Bottomhole assembly (BHA) stabilizer or reamer position adjustment methods and systems employing a cost function

Patent metadata

Field	Value
Publication number	US-11352841-B2
Application number	US-201616330536-A
Country	US
Kind code	B2
Filing date	Dec 8, 2016
Priority date	Dec 8, 2016
Publication date	Jun 7, 2022
Grant date	Jun 7, 2022

Abstract

A system that includes a drillstring with a bottomhole assembly (BHA). The system also includes at least one stabilizer or reamer integrated with the BHA, wherein each of the at least one stabilizer or reamer includes a position adjustment assembly. The system also includes a processing unit that provides control signals to each position adjustment assembly, wherein the control signals are based on a cost function.

First claim

What is claimed is:

1. A system that comprises:
a drillstring with a bottomhole assembly (BHA);
at least one stabilizer or reamer integrated with the BHA, wherein each of the at least one stabilizer or reamer includes a position adjustment assembly; and
a processing unit that provides control signals to each position adjustment assembly, wherein:
the control signals minimize a cost function; and
finite element based discrete system dynamics for the BHA are described as:
X ( k+ 1)= f BHA Mechanical [ X ( k )]+ f fluid damping [ X ( k )]+ f drill bits [ X ( k )]+ g [ u ( k )]+Uncertainty( k )
y ( k+ 1)= h [ X ( k )]

where:
X is a vector consisting of multiple dynamic states of the system;
f, g, and h represent linear and non-linear functions that describe a dynamic equation, including BHA finite element beam dynamics f BHA , drilling fluid damping dynamics f fluid damping , and drill bits dynamics f drill bits ;
y is a control output (stabilizer relative position along the BHA y=x 2 ;
u is a control input command to a stabilizer actuator;
uncertainty(k) is an uncertainty expected a dynamic model;
k is a discrete time step; and
k+1 is a next sampling time step following time step k.

2. The system of claim 1 , wherein the cost function accounts for predicted BHA states and a position range for each stabilizer or reamer.

3. The system of claim 1 , wherein each position adjustment assembly is configured to adjust at least an axial position of a respective stabilizer or reamer along the BHA.

4. The system of claim 1 , wherein the at least one stabilizer comprises a plurality of axially-spaced stabilizers.

5. The system of claim 1 , wherein the position adjustment assembly comprises a position lock/unlock component.

6. The system of claim 1 , wherein the position adjustment assembly comprises an actuator component.

7. The system of claim 1 , wherein the position adjustment assembly comprises a sliding track component or roller component.

8. The system of claim 1 , wherein the cost function includes at least four of a vibration magnitude term, a stabilizer or reamer position term, a drill bit wear term, a trajectory error term, an uncertainty term, a stabilizer or reamer wear term, a rate of penetration term, and a borehole tortuosity term.

9. The system of claim 8 , wherein the processing unit applies weights to at least some of the terms of the cost function.

10. The system of claim 8 , wherein the processing unit adjusts at least some of the terms or term weights of the cost function over time.

11. The system of claim 1 , further comprising a data storage in communication with the processing unit, wherein the data storage stores a look-up table (LUT) of values related to the cost function, and wherein the processing unit selects the control signals based at least in part on the LUT values.

12. The system according to claim 1 , wherein the processing unit is part of the BHA.

13. A method that comprises:
deploying a drillstring in a borehole, the drillstring having a bottomhole assembly (BHA) with at least one stabilizer or reamer, each stabilizer or reamer having a position adjustment assembly;
generating, by a processing unit, control signals for each position adjustment assembly minimize a cost function; and
adjusting, by at least one position adjustment assembly, a position of each respective stabilizer or reamer in response to the control signals; wherein finite element based discrete system dynamics for the BHA are described as:
X ( k+ 1)= f BHA Mechanical [ X ( k )]+ f fluid damping [ X ( k )]+ f drill bits [ X ( k )]+ g [ u ( k )]+Uncertainty( k )
y ( k+ 1)= h [ X ( k )]

where:
X is a vector consisting of multiple dynamic states of the system;
f, g, and h represent linear and non-linear functions that describe a dynamic equation, including BHA finite element beam dynamics f BHA , drilling fluid damping dynamics f fluid damping , and drill bits dynamics f drill bits ;
y is a control output (stabilizer relative position along the BHA y=x 2 ;
u is a control input command to a stabilizer actuator;
uncertainty(k) is an uncertainty expected a dynamic model;
k is a discrete time step; and
k+1 is a next sampling time step following time step k.

14. The method of claim 13 , further comprising obtaining, by a processing unit, predicted BHA states, wherein the cost function accounts for the predicted BHA states and a position range for each stabilizer or reamer.

15. The method of claim 13 , wherein said adjusting comprises operating a lock/unlock component of the position adjustment assembly.

16. The method of claim 13 , wherein said adjusting comprises operating an actuator component of the position adjustment assembly.

17. The method of claim 13 , wherein the cost function includes at least four of a vibration magnitude term, a stabilizer or reamer position term, a drill bit wear term, a trajectory error term, an uncertainty term, a stabilizer or reamer wear term, a rate of penetration term, and a borehole tortuosity term.

18. The method of claim 17 , further comprising adjusting at least some of the terms or term weights of the cost function over time.

19. The method according to claim 13 , further comprising applying the cost function to a time-domain optimization problem to select control signals for each position adjustment assembly.

20. The method according to claim 13 , further comprising applying the cost function to a frequency-domain optimization problem to select control signals for each position adjustment assembly.

Assignees

• Halliburton Energy Services Inc

Inventors

• Dykstra Jason D
• Song Xingyong
• Vadali Venkata Madhukanth

Classifications

• E21B17/10

  Wear protectors; Centralising devices {, e.g. stabilisers} · CPC title

• E21B17/1078 Primary

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

• E21B44/00

  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

• E21B10/30 Primary

  Longitudinal axis roller reamers, e.g. reamer stabilisers · CPC title