Systems and methods to inhibit packoff formation during drilling assembly removal from a wellbore

Patent metadata

Field	Value
Publication number	US-9291019-B2
Application number	US-201213717164-A
Country	US
Kind code	B2
Filing date	Dec 17, 2012
Priority date	Dec 20, 2011
Publication date	Mar 22, 2016
Grant date	Mar 22, 2016

Abstract

Systems and methods to inhibit packoff during drilling assembly removal from a wellbore, utilizing a drilling assembly that includes a transition region between a first section having a first cross-sectional area and a second section having a second cross-sectional area, wherein the second cross-sectional area is greater than the first cross-sectional area. The transition region includes a fluidizing assembly configured to partially fluidize a portion of the cuttings bed that is proximal to the transition region, and/or be in fluid communication with a flow control assembly configured to control flow rate of a fluidizing stream from the fluidizing assembly and to the portion of cuttings bed.

First claim

The invention claimed is:

1. A drill rig, comprising:
a drilling assembly configured to drill a wellbore, the drilling assembly comprising:
a first section having a first cross-sectional area;
a second section having a second cross-sectional area, wherein the first cross-sectional area is less than the second cross-sectional area, and further wherein the first section is farther from a terminal end of the drilling assembly than the second section;
a fluid conduit, wherein the first section and the second section define at least a portion of the fluid conduit, and further wherein the fluid conduit is configured to transmit a drilling fluid stream to the terminal end of the drilling assembly;
a transition region between the first section and the second section;
a fluidizing assembly configured to fluidize a portion of a cuttings bed proximal the transition region;
and a flow control assembly configured to selectively divert a portion of the drilling fluid stream to the fluidizing assembly, wherein the fluidizing assembly is configured to provide the portion of the drilling fluid stream to the portion of the cuttings bed as a fluidizing stream;

a mechanical drive assembly in mechanical communication with the drilling assembly;
a fluid supply assembly in fluid communication with the drilling assembly and configured to supply the drilling fluid stream to the drilling assembly; and
a controller configured to control the operation of the drill rig;
wherein the controller is configured to increase the portion of the drilling fluid stream that is supplied to the fluidizing assembly responsive to detecting at least one of a hook load that is greater than a maximum hook load threshold, a wellbore pressure that is greater than a maximum wellbore pressure threshold, and a wellbore diameter proximal to the fluidizing assembly that is greater than a maximum threshold wellbore diameter, and further wherein the controller is configured to decrease the portion of the drilling fluid stream that is supplied to the fluidizing assembly responsive to detecting at least one of a hook load that is less than a minimum hook load threshold, a wellbore pressure that is less than a minimum wellbore pressure threshold, and a wellbore diameter proximal to the fluidizing assembly that is less than a minimum threshold wellbore diameter.

2. A method of removing a drilling assembly from a wellbore, wherein the drilling assembly includes a transition region between a first section including a first cross-sectional area and a second section including a second cross-sectional area, wherein the first cross-sectional area is less than the second cross-sectional area, wherein the first section is farther from a terminal end of the drilling assembly than the second section, and further wherein the drilling assembly includes a fluid conduit configured to transmit a drilling fluid stream, the method comprising:
withdrawing at least a portion of the drilling assembly from the wellbore;
detecting a variable associated with packoff within the wellbore; and
providing a fluidizing stream to a portion of a cuttings bed proximal the transition region, wherein the fluidizing stream includes a portion of the drilling fluid stream, and further wherein the providing includes selectively providing the fluidizing stream based at least in part on the variable associated with packoff.

3. The method of claim 2 , wherein the variable associated with packoff includes at least one of a hook load, a down-hole pressure, a surface pressure, a down-hole torque, a surface torque, a fraction of the drilling fluid stream that comprises the fluidizing stream, an average diameter of the wellbore, a diameter of a portion of the wellbore, a diameter of a portion of the wellbore that is proximal to the transition region, the first cross-sectional area, the second cross-sectional area, an orientation of the wellbore, and an orientation of a portion of the wellbore that is proximal to the transition region.

