Distributed strain monitoring for downhole tools

Patent metadata

Field	Value
Publication number	US-2016265905-A1
Application number	US-201615019052-A
Country	US
Kind code	A1
Filing date	Feb 9, 2016
Priority date	Mar 9, 2015
Publication date	Sep 15, 2016
Grant date	—

Abstract

An apparatus for monitoring strain on a downhole component includes a fiber optic sensor having a length thereof in operable relationship with a downhole component and configured to deform in response to deformation of the downhole component. The fiber optic sensor defines a continuous, distributed sensor. An interrogation assembly is configured to transmit an electromagnetic interrogation signal into the fiber optic sensor and is configured to receive reflected signals therefrom. A processing unit is configured to receive information from the interrogation assembly and is configured to determine a strain on the downhole component during running of the downhole component to depth in a borehole.

First claim

What is claimed is:

1 . An apparatus for monitoring strain on a downhole component, the apparatus comprising:
a fiber optic sensor having a length thereof in an operable relationship with a downhole component and configured to deform in response to deformation of the downhole component, the fiber optic sensor defining a continuous, distributed sensor; an interrogation assembly configured to transmit an electromagnetic interrogation signal into the fiber optic sensor and configured to receive reflected signals therefrom; and a processing unit configured to receive information from the interrogation assembly and configured to determine a strain on the downhole component during running of the downhole component to depth in a borehole.

2 . The apparatus of claim 1 , further comprising a communication line operatively connecting the fiber optic sensor and the interrogation assembly.

3 . The apparatus of claim 2 , wherein the communication line is a fiber optic cable.

4 . The apparatus of claim 1 , wherein the fiber optic sensor is an optical fiber sensor.

5 . The apparatus of claim 4 , wherein the fiber optic sensor is a distributed fiber optic strain monitoring cable.

6 . The apparatus of claim 1 , wherein the interrogation assembly is configured as part of the downhole component.

7 . The apparatus of claim 6 , further comprising a data logger configured to record data from at least one of the interrogation assembly and the processing unit.

8 . The apparatus of claim 1 , wherein the downhole component is a housing configured to mimic the physical properties of a downhole tool.

9 . The apparatus of claim 1 , wherein the downhole component is operatively connected to a production string.

10 . The apparatus of claim 1 , wherein the interrogation assembly is on a ground surface and in operative communication with the fiber optic sensor.

11 . The apparatus of claim 1 , wherein the fiber optic sensor is disposed along a central axis of the downhole component.

12 . The apparatus of claim 1 , wherein the processing unit is configured to continuously determine a strain on the downhole component during running of the downhole component to depth.

13 . The apparatus of claim 1 , wherein the processing unit is configured to periodically determine a strain on the downhole component during running of the downhole component to depth.

14 . The apparatus of claim 1 , wherein the processing unit is configured to determine a strain on the downhole component at a potential landing site.

15 . The apparatus of claim 1 , wherein the downhole component is an electrical submersible pump.

16 . A method of monitoring strain on a downhole component, the method comprising:
disposing a length of an fiber optic sensor in a fixed relationship relative to a downhole component, the fiber optic sensor configured to deform in response to deformation of the downhole component, the fiber optic sensor defining a continuous distributed sensor; running the downhole component into a borehole to a potential landing site; transmitting an electromagnetic interrogation signal into the fiber optic sensor during running of the downhole component; receiving reflected signals from the fiber optic sensor during running of the downhole component; and determining a strain on the downhole component from the received reflected signal during the running of the downhole component.

17 . The method of claim 16 , further comprising recording the received reflected signals.

18 . The method of claim 16 , wherein the determining step occurs in situ.

19 . The method of claim 16 , wherein the fiber optic sensor is disposed along a central axis of the downhole tool.

20 . The method of claim 16 , further comprising determining a strain on the downhole component at the potential landing site of the downhole component.

21 . The method of claim 16 , further comprising transmitting at least one of the received reflected signal and the determined strain to a surface component.

22 . The method of claim 16 , wherein the determining step occurs continuously during the running of the downhole component.

23 . The method of claim 16 , wherein the determining step occurs periodically during the running of the downhole component.

Assignees

• Duncan Roger Glen
• Clarke Colin M
• Babar Asad
• Baker Hughes Inc

Inventors

• Duncan Roger Glen
• Clarke Colin M
• Babar Asad

Classifications

• E21B47/001

  for underwater installation · CPC title

• E21B47/135

  using light waves, e.g. infrared or ultraviolet waves · CPC title

• E21B47/16

  through the drill string or casing {, e.g. by torsional acoustic waves} · CPC title

• E21B43/12 Primary

  Methods or apparatus for controlling the flow of the obtained fluid to or in wells (E21B43/25 takes precedence; valve arrangements E21B34/00) · CPC title

• E21B47/12

  Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling · CPC title