Downhole flow control, joint assembly and method

Patent metadata

Field	Value
Publication number	US-10012032-B2
Application number	US-201314418834-A
Country	US
Kind code	B2
Filing date	Oct 11, 2013
Priority date	Oct 26, 2012
Publication date	Jul 3, 2018
Grant date	Jul 3, 2018

Abstract

A method for completing a wellbore in a subsurface formation includes providing a first base pipe and a second base pipe. Each base pipe comprises a tubular body forming a primary flow path and has transport conduits along an outer diameter for transporting fluids as a secondary flow path. The method also includes connecting the base pipes using a coupling assembly. The coupling assembly has a manifold, and a flow port adjacent the manifold that places the primary flow path in fluid communication with the secondary flow path. The method also includes running the base pipes into the wellbore, and then causing fluid to travel between the primary and secondary flow paths. A wellbore completion apparatus is also provided that allows for control of fluid between the primary and secondary flow paths.

First claim

What is claimed is:

1. A method for completing a wellbore in a subsurface formation, the method comprising:
providing a first base pipe and a second base pipe, with each base pipe comprising:
a tubular body having a first end, a second end and a bore there between forming a primary flow path; and
at least two transport conduits along an outer diameter of the tubular body for transporting fluids as a secondary flow path;

operatively connecting the second end of the first base pipe to the first end of the second base pipe by means of a coupling assembly, the coupling assembly comprising providing;
a manifold region that forms at least a portion of the secondary flow path by fluidly communicating each of the transport conduits from the first base pipe with each of the transport conduits of the second base pipe,
a coupling joint comprising a main tubular body defining a bore in fluid communication with the primary flow path of the first base pipe and the second base pipe, the main tubular body having a first end and a second end, wherein the first end is threadedly connected to the second end of the first base pipe, and the second end is threadedly connected to the first end of the second base pipe;
a flow port that places at least a portion of the primary flow path in fluid communication with the manifold region of the secondary flow path;
a load sleeve mechanically connected proximate to the first end of the second base pipe; and
a torque sleeve mechanically connected proximate to the second end of the first base pipe;

coupling the first base pipe, the coupling assembly, and the second base pipe respectively in series with the coupling assembly intermediate the first base pipe and second base pipe;
running the coupled first base pipe, the coupling assembly, and the second base pipe into the wellbore; and
causing fluid to travel between the primary and secondary flow paths through the flow port.

2. The method of claim 1 , wherein each of the tubular bodies comprise perforated base pipes.

3. The method of claim 2 , wherein each of the base pipes comprises a series of perforated joints threadedly connected to form the primary flow path.

4. The method of claim 1 , wherein:
the load sleeve and the torque sleeve each comprises:
a tubular body defining an inner bore therein in fluid communication with the primary flow path, and
transport conduits disposed longitudinally along the tubular body in fluid communication with the secondary flow path; and
the coupling joint further comprises:
a coaxial sleeve positioned around the tubular body, the sleeve forming an annual region between the tubular body and the sleeve, with the annular region defining the manifold, and the manifold placing the transport conduits of the load sleeve and of the torque sleeve in fluid communication.

5. The method of claim 4 , wherein the flow port comprises (i) a through opening in the tubular body of the coupling joint, (ii) a through-opening in the second end of the first tubular body, (iii) a through-opening in the first end of the second tubular body, or (iv) combinations thereof.

6. The method of claim 1 , wherein each of the tubular bodies comprise blank, perforated, or slotted pipes having a filter medium radially around the base pipe and along a substantial portion of the base pipe so as to form a sand screen.

7. The method of claim 6 , wherein the filtering medium of each sand screen comprises a wire-wrapped screen, a slotted liner, a ceramic screen, a membrane screen, an expandable screen, a sintered metal screen, a wire-mesh screen, a shape memory polymer, or a pre-packed solid particle bed.

8. The method of claim 1 , wherein each of the at least two transport conduits along the second base pipe extends substantially along the length of the second base pipe.

9. The method of claim 1 , wherein each of the at least two transport conduits along the first base pipe extends substantially along the length of the first base pipe, but one of the at least two transport conduits has a nozzle intermediate the first and second ends of the first base pipe.

10. The method of claim 9 , wherein:
the nozzle comprises a valve; and
the method further comprises adjusting the valve to increase or decrease fluid flow through the valve.

11. The method of claim 1 , wherein at least one of the at least two transport conduits along the first base pipe has an outlet end intermediate the first and second ends of the first base pipe.

12. The method of claim 1 , wherein the at least two transport conduits have different inner diameters.

13. The method of claim 1 , further comprising:
producing hydrocarbon fluids through the base pipe of the first and second base pipes from at least one interval along the wellbore, wherein producing hydrocarbon fluids causes hydrocarbon fluids to travel from the secondary flow path to the primary flow path.

14. The method of claim 1 , further comprising:
injecting a fluid through the base pipe and into the wellbore along at least one interval, wherein injecting the fluid causes fluids to travel from the primary flow path to the secondary flow path.

15. The method of claim 14 , wherein the fluid comprises a gas, an aqueous solution, steam, diluent, solvent, fluid loss control material, viscosified gel, viscoelastic fluid, chelating agent, acid, or a chemical consolidation agent.

16. The method of claim 1 , further comprising:
placing a plug into the wellbore downstream from the first and second base pipes.

17. The method of claim 1 , further comprising:
providing a packer assembly comprising:
at least one sealing element,
an inner mandrel, and
transport conduits extending substantially along the inner mandrel; and
operatively connecting the packer assembly to the first end of the first base pipe such that the transport conduits of the packer assembly are in fluid communication with the transport conduits of the base pipes;
and wherein the step of running the base pipes and connected joint assembly into the wellbore further comprises running the packer assembly into the wellbore; and
the method further comprises setting the at least one sealing element into engagement with the surrounding wellbore.

18. The method of claim 17 , wherein:
the packer assembly comprises a mechanically set packer; and
setting the sealing element comprises setting the mechanically-set packer into engagement with the surrounding open-hole formation.

19. The method of claim 1 , wherein the transport conduits of the load sleeve and the transport conduits of the torque sleeve each defines about six transport conduits placed within and radially around its corresponding tubular body.

20. The method of claim 1 , wherein:
the coupling assembly further comprises an inflow control device adjacent an opening in the flow port; and
the method further comprises adjusting the inflow control device to increase or decrease fluid flow through the flow port.

21. The method of claim 20 , wherein the inflow control device is controlled by a radio frequency signal, a mechanical shifting tool, or hydraulic pressure.

22. A joint assembly residing within a wellbore, comprising:
a first base pipe and a second base pipe connected in series, each base pipe comprising:
a tubular body having a first end, a second end and a bore there between forming a primary flow path for fluids; and
at least two transport conduits along an outer diameter of the tubular body configured to transport fluids as a secon

Assignees

• Yeh Charles S
• Barry Michael D
• Hecker Michael T
• Moffett Tracy J
• Exxonmobil Upstream Res Co

Inventors

• Yeh Charles S
• Barry Michael D
• Hecker Michael T
• Moffett Tracy J

Classifications

• E21B43/14

  Obtaining from a multiple-zone well · CPC title

• E21B34/12

  operated by movement of casings or tubings · CPC title

• E21B33/124

  Units with longitudinally-spaced plugs for isolating the intermediate space · CPC title

• E21B43/168

  Injecting a gaseous medium · CPC title

• E21B43/084

  Screens comprising woven materials, e.g. mesh or cloth · CPC title