Downhole swivel apparatus and method

• US 8,316,945 B2
• Filed: 11/20/2007
• Issued: 11/27/2012
• Est. Priority Date: 11/30/2004
• Status: Active Grant

• Current Assignee: Mako Rentals, Inc.
• Original Assignee: Mako Rentals, Inc.
• Inventors: Robichaux, Kip M., Caillouet, Kenneth G., Robichaux, Terry P.
• Primary Examiner(s): BUCK, MATTHEW R
• Application Number:
  US11/943,012
• Publication Number:
  US 20080105439A1
• Time in Patent Office: 1,834 Days
• Field of Search: 166/339, 166/363, 166/348, 166/367, 166/177.4, 166/292, 166/255, 166/359, 166/285, 166/291, 162/85, 162/91, 175/5
• US Class Current: 166/339
• CPC Class Codes: E21B 17/01 Risers
• CPC Class Codes: E21B 17/05 Swivel joints
• CPC Class Codes: E21B 21/001 specially adapted for underwater drilling dual gradient drilling E21B21/082
• CPC Class Codes: E21B 33/038 Connectors used on well heads, e.g. for connecting blow-out preventer and riser
• CPC Class Codes: E21B 33/06 Blow-out preventers , i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers rotating blow-out preventers E21B33/085
• CPC Class Codes: E21B 33/064 specially adapted for underwater well heads
• CPC Class Codes: E21B 33/085 Rotatable packing means, e.g. rotating blow-out preventers
• CPC Class Codes: E21B 41/0007 for underwater installations E21B41/005, E21B41/04, E21B41/06, E21B41/08, E21B41/10 take precedence
• CPC Class Codes: E21B 7/12 Underwater drilling using heave compensators E21B19/09

Abstract

What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

Claims

1. A method of removing fluid from an oil well in a marine environment, the oil well having a well bore with a longitudinal axis, a riser, and a drill string inside the riser, the method comprising the following steps:

(a) attaching a swivel to the drill string, the swivel including a mandrel and a sleeve, the sleeve being rotatably connected to the mandrel, the sleeve including at least one catch for an annular seal of an annular blowout preventer, the sleeve being longitudinally reciprocable relative to the mandrel;

(b) inserting the swivel into the riser, the riser being in fluid communication with the well bore;

(c) connecting the riser and well bore to an annular blowout preventer, the annular blowout preventer having an annular seal the connection being made by closing the annular seal on the sleeve, the annular blow-out preventer being located at a first level, the riser and well bore being at least partially filled with a first fluid, the first fluid being at a level in the riser which is above the first level, the at least one catch restricting longitudinal movement of the sleeve relative to the annular blow out preventer when a high differential pressure exists above and below the closed annular seal, the high differential pressure placing a longitudinal force on the sleeve along the longitudinal axis, and which force attempts to push the sleeve outside of the closed annular seal;

(d) the swivel and annular blowout preventer separating the first fluid into an upper section of the first fluid that is located above the first level, and a lower section of the first fluid that is located below the first level;

(e) displacing a portion of the lower section of the first fluid; and

(f) displacing a portion of the upper section of the first fluid.

2. The method of claim 1, wherein in steps “

e” and

“

f”

a second fluid is used for displacement.

3. The method of claim 2, wherein in step “

e”

a second fluid is used for displacement.

4. The method of claim 3, wherein in step “

f”

a third fluid is used for displacement.

5. The method of claim 4, wherein the second fluid is the same as the third fluid.

6. The method of claim 1, wherein the first fluid is a well drilling fluid.

7. The method of claim 1, wherein step “

e”

is performed before step “

f”

.

8. The method of claim 1, wherein step “

e”

is performed after step “

f”

.

9. The method of claim 1, wherein the drill string is rotated continuously for a set period of time.

10. The method of claim 1, wherein the drill string is rotated intermittently for a set period of time.

11. The method of claim 1, wherein the drill string is rotated reciprocally for a set period of time.

12. The method of claim 9, wherein the drill string is rotated between about thirty to ninety revolutions per minute.

13. The method of claim 9, wherein the drill string is rotated at about ninety revolutions per minute.

14. The method of claim 1, wherein in step “

c”

, the sleeve includes two catches which are spaced apart and which both tend to restrict longitudinal movement relative to the annular blow out preventer.

15. The method of claim 14, wherein each catch is radially symmetric relative to the sleeve.

16. The method of claim 14, wherein each catch includes at least one portion which is frustroconical.

17. The method of claim 14, wherein the catches and sleeve are fabricated from a single piece of stock material.

18. The method of claim 14, wherein the catches are large enough to contact the supporting structure for the annular seal of the annular blowout preventer.