Method and apparatus for transitioning between rotary drilling and slide drilling while maintaining a bit of a bottom hole assembly on a wellbore bottom

Patent metadata

Field	Value
Publication number	US-11559149-B2
Application number	US-202016993665-A
Country	US
Kind code	B2
Filing date	Aug 14, 2020
Priority date	Aug 14, 2020
Publication date	Jan 24, 2023
Grant date	Jan 24, 2023

Abstract

A method of transitioning from rotary to slide drilling while maintaining a bit of a bottom hole assembly (“BHA”) on a wellbore bottom includes (a) recording a first toolface value of the BHA that is coupled to a drill string; (b) identifying a correlation between the first toolface value and a first quill position of a quill coupled to the drill string; (c) identifying a breakover torque for the drill string; (d) performing rotary drilling; (e) recording a second toolface value while the bit remains on the wellbore bottom; (f) receiving, while the bit remains on the wellbore bottom, a target toolface value; (g) calculating, while the bit remains on the wellbore bottom, an unwind amount to unwind the drill string; and (h) unwinding the drill string by the unwind amount to bring the second toolface value closer to the target toolface value while the bit remains on the bottom.

First claim

What is claimed is:

1. A method of transitioning from rotary drilling to slide drilling while maintaining a bit of a bottom hole assembly on a wellbore bottom, wherein the method comprises:
(a) recording a first measured toolface value of the bottom hole assembly, wherein the bottom hole assembly is coupled to a drill string;
(b) identifying a correlation between the first measured toolface value and a first quill position of a quill coupled to the drill string;
(c) identifying a breakover torque for the drill string;
(d) performing rotary drilling;
(e) recording a second measured toolface value while the bit remains on the wellbore bottom;
(f) receiving, while the bit remains on the wellbore bottom, a target toolface value;
(g) calculating, while the bit remains on the wellbore bottom, an unwind amount to unwind the drill string; and
(h) unwinding the drill string by the unwind amount to bring the second measured toolface value closer to the target toolface value while the bit remains on the wellbore bottom,
wherein each of the second measured toolface value, the unwind amount, and the target toolface value is expressed in degrees;
wherein calculating the unwind amount comprises:
calculating a clockwise radial distance expressed in degrees between the second measured toolface value and the target toolface value; and

subtracting the clockwise radial distance from the breakover torque to determine the unwind amount.

2. The method of claim 1 , wherein when the second measured toolface value is greater than the target toolface value, then the clockwise radial distance is a difference—of 360 degrees and the second measured toolface value—added to the target toolface value.

3. The method of claim 1 , wherein when the target toolface value is greater than the second measured toolface value, then the clockwise radial distance is the difference between the target toolface value and the second measured toolface value.

4. The method of claim 1 , which further comprises:
increasing a weight on bit (“WOB”) after unwinding the drill string;
oscillating the drill string; and
beginning slide drilling.

5. The method of claim 4 , wherein the following steps (a)-(c) occur during an operation to add a stand of pipe to the drill string, and wherein the operation to add the stand of pipe occurs prior to the beginning of the slide drilling.

6. The method of claim 1 ,
wherein the drill string is not rotating when the first measured toolface value is recorded; and
wherein identifying the correlation between the first measured toolface value and the first quill position comprises referencing rotation of the drill string relative to the first quill position.

7. The method of claim 1 , wherein identifying the breakover torque for the drill string comprises:
capturing a torque measurement while increasing a rotations per minute (“RPM”) of the drill string; and
recording a number of revolutions required to reach maximum off-bottom rotating torque as the breakover torque.

8. The method of claim 1 ,
wherein performing rotary drilling comprises rotary drilling at a WOB indicator setpoint and a flow rate setpoint; and
wherein the method further comprises, after performing rotary drilling and before the second measured toolface value is recorded, reducing an RPM of the drill string to zero while maintaining the WOB indicator at the WOB indicator setpoint and the flow rate at the flow rate setpoint.

9. An apparatus adapted to transition a bit of a bottom hole assembly from a rotary drilling operation to a slide drilling operation while maintaining the bit on a wellbore bottom, the apparatus comprising:
a non-transitory computer readable medium having stored thereon a plurality of instructions, wherein the instructions are executed with at least one processor so that the following steps are executed:
(a) recording a first measured toolface value of the bottom hole assembly, wherein the bottom hole assembly is coupled to a drill string;
(b) identifying a correlation between the first measured toolface value and a first quill position of a quill coupled to the drill string;
(c) identifying a breakover torque for the drill string;
(d) performing rotary drilling;
(e) recording a second measured toolface value while the bit remains on the wellbore bottom;
(f) receiving, while the bit remains on the wellbore bottom, a target toolface value;
(g) calculating, while the bit remains on the wellbore bottom, an unwind amount to unwind the drill string; and
(h) unwinding the drill string by the unwind amount to bring the second measured toolface value closer to the target toolface value while the bit remains on the wellbore bottom,
wherein the instructions are executed with the at least one processor so that the following additional steps are executed:
increasing a weight on bit (“WOB”) after unwinding the drill string; and
beginning slide drilling.

10. The apparatus of claim 9 ,
wherein each of the second measured toolface value, the unwind amount, and the target toolface value is expressed in degrees;
wherein calculating the unwind amount comprises:
calculating a clockwise radial distance expressed in degrees between the second measured toolface value and the target toolface value; and
subtracting the clockwise radial distance from the breakover torque to determine the unwind amount.

11. The apparatus of claim 10 , wherein when the second measured toolface value is greater than the target toolface value, then the clockwise radial distance is a difference—of 360 degrees and the second measured toolface value—added to the target toolface value.

12. The apparatus of claim 10 , wherein when the target toolface value is greater than the second measured toolface value, then the clockwise radial distance is the difference between the target toolface value and the second measured toolface value.

Assignees

• Nabors Drilling Tech Usa Inc

Inventors

• Groover Austin
• Coffey Scott
• Curran Drew
• Lacroix Adam

Classifications

• A47F7/145 Primary

  Terraced shelves · 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

• E21B7/04

  Directional drilling · CPC title

• A47F5/01

  made of tubes or wire ({A47F5/0807 takes precedence} foldable or adjustable A47F5/13) · CPC title

• E21B47/024

  of devices in the borehole (determining slope or direction of the borehole E21B47/022) · CPC title