Fluid stabbing dog

Patent metadata

Field	Value
Publication number	US-9422789-B2
Application number	US-201514752866-A
Country	US
Kind code	B2
Filing date	Jun 27, 2015
Priority date	Mar 15, 2013
Publication date	Aug 23, 2016
Grant date	Aug 23, 2016

Abstract

A diverter system having stabbing dogs is provided. In one embodiment, such a system includes a diverter, a housing, and a plurality of stabbing dogs coupled to the housing. The stabbing dogs are positioned to enable locking elements of the stabbing dogs to be extended into recesses in the diverter to secure the diverter within the housing. At least one of the recesses in the diverter is connected to a fluid conduit within the diverter, and at least one stabbing dog includes a fluid passage that enables fluid to be routed into the fluid conduit within the diverter through the at least one stabbing dog. Additional systems, devices, and methods are also disclosed.

First claim

The invention claimed is:

1. A system comprising:
a first component;
a second component; and
a plurality of stabbing dogs coupled to the second component and positioned to enable locking elements of the plurality of stabbing dogs to be extended into recesses in the first component to secure the first component to the second component, wherein at least one of the recesses in the first component is connected to a fluid conduit within the first component and at least one stabbing dog of the plurality of stabbing dogs includes a fluid passage that enables fluid to be routed into the fluid conduit within the first component through the at least one stabbing dog.

2. The system of claim 1 , wherein the at least one stabbing dog includes a stabbing dog housing, an extendable locking element within the stabbing dog housing, and a male stab having the fluid passage disposed within the extendable locking element.

3. The system of claim 2 , comprising a spacer disposed between the male stab and the extendable locking element.

4. The system of claim 3 , wherein the spacer is spaced apart from the male stab to allow the male stab to float within the spacer.

5. The system of claim 2 , comprising a female receptacle mounted within the at least one recess and configured to receive the male stab, the female receptacle including a cage disposed between two seals configured to seal against the male stab, the cage having openings to allow fluid to pass from the male stab, through the openings in the cage, out of fluid ports in the female receptacle, and into the fluid conduit.

6. The system of claim 2 , wherein the stabbing dog housing includes fluid ports that enable the extendable locking element to be hydraulically driven within the stabbing dog housing.

7. The system of claim 1 , wherein the first component includes an annular preventer having a piston and the fluid conduit enables fluid to be routed through the at least one stabbing dog to the piston to operate the annular preventer.

8. The system of claim 7 , wherein the at least one stabbing dog includes:
a first stabbing dog in fluid communication with the annular preventer to enable the piston to be hydraulically driven to close a packer of the annular preventer; and
a second stabbing dog in fluid communication with the annular preventer to enable the piston to be hydraulically driven to open the packer of the annular preventer.

9. The system of claim 1 , comprising a seal between the first component and the second component.

10. The system of claim 9 , wherein the at least one stabbing dog includes a stabbing dog in fluid communication with the seal in a manner that enables fluid from the stabbing dog to energize the seal between the first component and the second component.

11. The system of claim 1 , comprising a marine riser including the first component.

12. A system comprising:
an oilfield component including hydraulic functions;
a support structure; and
locking dogs for physically locking the oilfield component to the support structure, wherein the locking dogs include moveable hydraulic stabs configured to route hydraulic control fluid into the oilfield component to enable control of the hydraulic functions of the oilfield component, and wherein the moveable hydraulic stabs are extended into recesses to lock the oilfield component to the support structure.

13. The system of claim 12 , wherein the oilfield component includes a diverter, the support structure includes a diverter housing, and the locking dogs are mounted on the diverter housing with the moveable hydraulic stabs extended into recesses in the diverter to lock the diverter to the diverter housing.

14. The system of claim 13 , comprising a diverter control unit.

15. The system of claim 14 , wherein the diverter housing includes a connection plate for making fluid connections between the diverter control unit and the locking dogs.

16. A method comprising:
positioning a first oilfield component within a second oilfield component;
extending a locking dog to retain the first oilfield component in the second oilfield component, wherein extending the locking dog also connects a fluid conduit within the locking dog to a fluid conduit within the first oilfield component; and
routing hydraulic control fluid into the fluid conduit within the first oilfield component through the fluid conduit within the locking dog.

17. The method of claim 16 , wherein the locking dog is mounted on the second oilfield component and extending the locking dog includes extending the locking dog into a recess in the first oilfield component.

18. The method of claim 16 , wherein the first oilfield component includes a diverter and the second oilfield component includes a diverter housing, and extending the locking dog includes extending the locking dog into a recess in the diverter to retain the diverter within the diverter housing.

19. The method of claim 18 , comprising extending multiple locking dogs to retain the diverter in the diverter housing such that stabs in the multiple locking dogs are placed in fluid communication with respective fluid conduits of the diverter.

Assignees

• Cameron Int Corp

Inventors

• Bushman Jerod C
• Hankins John B
• Hoefler John A
• Tenorio Harold A

Classifications

• E21B21/106 Primary

  Valve arrangements outside the borehole, e.g. kelly valves (valves specifically for maintaining circulation of drilling fluid while connecting or disconnecting tubular joints E21B21/019) · CPC title

• E21B41/0007

  for underwater installations (E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence) · CPC title

• E21B17/01

  Risers · CPC title

• E21B19/004 Primary

  supporting a riser from a drilling or production platform · CPC title

• E21B21/001

  specially adapted for underwater drilling (dual gradient drilling E21B21/082) · CPC title