Methods and apparatus for drilling with a multiphase pump
View Patent ↗The present invention generally relates to an apparatus and method for removing hydrocarbons and other material from a wellbore. In one aspect, a method of drilling a sub-sea wellbore is provided. The method includes circulating a drilling fluid through a drill string from a surface of the sea to a drill bit in the wellbore. The method further includes pumping the fluid and drill cuttings from the sea floor to the surface with a multiphase pump having at least two plungers operating in a predetermined phase relationship. In another aspect, a fluid separator system having a first and a second plunger assembly is provided. The fluid separator system includes at least one fluid line for removing a fluid portion from the at least one plunger assembly and at least one gas line for removing gas from the first and a second plunger assembly.
1. A method of drilling a subsea wellbore, comprising: circulating a drilling fluid through a first flow path to a drill bit in the wellbore, the fluid flowing upwards in a second flow path within the wellbore; and pumping the fluid and drill cuttings from the second flow path to a fluid handling system having at least two plungers operating in a predetermined phase relationship.
2. The method of claim 1 , wherein the at least two plungers operate substantially counter synchronously.
3. The method of claim 2 , wherein the plungers are moved in a first direction by the fluid and in a second direction by power fluid provided from the surface.
4. The method of claim 1 , wherein the fluid handling system is disposed at a sea floor.
5. The method of claim 1 , wherein the fluid handling system is disposed on a riser at a location between the surface and a sea floor.
6. A method of transporting cuttings from a subsea wellbore, comprising: urging the cuttings in a fluid slurry from an annular area in the wellbore to a pump assembly in fluid communication with the wellbore; utilizing the slurry to operate at least one plunger member of the pump assembly in a first direction; and utilizing a power fluid to operate the at least one plunger in a second direction, thereby pumping the slurry towards the surface of the sea.
7. A method of reducing equivalent circulating density in a subsea wellbore, comprising: pumping a fluid through a drill pipe from a surface of water to a drill bit in a wellbore; circulating the fluid and cuttings to the top of the wellbore; and adding energy to the fluid and cuttings with a multi-phase pump, thereby urging the fluid and cuttings to the surface.
8. The method of claim 7 , wherein the multi-phase pump includes at least two plungers operating in a predetermined phase relationship.
9. The method of claim 8 , wherein plungers operate substantially counter synchronously.
10. A sub-sea fluid pumping system, comprising: a pair of substantially counter synchronous fluid pumps locatable adjacent a sub-sea wellbore and in fluid communication with an annulus therein; at least one fluid path for communicating wellbore fluid between the annulus and the fluid pumps; and at least one power fluid line for providing power fluid to the fluid pumps.
11. The system of claim 10 , wherein the pair of substantially counter synchronous fluid pumps are a pair of plungers, each plunger movable between an extended position and a retracted position.
12. The system of claim 11 , wherein the wellbore fluid urges the plunger to the extended position.
13. The system of claim 11 , further including a control line for providing a fluid to urge the plunger to the extended position.
14. The system of claim 11 , wherein the power fluid urges the plunger to the retracted position.
15. The system of claim 11 , further including a seal assembly disposed around each plunger to constantly scrape and polish each plunger as it moves between the extended position and the retracted position.
16. The system of claim 15 , wherein the seal assembly includes a plurality of rings disposed on either side of a sealant.
17. The system of claim 16 , wherein the sealant is remotely injected during the operation of the fluid pumps.
18. The system of claim 10 , further including a pulsation control assembly to control the back pressure in a sub-sea wellbore due to the movement of the pair of substantially counter synchronous fluid pumps.
19. The system of claim 18 , wherein the pulsation control assembly includes an accumulator piston disposed in a gas filled accumulator.
20. The system of claim 10 , further including a plurality of upper valves to control the amount of power fluid to the pair of fluid pumps.
21. The system of claim 10 , further including a plurality of lower valves to control the amount of wellbore fluid entering the pair of fluid pumps and the amount of discharge fluid exiting the pair of fluid pumps.
22. The system of claim 10 , wherein the fluid pumps are operatively connected to a guide base.
23. The system of claim 22 , wherein the fluid pumps may be individually inserted and retrieved from the guide base.
24. The system of claim 10 , further including a gas line for removing gas from the pair of fluid pumps to prevent gas lock during a pump cycle.
25. The system of claim 10 , wherein the fluid pumps are operatively connected to a riser pipe.
26. A sub-sea fluid pumping system, comprising: a pair of substantially counter synchronous fluid pumps disposed on a riser pipe at a location between a surface and a sea floor, whereby the fluid pumps are in fluid communication with an annulus of a sub-sea wellbore; at least one fluid path for communicating wellbore fluid between the annulus and the fluid pumps; and at least one power fluid line for providing power fluid to the fluid pumps.
27. The system of claim 26 , wherein the pair of substantially counter synchronous fluid pumps are a pair of plungers, each plunger movable between an extended position and a retracted position.
28. The system of claim 26 , wherein the fluid pumps may be individually inserted and retrieved from the riser pipe.