4. The method of claim 2 , wherein the selectively providing includes controlling a flow rate of the fluidizing stream.

5. The method of claim 2 , wherein the selectively providing includes selectively providing 1 to 60% of the drilling fluid stream as the fluidizing stream.

6. The method of claim 2 , wherein the selectively providing includes increasing a flow rate of the fluidizing stream responsive to detecting at least one of a hook load that is greater than a maximum hook load threshold, a wellbore pressure that is greater than a maximum wellbore pressure, a torque that is greater than a maximum torque, and a wellbore diameter proximal to the transition region that is greater than a maximum threshold wellbore diameter, and further wherein the selectively providing includes decreasing the flow rate of the fluidizing stream responsive to detecting at least one of a hook load that is less than a minimum hook load threshold, a wellbore pressure that is less than a minimum wellbore pressure, and a wellbore diameter proximal to the transition region that is less than a minimum threshold wellbore diameter.

7. The method of claim 2 , wherein the providing includes selectively providing the fluidizing stream based at least in part on a variable associated with the drilling assembly, wherein the variable associated with the drilling assembly includes at least one of an orientation of the drilling assembly within the wellbore, an orientation of a fluidizing assembly within the wellbore, and a distance between the transition region and the portion of the cuttings bed.

8. The method of claim 2 , wherein the drilling assembly includes a fluidizing assembly that includes a plurality of fluid orifices, and further wherein the providing includes selectively providing the fluidizing stream to a selected one of the plurality of fluid orifices responsive at least in part to at least one of an orientation of the selected one of the plurality of fluid orifices and a location of the selected one of the plurality of fluid orifices with respect to a location of the portion of the cuttings bed.

9. The method of claim 8 , wherein the method includes providing the fluidizing stream to the selected one of the plurality of fluid orifices responsive to the selected one of the plurality of fluid orifices being within a threshold distance of the portion of the cuttings bed.

10. The method of claim 8 , wherein the drilling assembly includes an orientation detection device configured to detect an orientation of each of the plurality of fluid orifices, wherein the method further includes detecting the orientation of each of the plurality of fluid orifices, and further wherein the method includes providing the fluidizing stream to the selected one of the plurality of fluid orifices responsive to detecting that the selected one of the plurality of fluid orifices is within a threshold distance of a bottom surface of the wellbore.

11. The method of claim 8 , wherein the selected one of the plurality of fluid orifices includes an orientation control assembly configured to control an orientation of the selected one of the plurality of orifices with respect to at least one of the drilling assembly, the wellbore, and the cuttings bed, and further wherein the method includes controlling the orientation of the selected one of the plurality of fluid orifices, wherein the controlling includes directing a portion of the fluidizing stream that flows through the selected one of the plurality of fluid orifices toward the cuttings bed.

12. The method of claim 8 , wherein the selectively providing includes selectively providing the fluidizing stream to a base of the cuttings bed.

Assignees

• Aphale Chinar R
• Valsecchi Pietro
• Wallace Jon M
• Zhou Fuping
• Exxonmobil Upstream Res Co

Inventors

• Aphale Chinar R
• Valsecchi Pietro
• Wallace Jon M
• Zhou Fuping

Classifications

• E21B31/03 Primary

  Freeing by flushing · CPC title

• E21B21/00

  Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor (freeing objects stuck in boreholes by flushing E21B31/03) · CPC title

• E21B21/10

  Valve arrangements in drilling-fluid circulation systems · CPC title

• E21B23/04

  operated by fluid means, e.g. actuated by explosion (E21B23/08 takes precedence) · CPC title

• E21B41/0078

  Nozzles used in boreholes (drilling by liquid or gas jets E21B7/18; drill bits with nozzles E21B10/60; perforators using direct fluid action E21B43/114; obtaining a slurry of minerals using nozzles E21B43/29) · CPC title