Measuring torque in a downhole environment

Patent metadata

Field	Value
Publication number	US-9429008-B2
Application number	US-201414198854-A
Country	US
Kind code	B2
Filing date	Mar 6, 2014
Priority date	Mar 15, 2013
Publication date	Aug 30, 2016
Grant date	Aug 30, 2016

Abstract

A drilling system may include one or more downhole components to which a torque is applied. To determine the torque, the rotational velocity may be determined at two locations on a downhole component. An angle of twist may be determined by taking the integral of the rotational velocity at the two points, and the torque may be proportional to the angle of twist. The angle of twist, physical properties based on the geometry and material of the downhole component may be used, and the distance between the two locations may be used to calculate the torque.

First claim

What is claimed is:

1. A method for determining torque on a downhole component within a wellbore, comprising:
obtaining a first rotational velocity measurement at a first location of a downhole component;
obtaining a second rotational velocity measurement at a second location of the downhole component, wherein obtaining the first and second rotational velocity measurements includes synchronizing sampling of the first and second rotational velocity measurements; and
calculating torque on the downhole component using the first and second rotational velocity measurements.

2. The method recited in claim 1 , wherein calculating torque on the downhole component includes:
integrating the first and second rotational velocity measurements.

3. The method recited in claim 1 , wherein calculating torque on the downhole component includes:
calculating an angle of twist of the downhole component.

4. The method recited in claim 3 , further comprising:
calculating a difference between an integral of the first rotational velocity measurement and an integral of the second rotational velocity measurement.

5. The method recited in claim 1 , wherein calculating torque on the downhole component includes calculating torque upon start-up of rotation of the downhole component.

6. The method recited in claim 1 , further comprising:
calculating mechanical power transmitted through the downhole component.

7. The method recited in claim 1 , wherein calculating torque includes determining a length between the first and second locations of the downhole component.

8. The method recited in claim 7 , wherein the length is a predetermined length.

9. The method recited in claim 1 , wherein calculating torque includes calculating torque using the equation:

T
=

(

∫

V
A

⁢

ⅆ
t

-

∫

V
B

⁢

ⅆ
t

)

⁢
GJ

L
AB

where T is the torque, V A is a rotational velocity at the first location, V B is a rotational velocity at the second location, L AB is a length between the first and second locations, G is a material shear modulus, and J is a polar moment of inertia.

10. The method recited in claim 1 , wherein calculating torque on the downhole component includes receiving the first and second rotational velocity measurements at a surface of the wellbore and thereafter calculating torque.

11. A drilling system, comprising:
a downhole component;
at least two sensing instruments coupled to the downhole component, each of the at least two sensing instruments including a rotational velocity sensor;
a controller communicatively coupled to the at least two sensing instruments, the controller being programmed to use rotational velocity measurements from the rotational velocity sensors to calculate a torque on at least a portion of the downhole component located adjacent one or both of the at least two sensing instruments; and
a synchronizer configured to synchronize sampling of rotational velocity measurements by the rotational velocity sensors.

12. The drilling system recited in claim 11 , the controller being programmed to calculate the torque on a portion of the downhole component located between the at least two sensing instruments.

13. The drilling system recited in claim 11 , the controller being programmed to integrate rotational velocity measurements to obtain angular position information.

14. The drilling system recited in claim 11 , the controller being coupled to the drill string.

15. The drilling system recited in claim 11 , the downhole component including one or more of:
a drill string;
a bottom-hole assembly;
a motor;
a drill bit;
a milling bit;
a reamer; or
a stabilizer.

16. The drilling system recited in claim 11 , the drill string including wired drill pipe, the at least two sensing instruments being in communication with a conductive communication element of the wired drill pipe.

17. The drilling system recited in claim 11 , the synchronizer using a sampling rate selected based on at least a rotational speed and an angle of twist resolution.

18. A method for calculating torque on a downhole tool within a wellbore, comprising:
obtaining synchronized measurements of rotational velocity at first and second locations of a downhole tool within a wellbore;
integrating the synchronized measurements of rotational velocity at the first and second locations;
determining a difference between the integrals of synchronized measurements of rotational velocity at the first and second locations; and
calculating a torque between the first and second locations using the difference between the integrals, a distance between the first and second locations, and physical properties of the downhole tool.

19. The method recited in claim 18 , wherein obtaining synchronized measurements includes obtaining measurements using rotational velocity sensors operating at a sampling rate selected based on at least a rotational speed and an angle of twist resolution.

20. The method recited in claim 18 , wherein the downhole tool includes or is coupled to a drill string, and wherein calculating the torque includes calculating torque using a controller:
coupled to a drill string; or
at a surface of the wellbore.

Assignees

• Smith International

Inventors

• Beylotte James E

Classifications

• E21B44/00 Primary

  Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions · CPC title