Downhole cutting tool having sensors or releasable particles to monitor wear or damage to the tool

Patent metadata

Field	Value
Publication number	US-10570670-B2
Application number	US-201414902162-A
Country	US
Kind code	B2
Filing date	Mar 24, 2014
Priority date	Mar 24, 2014
Publication date	Feb 25, 2020
Grant date	Feb 25, 2020

Abstract

A wellbore formation system includes a downhole cutting tool having a body and at least one cutting element. A sensor is coupled to the downhole cutting tool, and the sensor includes a transmitter configured to transmit a signal prior to wear on a portion of the downhole cutting tool reaching a first amount. The sensor ceases transmission of the signal when the wear on the portion of the downhole cutting tool reaches the first amount.

First claim

What is claimed is:

1. A wellbore formation system comprising:
a downhole cutting tool having a drill bit that includes a body and at least one cutting element attached to the body;
a first particle disposed at a first interface between a first layer and a second layer on the at least one cutting element, the first particle having a characteristic that exhibits photoluminescence as a first signature;
a second particle disposed at a second interface between the second layer and a third layer on the at least one cutting element, the second particle having a second particle characteristic that exhibits photoluminescence as a second signature, wherein the second particle is a second nanoparticle or a second microparticle; and
a sensor configured to detect at least one of the first signature of the first particle characteristic and the second signature of the second particle characteristic when the first particle or the second particle is released from the downhole cutting tool and wherein the sensor is disposed on the drill bit.

2. The system of claim 1 , wherein the first particle is released from the downhole cutting tool when a portion of the downhole tool wears by a first amount.

3. The system of claim 2 , wherein the second particle is released from the downhole cutting tool when a portion of the downhole tool wears by a second amount.

4. The system of claim 1 , wherein the first particle is released from a first location of the downhole cutting tool indicating wear in the first location.

5. The system of claim 4 , wherein the second particle is released from a second location of the downhole cutting tool indicating wear in the second location.

6. The system of claim 1 , wherein:
the downhole cutting tool is a fixed cutter drill bit;
the at least one cutting element is a polycrystalline diamond cutter (PDC) having a diamond table coupled to a substrate; and
the first particle is embedded within the diamond table.

7. The system of claim 6 , wherein:
the first particle is located within the diamond table a first distance from a cutting surface of the PDC cutter; and
the first particle is released from the PDC cutter when the PDC cutter wears by the first distance.

8. The system of claim 1 , wherein:
the downhole cutting tool is a fixed cutter drill bit;
the at least one cutting element is a polycrystalline diamond cutter (PDC) having a diamond table coupled to a substrate; and
the first particle is embedded at an interface between the diamond table and the substrate.

9. The system of claim 8 , wherein:
the first particle is located within the diamond table a first distance from a cutting surface of the PDC cutter; and
the first particle is released from the PDC cutter when wear on the PDC cutter reaches the interface.

10. The system of claim 1 , wherein at least one of the first particle and the second particle is coupled to a surface of the body.

11. The system of claim 1 , wherein:
the first particle is embedded within the downhole cutting tool at a first depth; and the second particle is embedded within the downhole cutting tool at a second depth.

12. The system of claim 1 , wherein the sensor is configured to detect the first signature of the first particle characteristic and the system further comprises:
a second sensor configured to detect the second signature of the second particle characteristic.

13. The system of claim 1 , wherein the second particle characteristic is the same as the first particle characteristic.

14. The system of claim 13 , wherein the second signature is different than the first signature.

15. The system of claim 1 , wherein:
the first particle characteristic further includes a magnetic property or a radio frequency property; and
the second particle characteristic further includes the magnetic property or the radio frequency property.

16. A method for detecting wear on a downhole cutting tool, the method comprising:
operating the downhole cutting tool to remove material in a wellbore wherein the downhole cutting tool includes a drill bit that includes a body and at least one cutting element attached to the body, wherein a first particle having a characteristic of photoluminescence is disposed at a first interface between a first layer and a second layer on the at least one cutting element, and a second particle having a characteristic of photoluminescence is disposed at a second interface between the second layer and a third layer on the at least one cutting element;
detecting a first particle characteristic within the wellbore by a sensor disposed on the drill bit indicating a first amount of wear at a first portion of the at least one cutting element, wherein the first particle is a first nanoparticle or a first microparticle; and
detecting a second particle characteristic within the wellbore by the sensor indicating a second amount of wear at a second portion of the at least one cutting element, wherein the first particle is a second nanoparticle or a second microparticle.

17. The method of claim 16 , wherein the first particle characteristic is the same as the second particle characteristic.

18. The method of claim 16 , wherein:
the first particle characteristic is a radioactivity property, a magnetic property, or a radio frequency property; and
the second particle characteristic is the radioactivity property, the magnetic property, or the radio frequency property.

19. The method of claim 16 , wherein:
detection of the first signature is indicative of the downhole cutting tool wearing to a first depth; and
detection of the second signature is indicative of the downhole cutting tool wearing to a second depth.

20. The method of claim 16 , wherein:
detection of the first signature is indicative of the downhole cutting tool wearing in a first location; and
detection of the second signature is indicative of the downhole cutting tool wearing in a second location.

Assignees

• Halliburton Energy Services Inc

Inventors

• Bird Jay Stuart
• Rashid Kazi M

Classifications

• E21B12/02 Primary

  Wear indicators · CPC title

• E21B10/08

  Roller bits (E21B10/26 takes precedence; roller core bits E21B10/06; characterised by wear resisting parts E21B10/50) · CPC title

• E21B10/55

  with preformed cutting elements · CPC title

• E21B10/56

  Button-type inserts (E21B10/52 takes precedence) · CPC title

• E21B10/42

  Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits (characterised by wear resisting parts E21B10/46; by conduits or nozzles for drilling fluid E21B10/60; by detachable or adjustable parts E21B10/62) · CPC title