Downhole tubular inspection combining partial saturation and remote field eddy currents

Patent metadata

Field	Value
Publication number	US-11693144-B2
Application number	US-202217665208-A
Country	US
Kind code	B2
Filing date	Feb 4, 2022
Priority date	Jun 8, 2021
Publication date	Jul 4, 2023
Grant date	Jul 4, 2023

Abstract

A system may include an electromagnetic (EM) logging tool for inspecting downhole tubulars. The EM logging tool may include a mandrel, at least one low-frequency transmitter coil disposed on the mandrel, at least one-low frequency receiver coil disposed on the mandrel, and at least one-high frequency sensor configured to measure one or more electromagnetic properties of a tubular.

First claim

What is claimed is:

1. A downhole tubular inspection tool, comprising:
a tool body configured for lowering into an inner tubular on a conveyance;
a low-frequency sensor module including a low-frequency transmitter coil and a low-frequency receiver coil disposed along the tool body, wherein the low-frequency transmitter coil and receiver coil are operable within a first frequency range to measure electromagnetic properties of one or more outer tubulars disposed around the inner tubular; and
at least one high-frequency sensor module operable within a second frequency range greater than the first frequency range for measuring electromagnetic properties of the inner tubular.

2. The downhole tubular inspection tool of claim 1 , wherein the high-frequency sensor module is disposed on a deployable sensor pad coupled to the tool body with one or more extendable arms.

3. The downhole tubular inspection tool of claim 1 , wherein the low-frequency transmitter is excited by either a continuous-wave current (frequency-domain excitation), or a pulsed current (time-domain excitation).

4. The downhole tubular inspection tool of claim 1 wherein the low-frequency receiver is axially spaced along the tool body from the low-frequency transmitter.

5. The downhole tubular inspection tool of claim 1 wherein the low-frequency receiver is positioned along the tool body at essentially the same axial position as the low-frequency transmitter.

6. The downhole tubular inspection tool of claim 1 wherein the low-frequency transmitter and low-frequency receiver comprise a remote field eddy current (RFEC) transmitter and RFEC receiver operating in a frequency range of 0.1-500 Hz.

7. The downhole tubular inspection tool of claim 6 , wherein the RFEC receiver comprises a plurality of RFEC receivers axially spaced along the tool body.

8. The downhole tubular inspection tool of claim 1 wherein the high-frequency device comprises a partial saturation eddy current (PSEC) sensor operating in a frequency range of 10 kHz-150 kHz.

9. The downhole tubular inspection tool of claim 8 , wherein the high-frequency device comprises a magnetizer unit for imposing a constant magnetic field for reducing a permeability of the inner tubular while operating the PSEC sensor.

10. The downhole tubular inspection tool of claim 1 , further comprising one or more non-ferromagnetic tubing centralizers for centering the tool body within the first downhole tubular.

11. The downhole tubular inspection tool of claim 1 , further comprising:
one or more directional sensors coupled to the tool body responsive to a directional orientation of the tool body as it is lowered through the inner tubular.

12. A method for inspecting nested downhole tubulars, comprising:
conveying a logging tool having both a low-frequency transmitter and receiver and a high-frequency sensor module through a plurality of downhole tubulars comprising an inner tubular and one or more outer tubulars disposed around the inner tubular;
operating the low-frequency transmitter and receiver on the logging tool within a first frequency range to log low-frequency measurements of the one or more outer tubulars;
operating the high-frequency sensor module on the logging tool in a second frequency range of greater than the first frequency range to log high-frequency measurements of at least the inner tubular; and
inverting the low-frequency measurements to determine tubular parameters of one or more of the downhole tubulars, wherein the inversion is based in part on the high-frequency measurements logged by the high-frequency sensor.

13. The method of claim 12 , wherein inverting the low-frequency measurements to determine tubular parameters comprises determining a thickness, a percentage metal loss or gain, a magnetic permeability, an electrical conductivity, an eccentricity, or an inner diameter (ID) of one or more of the downhole tubulars.

14. The method of claim 12 , further comprising:
processing the high-frequency log to determine one or more parameters of the inner pipe comprising a magnetic permeability, an electrical conductivity, an ID, and a wall thickness at any given depth, and using those parameters to constrain the inversion of the low-frequency measurements to solve for parameters of the one or more outer pipes.

15. The method of claim 14 , further comprising setting electromagnetic properties of the outer tubulars equal to electromagnetic materials properties of the inner tubular wherein the outer tubulars and inner tubular are made of the same material.

16. The method of claim 15 , further comprising:
conveying the logging tool through a first zone wherein one of the downhole tubulars is an innermost tubular to obtain electromagnetic material properties of the innermost tubular in the first zone; and
conveying the logging tool through a second zone wherein the one of the downhole tubulars is not an innermost tubular and extrapolating its electromagnetic material properties based on its electromagnetic material properties in the first zone.

17. A method for inspecting nested downhole tubulars, comprising:
conveying a logging tool having both a low-frequency transmitter and receiver and a high-frequency sensor module through a plurality of downhole tubulars comprising an inner tubular and one or more outer tubulars disposed around the inner tubular;
operating the low-frequency transmitter and receiver within a first frequency range to log low-frequency measurements of the one or more outer tubulars;
operating the high-frequency sensor module in a second frequency range of greater than the first frequency range to log high-frequency measurements of at least the inner tubular;
inverting the low-frequency measurements to determine tubular parameters of one or more of the downhole tubulars includes determining one or both of a magnetic permeability and an electrical conductivity of the downhole tubulars and an eccentricity of the inner tubular with respect to one of the outer tubulars; and
processing the high-frequency measurements to determine a wall thickness and size of anomalies in the inner tubular, wherein this processing is based in part on one of a magnetic permeability, electrical conductivity, and eccentricity determined from the low-frequency measurements.

18. A method for inspecting nested downhole tubulars, comprising:
conveying a logging tool having both a low-frequency transmitter and receiver and a high-frequency sensor module through a plurality of downhole tubulars comprising an inner tubular and one or more outer tubulars disposed around the inner tubular;
operating a low-frequency transmitter and receiver within a first frequency range to log omni-directional low-frequency measurements of the one or more outer tubulars;
operating a high-frequency sensor module in a second frequency range of greater than the first frequency range to obtain a directional log of high-frequency measurements of at least the inner tubular, using multiple partial saturation eddy current (PSEC) sensors on sensor pads to provide directional sensitivity and a gyroscope or accelerometer information to put measurements on angle;
processing the low-frequency logs using inversion to determine an eccentricity ratio of the inner tubular with respect to one or more of the outer tubulars;
processing the high-frequency directional log to determine an eccentricity azimuth angle of the inner tubular with respect to one or more of the outer tubulars by comparing variations in electromagnetic signals at a given depth with a baseline signal obtained fro

Assignees

• Halliburton Energy Services Inc

Inventors

• Dai Junwen
• Fouda Ahmed E
• Hill Iii Freeman Lee
• Jones Christopher Michael

Classifications

• G01V3/10 Primary

  using induction coils · CPC title

• E21B47/007

  Measuring stresses in a pipe string or casing (for locating blocked portions of pipes E21B47/09) · CPC title

• E21B17/1078

  Stabilisers or centralisers for casing, tubing or drill pipes (E21B17/1007 - E21B17/1064 take precedence) · CPC title

• E21B47/006 Primary

  Detection of corrosion or deposition of substances · CPC title

• E21B47/085

  using radiant means, e.g. acoustic, radioactive or electromagnetic · CPC title