Rotational downlinking to rotary steerable system

• US 9,822,633 B2
• Filed: 10/02/2014
• Issued: 11/21/2017
• Est. Priority Date: 10/22/2013
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Sugiura, Junichi
• Primary Examiner(s): Gay, Jennifer H
• Assistant Examiner(s): BUTCHER, CAROLINE N
• Application Number:
  US14/505,463
• Publication Number:
  US 20150107903A1
• Time in Patent Office: 1,146 Days
• Field of Search: None
• CPC Class Codes: E21B 3/00 Rotary drilling
• CPC Class Codes: E21B 44/00 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 Class Codes: E21B 44/005 Below-ground automatic control systems
• CPC Class Codes: E21B 47/12 Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
• CPC Class Codes: E21B 7/06 Deflecting the direction of boreholes

Abstract

A downhole steering tool comprising a first member, fixedly coupled with a drill string, and a second member, proximate the first member and rotatable substantially freely with respect to the first member. A first sensor is operable to measure a difference in rotation rates of the first and second members. A second sensor is operable to measure a substantially real-time rotation rate of the second member in the wellbore. A tool controller is operable to process sensor signals from the first and second sensors to determine a rotation rate of the drill string. Surface-initiated changes in the rotation rate of the drill string are then utilized by the downhole steering tool for steering and other control.

Claims

1. An apparatus, comprising:

a downhole steering tool conveyed in a wellbore via a drill string, the downhole steering tool deployed between a drilling motor and a drill bit in the drill string, wherein the downhole steering tool comprises;

a collar fixedly coupled with the drill string;

a roll-stabilized sensor housing deployed in the collar and disposed to rotate freely with respect to the collar, the roll-stabilized housing deployed axially between first and second torquers configured to apply torque to the roll-stabilized housing;

a first sensor operable to measure a difference in rotation rates between the collar and the roll-stabilized housing, the first sensor including a magnetic marker deployed on the collar and a magnetic sensor deployed in the roll-stabilized housing;

a second sensor deployed in the roll-stabilized housing and operable to measure a rotation rate of the roll-stabilized housing in the wellbore; and

a tool controller deployed in the roll-stabilized housing and operable to process sensor signals from the first and second sensors to determine a rotation rate of the drill string and (ii) decode an encoding language comprising codes that are represented in the encoding language as predefined sequences of varying rotation rates of the drill string to receive commands from a surface location to control the downhole steering tool; and

a surface controller operable at the surface location to send downlink codes to the tool controller in the form of a predefined sequence of varying rotation rates of the drill string to control the downhole steering tool, wherein the predefined sequence of varying rotation rates of the drill string are achieved via modulation of a drilling fluid flow rate in the drill string to modulate a rotation rate of the drilling motor and thereby modulate a rotation rate of the collar.

2. The apparatus of claim 1 wherein the roll-stabilized sensor housing has a rotation rate with respect to the wellbore that is less than a rotation rate of the drill string.

3. The apparatus of claim 1 wherein the roll-stabilized sensor housing is non-rotating with respect to the wellbore.

4. The apparatus of claim 1 wherein the second sensor is or comprises at least one of an accelerometer, a magnetometer, and/or a gyroscopic sensor.

5. The apparatus of claim 1 wherein the downhole steering tool is part of a rotary-steerable system, and wherein the tool controller is operable to process the sensor signals and decode the encoding language while the rotary-steerable system is operated to elongate the wellbore.

6. The apparatus of claim 1, wherein the magnetic sensor deployed in the roll-stabilized housing comprises a magnetometer.

7. The apparatus of claim 6, wherein the magnetometer comprises a two-axis magnetometer.

8. The apparatus of claim 1, wherein the tool controller is further operable to receive said modulating the drilling fluid flow rate at one or both of the first and second torquers and to correlate said modulating the drilling fluid flow rate with said varying rotation rates to decode the encoding language.

