Internal drilling riser centralizer
The method of centralizing a rotating string within the bore of a subsea blowout preventer stack and a drilling riser comprising providing a multiplicity of rollers having a first position and a second position, when the rollers are in the first position the rollers defining a first circle which is proximately the size of the bore of the drilling riser, when the rollers are in the second position the rollers defining a second circle which is smaller than the first circle, and when the rollers are in the second position the rollers prevent the rotating string from contacting the bore of the subsea blowout preventer stack or the drilling riser proximate the rollers.
This invention relates to the general subject of centralizing the rotating pipe within a deepwater drilling riser to prevent key seating damage.
CROSS-REFERENCE TO RELATED APPLICATIONSNot applicable.
STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENTNot applicable
REFERENCE TO A “MICROFICHE APPENDIX”Not applicable
BACKGROUND OF THE INVENTIONThe field of this invention is that of offshore floating drilling systems for drilling oil and gas wells in offshore waters. These have a blowout preventer stack landed on a wellhead on the ocean floor with a drilling riser attached to the top and continuing up to a vessel floating at the ocean surface.
At the connection of the riser to the top of the blowout preventer stack there is typically a flex joint to keep the riser from being overstressed due to surface vessel movement, side forces from currents, or when the riser is allowed to be momentarily slack. An example of this type flex joint is seen in U.S. Pat. No. 5,951,061. This flex joint often represents a dog leg in the alignment of the bore of the blowout preventer stack and the bore of the drilling riser.
Within the bore of the drilling riser and the blowout preventer stack, a drill string is run in order to drill the oil or gas well. Typically the drill string is rotated during drilling, and often has hard facing on the coupling to prevent wear on them. When the drill string is rotated and is centrally located within the bore, there is no effect on the bore. However, when the riser is deflected, the drill string can be deflected to contact the bore of the drilling riser or the blowout prevent stack.
When the drill string is deflected to contact the bore of the drilling riser or blowout preventer stack, wear can be concentrated at the point of contact. Hard facing on the tool joints can make them act like a cutting tool to exacerbate the damage to the bore. In the worst case, a notch can be caused which is called a key seat.
A key seat in the bore of the drilling riser or blowout preventer stack can literally wear all the way through the metal. It will typically occur above the blowout preventer rams and so will not cause a blowout. Unfortunately a hole to the seawater will cause substantial pollution of the drilling mud into the seawater and loss of drilling mud pressure to control the pressure in the well. This loss of drill mud pressure will allow oil and gas to enter the well and require that the well be closed in or a blowout will occur.
This has been a common concern throughout the history of floating drilling since the early days in the 1960s until now, with the only solution being to closely monitor the position of the vessel to prevent this misalignment. In some cases such as drilling in the water off the coast of Alaska tidal movement of the vessels in relatively shallow water cause substantial deflection. This inflicts substantial wear on the drilling components which simply must be withstood.
BRIEF SUMMARY OF THE INVENTIONThe object of this invention is to provide a method to centralize an rotating drill string within the bore of a drilling riser and blowout preventer stack to prevent wear damage or key seating to the bore of the drilling riser or blowout preventer stack.
A second object of this invention is to provide a method to centralize an oscillating drill string within the bore of a drilling riser and blowout preventer stack to prevent wear damage or key seating to the bore of the drilling riser or blowout preventer stack.
A third object of this invention is to provide a method of removing the centralizing equipment from the bore so that equipment which is nearly the diameter of the full bore are able to pass by the centralizing equipment.
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In this way the internal bore 72 of the drilling riser centralizer 52 and similarly the bore 70 of the internal steel pipe 30 are protected from damage by the rotating pipe 62.
The particular embodiments disclosed above are illustrative only, as the invention may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the invention. Accordingly, the protection sought herein is as set forth in the claims below.
Claims
1. The method of centralizing a rotating string within the bore of a subsea blowout preventer stack and a drilling riser comprising:
- providing a multiplicity of guides having a first position and a second position,
- when said guides are in said first position said guides defining a first boundary which is proximately the size of the bore of the drilling riser,
- when said guides are in said second position said guides defining a second boundary which is smaller than said first boundary, and
- when said guides are in said second position said guides prevent said rotating string from contacting the bore of said subsea blowout preventer stack or said drilling riser proximate said guides.
2. The method of claim 1 further comprising said guides are moved between said first position and said second position by hydraulic cylinders.
3. The method of claim 2 further comprising said guides are rollers.
4. The method of claim 1 further comprising said guides are rollers.
5. The method of claim 1 further comprising said second boundary is proximately a circle.
6. The method of claim 5 further comprising said guides are rollers.
7. The method of claim 6 further comprising said guides are moved between said first position and said second position by hydraulic cylinders.
8. The method of claim 1 further comprising said guides are rollers.
9. In a subsea drilling system comprising a rotating or translating drilling string of pipe, a subsea blowout preventer stack, and a drilling riser extending to a floating vessel on the surface of the sea, and a flexible joint between said subsea blowout preventer stack and said drilling riser, said subsea blowout preventer stack having a minimum bore size and said drilling riser having a minimum bore size, and said flexible joint allowing said drilling riser bore to not be angularly aligned with said blowout preventer bore such that said rotating or translating drilling string of pipe can wear or “keyseat” the internal area of said subsea blowout preventer stack, said flexible joint, or said drilling riser, the method of preventing said wear or “keyseating” comprising providing a multiplicity of guides having a first position and a second position,
- when said guides are in said first position said guides defining a first boundary which is proximately the size of the bore of the drilling riser,
- when said guides are in said second position said guides defining a second boundary which is smaller than said first boundary, and
- when said guides are in said second position said guides prevent said rotating string from contacting the bore of said subsea blowout preventer stack or said drilling riser proximate said guides.
10. The method of claim 9 further comprising said guides are moved between said first position and said second position by hydraulic cylinders.
11. The method of claim 10 further comprising said guides are rollers.
12. The method of claim 9 further comprising said guides are rollers.
13. The method of claim 9 further comprising said second boundary is proximately a circle.
14. The method of claim 13 further comprising said guides are rollers.
15. The method of claim 14 further comprising said guides are moved between said first position and said second position by hydraulic cylinders.
16. The method of claim 9 further comprising said guides are rollers.
Type: Application
Filed: May 3, 2011
Publication Date: Nov 8, 2012
Inventor: Benton Frederick Baugh (Houston, TX)
Application Number: 13/068,062
International Classification: E21B 17/10 (20060101);