Method to mitigate bit induced vibrations by intentionally modifying mode shapes of drill strings by mass or stiffness changes

Patent metadata

Field	Value
Publication number	US-11021945-B2
Application number	US-201815970585-A
Country	US
Kind code	B2
Filing date	May 3, 2018
Priority date	Nov 1, 2013
Publication date	Jun 1, 2021
Grant date	Jun 1, 2021

Abstract

A method for reducing vibrations in a drill tubular coupled to a drill bit configured to drill a borehole in a formation includes: constructing a model of a system having the drill tubular, the model having a mass distribution, a stiffness, and/or a damping of the drill tubular; and calculating a plurality of modes using the model. The method also includes increasing an effective damping of the drill tubular for the plurality of modes by modifying at least one of the mass distribution, the stiffness, and the damping of the drill tubular using a predefined damping criterion, wherein the predefined damping criterion includes a ratio, the ratio having a deflection at the drill bit of at least one mode in the plurality and an eigenfrequency of the at least one mode in the plurality, wherein the deflection at the drill bit is raised to a power other than one.

First claim

What is claimed is:

1. A method for reducing vibrations in a drill tubular coupled to a drill bit configured to drill a borehole in a formation, the method comprising:
constructing a mathematical model of a system comprising the drill tubular, the mathematical model comprising at least one of a mass distribution of the drill tubular, a stiffness of the drill tubular, and a damping of the drill tubular;
calculating a plurality of modes using the mathematical model; and
increasing an effective damping of the drill tubular for the plurality of modes by modifying at least one of the mass distribution of the drill tubular, the stiffness of the drill tubular, and the damping of the drill tubular using a predefined damping criterion that provides a criteria to limit vibrations resulting from self-excitation;
wherein the predefined damping criterion comprises a ratio, the ratio comprising a deflection at the drill bit of at least one of the plurality of modes and an eigenfrequency of the at least one of the plurality of modes, wherein the deflection at the drill bit is raised to a power larger than one.

2. The method according to claim 1 , wherein the predefined damping criterion further comprises a modal damping and a force model.

3. The method according to claim 2 , wherein the predefined damping criterion further comprises a derivative of the force model.

4. The method according to claim 3 , wherein the predefined damping criterion defines a limit for the derivative of the force model.

5. The method according to claim 2 , wherein the force model comprises a borehole wall force model of a force imposed on the drill tubular due to an interaction between the drill tubular and a wall of the borehole.

6. The method according to claim 2 , wherein the force model comprises a sum of forces imposed on the drill tubular, the sum of forces comprising a declining characteristic of aggressiveness of the drill bit with respect to a rotational speed of the drill tubular.

7. The method according to claim 2 , wherein the force model comprises a drill bit force model of a force applied to the drill bit while the drill bit is cutting the formation.

8. The method according to claim 7 , wherein the drill bit force model comprises a declining characteristic of aggressiveness of the drill bit with respect to a rotational speed of the drill tubular.

9. The method according to claim 2 , wherein modifying comprises changing the modal damping of the drill tubular.

10. The method according to claim 2 , wherein modifying comprises increasing the eigenfrequency.

11. The method according to claim 2 , wherein the force model comprises a declining characteristic of aggressiveness of the drill bit with respect to a rotational speed of the drill tubular and modifying comprises changing a rotational speed of the drill bit in order to reduce the vibrations.

12. The method according to claim 1 , wherein modifying comprises reducing the deflection at the drill bit.

13. The method according to claim 1 , wherein the mathematical model comprises a borehole wall force model of a force imposed on the drill tubular due to an interaction between the drill tubular and a wall of the borehole.

14. The method according to claim 1 , wherein the vibrations are at least one of torsional vibrations, axial vibrations, and lateral vibrations.

15. The method according to claim 1 , wherein the system further comprises the drill tubular disposed in a drilling fluid in the borehole.

16. The method according to claim 1 , wherein the drill tubular comprises at least one of a bottomhole assembly (BHA) and a borehole wall interaction component configured to contact a wall of the borehole.

17. The method according to claim 1 , wherein the drill tubular comprises a bottomhole assembly (BHA) having one or more downhole tools and modifying the mass distribution comprises moving the one or more downhole tools to a new location within the BHA.

18. The method according to claim 1 , wherein the increasing is limited by a predetermined constraint.

Assignees

• Hohl Andreas
• Tergeist Mathias
• Oueslati Hatem
• Herbig Christian
• Jain Jayesh J
• Reckmann Hanno
• Endres Lance A
• Baker Hughes A Ge Co Llc

Inventors

• Hohl Andreas
• Tergeist Mathias
• Oueslati Hatem
• Herbig Christian
• Jain Jayesh J
• Reckmann Hanno
• Endres Lance A

Classifications

• G06F30/17

  Mechanical parametric or variational design · CPC title

• E21B44/02 Primary

  Automatic control of the tool feed ({E21B44/005,} E21B44/10 take precedence) · CPC title

• E21B2200/20

  Computer models or simulations, e.g. for reservoirs under production, drill bits · CPC title