Systems and methods of controlling downhole behavior

Patent metadata

Field	Value
Publication number	US-12018556-B2
Application number	US-201917272370-A
Country	US
Kind code	B2
Filing date	Aug 27, 2019
Priority date	Aug 29, 2018
Publication date	Jun 25, 2024
Grant date	Jun 25, 2024

Abstract

A bit used in a downhole environment has an active element that is movable relative to the bit. The bit is rotated in the downhole environment, and at least one downhole parameter is measured. The at least one downhole parameter is compared against a target parameter value, and when the at least one downhole parameter is beyond a threshold value of the target parameter value, the active element is selectively relative to the bit. Movement of the active element alters the proportion of the weight on the active element as compared to the other cutting structure of the bit. Changing the proportion of weight can be used to reduce the depth of cut of the cutting structure and to reduce or eliminate motor stall or stick-slip behavior.

First claim

What is claimed is:

1. A system for drilling a wellbore, the system comprising:
a bottomhole assembly (BHA) including:
a cutting tool having a body, a cutting structure comprising a plurality of cutting elements, and a longitudinal axis oriented in a longitudinal direction;
an active element connected to the body along the longitudinal axis, the active element moveable relative to the body at least partially in the longitudinal direction of the cutting tool, the active element comprising an ultrahard element;
an actuator coupled to the active element and configured to move the active element;
at least one sensor, the sensor configured to measure at least one downhole parameter; and
at least one processor in communication with the at least one sensor and the actuator to move the active element based on a difference between the at least one downhole parameter and an actuation threshold or deactivation threshold value of a target parameter, wherein the actuation and deactivation threshold values are different.

2. The system of claim 1 , the at least one sensor being a rotational speed sensor positioned in the BHA to measure a rotational speed of the cutting tool, and wherein the processor is further configured to calculate the difference between the at least one downhole parameter and the target parameter by comparing the rotational speed of the cutting tool to a historical value of a cutting tool rotational speed, or to a rotational speed of a torque source of the cutting tool.

3. The system of claim 1 , the at least one sensor being a formation sensor configured to measure at least one formation property.

4. The system of claim 1 , the at least one sensor being a force sensor positioned in the BHA and configured to measure a weight-on-bit (WOB), wherein the processor is further configured to calculate the difference between the at least one downhole parameter received from the at least one sensor and the target parameter by comparing the WOB to a target WOB.

5. The system of claim 1 , the at least one sensor being a torque sensor positioned in the BHA to measure a torque on the cutting tool, wherein the processor is further configured to calculate the difference between the at least one downhole parameter received from the at least one sensor and the target parameter by comparing the torque on the cutting tool to a torque applied by a torque source.

6. The system of claim 1 , further comprising a downhole motor that provides torque to rotate the bit, the at least one sensor including one or more pressure sensor positioned to measure a pressure drop across the downhole motor.

7. The system of claim 1 , the active element having a maximum stroke between 0.1 in. (0.25 cm) and 1.5 in. (3.81).

8. A system for drilling a wellbore, the system comprising:
a bit having a longitudinal axis about which the bit is rotatable;
an active element positioned in the bit, the active element moveable relative to the bit along the longitudinal axis;
an actuator that applies a force to the active element to move the active element;
at least one sensor configured to measure at least one downhole parameter; and
a processor in communication with the at least one sensor and the actuator to move the active element toward an extended state when the at least one downhole parameter exceeds an actuation threshold value and move the active element toward a retracted state when the at least one downhole parameter is within a deactivation threshold value, and wherein the actuation threshold value is different from the deactivation threshold value.

9. The system of claim 8 , the deactivation threshold value being closer to a target parameter than the activation threshold value.

10. The system of claim 8 , the at least one sensor being a first sensor, the at least one downhole parameter being a first downhole parameter, and the actuation threshold value being a first actuation threshold value, the system further comprising:
a second sensor, where the processor is configured to actuate the actuator to move the active element a first distance when the first downhole parameter exceeds the first actuation threshold value, and the processor is configured to move the active element a second distance when a second downhole parameter from the second sensor exceeds a second actuation threshold value.

11. The system of claim 8 , the at least one downhole parameter being a first downhole parameter and the actuation threshold value being a first actuation threshold value, the processor further being configured to move the active element a first distance when the first downhole exceeds the first actuation threshold value, and the processor is configured to move the active element a second distance when a second downhole parameter exceeds a second actuation threshold value.

12. The system of claim 11 , the first downhole parameter and the second downhole parameter being the same downhole parameter, and the first actuation threshold value and the second actuation threshold value are different magnitudes for the same downhole parameter.

13. A method of controlling a bit, comprising:
tripping the bit into a downhole environment, the bit having an active element that is movable relative to the bit along a longitudinal axis of the bit;
applying torque to the bit in the downhole environment;
measuring a rotational speed of the bit;
comparing the rotational speed against a target parameter value; and
when the rotational speed is beyond an actuation threshold value of the target parameter value and/or within a deactivation threshold value of the target parameter, moving the active element relative to the bit, wherein the actuation threshold value is different from the deactivation threshold value.

14. The method of claim 13 , wherein moving the active element relative to the bit includes controlling a valve between a closed state and at least one open state and thereby applying a hydraulic force that moves the active element.

15. The method of claim 13 , the target parameter value being a rolling average of the rotational speed.

16. The method of claim 15 , the rolling average being a first rolling average and the actuation threshold value being a first actuation threshold value, wherein comparing the rotational speed against the target parameter value includes:
calculating a second rolling average of the rotational speed, the first rolling average and second rolling average being averaged over different time periods; and
comparing the second rolling average to the first actuation threshold value or to a second actuation threshold value.

17. The method of claim 16 , wherein moving the active element relative to the bit includes moving the active element relative to the bit when either the second rolling average exceeds the first actuation threshold value, or the second rolling average exceeds the second actuation threshold value.

18. The method of claim 13 , the bit including a cutting structure separate from the active element, wherein the cutting structure separate from the active element is axially fixed relative to the longitudinal axis of the bit.

Assignees

• Schlumberger Technology Corp

Inventors

• Mahajan Manoj D
• Woolston Scott Richard
• Hall Huntington Tracy
• Marshall Jonathan D

Classifications

• E21B10/62 Primary

  characterised by parts, e.g. cutting elements, which are detachable or adjustable (E21B10/64 takes precedence; for roller bits E21B10/20; for augers E21B10/44) · 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

• E21B10/43

  characterised by the arrangement of teeth or other cutting elements · CPC title

• E21B47/013

  Devices specially adapted for supporting measuring instruments on drill bits · CPC title

• E21B44/04 Primary

  in response to the torque of the drive {; Measuring drilling torque (E21B44/06 takes precedence; measuring stresses in a well bore pipe E21B47/007)} · CPC title