annulus between the casing and a wall of a wellbore formed in a subsurface formation, wherein a cement with unknown bonding condition exists in the annulus, wherein the downhole tool includes at least one transmitter configured to emit an acoustic transmission at different azimuthal positions, and wherein the downhole tool includes a receiver array that includes at least two receivers physically positioned in different azimuthal directions;
emitting, from the at least one transmitter, a first acoustic transmission in a first azimuthal direction to the cement such that at least a portion of the first acoustic transmission is to penetrate the cement;
detecting, by the at least two receivers of the receiver array, a first acoustic response that is derived from the first acoustic transmission;
emitting, from the at least one transmitter, a second acoustic transmission in the second azimuthal direction to the cement such that at least a portion of the second acoustic transmission is to penetrate the cement;
detecting, by the at least two receivers of the receiver array, a second acoustic response that is derived from the second acoustic transmission;
determining a dipole wellbore resonance based on the first acoustic response and the second acoustic response the dipole wellbore resonance including late time arrivals;
converting a first time segment of the late time arrivals into amplitude measurements in the frequency domain at different azimuthal angles;
determining a channel direction based on the amplitude measurements in the frequency domain at the different azimuthal angles; and
evaluating a property of the cement based on the dipole wellbore resonance, wherein evaluating includes determining a bonding condition of the cement in the channel direction, wherein determining a bonding condition of the cement in the channel direction includes:
selecting a second time segment of the late time arrivals, the second time segment associated with a frequency sensitive to cement bonding;
converting the second time segment of the late time arrivals into amplitude measurements in the frequency domain; and
evaluating the bonding condition of the cement in the channel direction based on the amplitude measurements of the second time segment of the late time arrivals in the frequency domain.

2. The method of claim 1 , further comprising:
rotating the at least one transmitter from the first azimuthal direction to the second azimuthal direction, after emitting the first acoustic transmission and before emitting the second acoustic transmission.

3. The method of claim 1 , wherein evaluating the bonding condition of the cement in the channel direction comprises:
selecting one or more of the amplitude measurements of the second time segment in the frequency domain, wherein selecting includes selecting amplitude measurements associated with bonding condition;
comparing the selected one or more amplitude measurements to a library of amplitudes for different tubing and casing configurations, eccentricities, and channel directions; and
evaluating the property of the cement based on the comparing.

4. The method of claim 1 , wherein evaluating the property of the cement further includes evaluating a bonding condition of the cement based on amplitude and frequency characteristics of the one or more late time arrivals.

5. The method of claim 4 , wherein evaluating the bonding condition of the cement comprises determining whether the bonding condition is at least one of a fully bonded condition, a free pipe condition, and a partially bonded condition.

6. The method of claim 1 , further comprising performing a remedial action to correct a fault in the cement based on the evaluating the property of the cement.

7. The method of claim 1 , wherein converting the second time segment of the late time arrivals into amplitude measurements in the frequency domain includes transforming the second time segment of the late time arrivals into the frequency domain and evaluating a bonding condition of the cement based on the characteristics of the one or more late time arrivals in the frequency domain.

8. A system comprising:
a downhole tool to be conveyed in a tubing that is positioned in a casing that is positioned to form an annulus between the casing and a wall of a wellbore formed in a subsurface formation, wherein a cement has been placed in the annulus, wherein the downhole tool comprises,
at least one transmitter configured to,
emit a first acoustic transmission in a first azimuthal direction to the cement such that at least a portion of the first acoustic transmission is to penetrate the cement; and
emit a second acoustic transmission in a second azimuthal direction to the cement such that at least a portion of the second acoustic transmission is to penetrate the cement, wherein the second azimuthal direction is orthogonal to the first azimuthal direction;

a receiver array that includes at least two receivers physically positioned in different azimuthal directions, wherein the receiver array is configured to,
detect, at the at least two receivers, a first acoustic response that is derived from the first acoustic transmission; and
detect, at the at least two receivers, a second acoustic response that is derived from the second acoustic transmission;

a processor; and
a machine-readable medium having program code executable by the processor to cause the processor to,
determine a dipole wellbore resonance based on the first acoustic response and the second acoustic response, the dipole wellbore response including late time arrivals;
convert a first time segment of the late time arrivals into amplitude measurements in the frequency domain at different azimuthal angles;
determine a channel direction based on the amplitude measurements in the frequency domain at the different azimuthal angles; and
evaluate a property of the cement based on the dipole wellbore resonance, wherein evaluating includes determining a bonding condition of the cement in the channel direction, wherein determining a bonding condition of the cement in the channel direction includes:
selecting a second time segment of the late time arrivals, the second time segment associated with a frequency sensitive to cement bonding;
converting the second time segment of the late time arrivals into amplitude measurements in the frequency domain; and
evaluating the bonding condition of the cement in the channel direction based on the amplitude measurements of the second time segment of the late time arrivals in the frequency domain.

9. The system of claim 8 , wherein the at least one transmitter is to rotate from the first azimuthal direction to the second azimuthal direction, after emission of the first acoustic transmission and before emission of the second acoustic transmission.

10. The system of claim 8 , wherein the program code executable by the processor to cause the processor to evaluate the bonding condition of the cement in the channel direction comprises program code executable by the processor to cause the processor to,
select one or more of the amplitude measurements of the second time segment in the frequency domain, wherein selecting includes selecting amplitude measurements associated with bonding condition;
compare the selected one or more amplitude measurements to a library of amplitudes for different tubing and casing configurations, eccentricities, and channel directions; and
evaluate the property of the cement based on the comparing.

11. The system of claim 8 , wherein the pro

Assignees

• Halliburton Energy Services Inc

Inventors

• Ge Yao
• Wang Ruijia
• Ma Ho Yin
• Wu Xiang

Classifications

• G01V1/48

  Processing data · CPC title

• G01V1/44

  using generators and receivers in the same well (G01V1/52 takes precedence) · CPC title

• G01V2210/1299

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

• G01V2210/1429

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

• G01V1/50

  Analysing data · CPC title