Contingent continuous circulation drilling system

Patent metadata

Field	Value
Publication number	US-9316071-B2
Application number	US-201313748161-A
Country	US
Kind code	B2
Filing date	Jan 23, 2013
Priority date	Jan 23, 2013
Publication date	Apr 19, 2016
Grant date	Apr 19, 2016

Abstract

A method for deploying a tubular string into a wellbore includes: injecting fluid through a top drive and flow sub into a top of the tubular string and lowering the tubular string into the wellbore. The flow sub: connects the tubular string top to a quill of the top drive, is in a top injection mode, and has a closed port and an open bore. The method further includes halting injection of the fluid through the top drive and lowering of the tubular string. The method further includes, while injection and lowering are halted: disconnecting the flow sub from the tubular string top; adding one or more tubular joints to the tubular string and connecting the flow sub to a top of the added joints. The method further includes resuming injection of the fluid through the top drive and lowering of the tubular string.

First claim

The invention claimed is:

1. A method for deploying a tubular string into a wellbore, comprising:
injecting fluid through a top drive and a flow sub into a top of the tubular string and lowering the tubular string into the wellbore, wherein:
the flow sub connects the tubular string top to a quill of the top drive,
the flow sub is in a top injection mode, and
the flow sub has:
a closed port formed through a wall thereof, and
an open bore conducting the fluid from the quill into the tubular string top;

halting injection of the fluid through the top drive and the tubular string and halting lowering of the tubular string;
while injection and lowering are halted:
disconnecting the flow sub from the tubular string top;
adding one or more tubular joints to the tubular string; and
connecting the flow sub to a top of the added joints; and

resuming injection of the fluid through the top drive and lowering of the tubular string.

2. The method of claim 1 , further comprising:
halting lowering of the tubular string;
while lowering is halted, shifting the flow sub to a side injection mode, thereby opening the port and closing the bore, and injecting the fluid into the port; and
while injecting the fluid into the port:
halting injection of the fluid through the top drive;
disconnecting the quill from the flow sub; and
adding a stand to the tubular string, the stand having a second flow sub and one or more of the tubular joints.

3. The method of claim 2 ,
further comprising monitoring an exposed formation adjacent to the wellbore for instability,
wherein the flow sub is shifted to the side injection mode in response to detection of the instability.

4. The method of claim 3 , wherein the formation is monitored by:
measuring a flow rate of the injected fluid;
measuring a flow rate of fluid returning from the wellbore; and
comparing the flow rates.

5. The method of claim 2 , wherein each flow sub comprises:
a port valve for closing the port in the top injection mode and for opening the port in the side injection mode, and
a bore valve operably coupled to the port valve for opening the bore in the top injection mode and for closing the bore in the side injection mode.

6. The method of claim 5 , wherein:
the flow sub is shifted to the side injection mode by:
engaging the flow sub with a clamp; and
operating an automated actuator of the clamp to open the port valve, thereby also closing the bore valve, and

the fluid is injected into the port via an inlet of the clamp.

7. The method of claim 1 , wherein:
the tubular string is a drill string having a drill bit disposed at a bottom thereof,
the fluid is mud, and
the method further comprises rotating the drill bit while injecting the mud and lowering the drill string, thereby drilling the wellbore.

8. The method of claim 1 , further comprising:
halting lowering of the tubular string due to failure of the top drive; and
while lowering is halted:
shifting the flow sub to a side injection mode, thereby opening the port and closing the bore, and injecting the fluid into the port; and
while injecting the fluid into the port:
disconnecting the quill from the flow sub; and
servicing or replacing the top drive.

9. A top drive system, comprising:
a flow sub, comprising:
a tubular housing having: a longitudinal bore formed therethrough, a flow port formed through a wall thereof, an upper coupling, and a lower coupling for connection to a tubular;
a bore valve operable between an open position and a closed position, wherein the bore valve allows free passage through the bore in the open position and isolates an upper portion of the bore from a lower portion of the bore in the closed position; and
a valve member for selectively opening and closing the flow port; and

a top drive comprising:
a motor operable to rotate a quill;
a swivel having an inlet for receiving a kelly hose and an outlet in fluid communication with the quill; and
a backup wrench movable between an upper position and a lower position,

wherein:
the motor, swivel, and backup wrench are connected together to form a frame of the top drive,
the upper coupling is connected to the quill,
the backup wrench is engageable with an upper portion of the tubular housing in the upper position,
the backup wrench is engageable with a threaded coupling of the tubular housing in the lower position,
the valve member is a sleeve,
the sleeve is disposed in the tubular housing,
the sleeve is movable between an open position where the flow port is exposed to the bore and a closed position where a wall of the sleeve is disposed between the flow port and the bore, and
the flow sub further comprises a bore valve actuator operably coupling the sleeve and the bore valve such that opening the sleeve closes the bore valve and closing the sleeve opens the bore valve.

10. The system of claim 9 , further comprising a clamp comprising:
an inlet for injecting fluid into the flow port and operable to engage the valve member and seal against a surface of the tubular housing adjacent to the flow port; and
an automated valve actuator for operating the valve member to open and close the port.

11. The system of claim 9 ,
further comprising an internal blowout preventer comprising a valve member, a seat, and a linkage operable by the top drive to open and close the valve member,
wherein the internal blowout preventer connects the flow sub to the quill.

12. The system of claim 9 , further comprising a torque sub comprising a turns counter and a torque shaft having a load cell and connecting the flow sub to the quill.

13. The system of claim 9 , further comprising a mud saver valve operable to open in response to fluid pumped through the top drive and to close in response to cessation of pumping.

14. A method for deploying a tubular string into a wellbore, comprising:
injecting fluid through a top drive and a flow sub into a top of the tubular string and lowering the tubular string into the wellbore, wherein:
the flow sub connects the tubular string top to a quill of the top drive,
the flow sub is in a top injection mode, and
the flow sub has:
a port formed through a wall thereof,
a valve member closing the port, and
an open bore conducting the fluid from the quill into the tubular string top;

halting lowering of the tubular string; and
while lowering is halted, shifting the flow sub to a side injection mode, thereby moving the valve member to open the port and closing the bore, and injecting the fluid into an annulus of the wellbore, thereby circulating from the annulus, up a bore of the tubular string, and to the port.

15. A method for deploying a tubular string into a wellbore, comprising:
injecting fluid into an annulus of the wellbore, thereby circulating from the annulus, up a bore of the tubular string, and to an open port of a flow sub connected to a top of the tubular string and lowering the tubular string into the wellbore,
wherein:
the tubular string has a bottomhole assembly,
the bottomhole assembly includes a reverse circulation drill bit and a drilling motor, and
the drilling motor utilizes the injected fluid to rotate the drill bit, thereby drilling the wellbore;

halting injection of the fluid through the annulus and the tubular string and halting lowering of the tubular string;
while lowering is halted:
disconnecting the flow sub from the tubular string top;
adding one or more tubular joints to the tubular string and connecting the flow sub to a top of the added joints; and

resuming lowering of the tubular string.

Assignees

• Weatherford Technology Holdings Llc

Inventors

• Feasey Guy F

Classifications

• E21B33/064

  specially adapted for underwater well heads · CPC title

• E21B19/006

  including heave compensators · CPC title

• E21B21/08 Primary

  Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure (valve arrangements therefor E21B21/10) · CPC title

• E21B19/16

  Connecting or disconnecting pipe couplings or joints (E21B19/20 takes precedence) · CPC title

• E21B3/022

  Top drives · CPC title