9. A method, comprising:

(a) deploying a drill string in a subterranean wellbore, wherein the drill string includes a steering tool deployed between a drilling motor and a drill bit, and wherein the steering tool comprises;

a collar coupled with the drill string;

a roll-stabilized sensor housing deployed in the collar and disposed to rotate freely with respect to the collar, the roll-stabilized housing deployed axially between first and second torquers configured to apply torque to the roll-stabilized housing;

a rotation measurement device operable to measure relative rotation rate between the collar and the roll-stabilized housing, the rotation rate measurement device including a magnetic marker deployed on the collar and a magnetic sensor deployed in the roll-stabilized housing; and

a sensor deployed in the roll-stabilized housing and operable to measure the rotation rate of the roll-stabilized housing in the wellbore;

(b) rotating the drill string at a first rotation rate, wherein rotating the drill string at the first rotation rate rotates the collar at the first rotation rate; and

(c) transmitting a signal to the steering tool by;

modulating a drilling fluid flow rate in the drill string to modulate a rotation rate of the drilling motor and thereby modulate a rotation rate of the collar such that the collar rotates at a second rotation rate for a first predetermined period of time, wherein the second rotation rate is different than the first rotation rate and rotating the drill string at a third rotation rate for a second predetermined period of time, wherein the third rotation rate is different than the first and second rotation rates.

10. The method of claim 9 wherein the second rotation rate differs from each of the first and third rotation rates by at least ten revolutions per minute.

11. The method of claim 9, further comprising:

(d) causing a tool controller located in the steering tool to receive the signal transmitted in (c) by;

processing sensor signals from the rotation measurement device and the sensor to measure said modulated rotation rate of the collar;

receiving said modulating the drilling fluid flow rate at one or both of the first and second torquers; and

correlating said modulating the drilling fluid flow rate with said modulated rotation rate of the collar to decode the signal transmitted in (c).

12. An apparatus, comprising:

a downhole steering tool conveyed in a wellbore via a drill string, the downhole steering tool is deployed between a drilling motor and a drill bit in the drill string, wherein the downhole steering tool comprises;

a collar fixedly coupled with the drill string;

a roll-stabilized sensor housing deployed in the collar and disposed to rotate freely with respect to the collar, the roll-stabilized housing deployed axially between first and second torquers configured to apply torque to the roll-stabilized housing;

a first sensor operable to measure a difference in rotation rates between the collar and the roll-stabilized housing, the first sensor including a magnetic marker deployed on the collar and a magnetic sensor deployed in the roll-stabilized housing;

a second sensor deployed in the roll-stabilized housing and operable to measure a rotation rate of the roll-stabilized housing in the wellbore;

a tool controller deployed in the roll-stabilized housing and operable to;

process sensor signals from the first and second sensors to determine a rotation rate of the drill string; and

decode an encoding language comprising codes that are represented in the encoding language as predefined sequences of varying rotation rates of the drill string to communicate with a surface location to control the downhole steering tool; and

a surface controller operable at the surface location to send downlink codes to the tool controller in the form of a predefined sequence of varying rotation rates of the drill string to control the downhole steering tool;

the surface controller being operable to automatically control the sequence of varying rotation rates of the drill string to send downlink codes to the to the steering tool, wherein the surface controller is configured to send the downlink codes to the tool controller in the form of a predefined sequence of varying rotation rates via modulating a drilling fluid flow rate in the drill string, the modulating operative to modulate a rotation rate of the drilling motor and thereby modulate a rotation rate of the collar.

13. The apparatus of claim 12 wherein the wellbore extends from a wellsite surface to a subterranean formation, and wherein the tool controller is further operable to interpret downlink signals transmitted from the wellsite surface as predefined variations in the rotation rate of the drill string, wherein the downlink signals are encoded with the encoding language as the predefined variations.

14. The apparatus of claim 13 wherein the downhole steering tool is part of a rotary-steerable system, and wherein the tool controller is operable to process the sensor signals and decode the encoding language while the rotary-steerable system is operated to elongate the wellbore.

15. The apparatus of claim 12, wherein the tool controller is further operable to a filter the rotation rate of the drill string via a digital filter.

16. The apparatus of claim 12, wherein the tool controller is further operable to receive said modulating the drilling fluid flow rate at one or both of the first and second torquers and to correlate said modulating the drilling fluid flow rate with said varying rotation rates to decode the encoding language.