COMPACT CABLE SUSPENDED PUMPING SYSTEM FOR LUBRICATOR DEPLOYMENT

• US 20110300008A1
• Filed: 06/04/2010
• Published: 12/08/2011
• Est. Priority Date: 06/04/2010
• Status: Active Grant

• Current Assignee: Zeitecs B.V. (SLB)
• Original Assignee: Zeitecs B.V. (SLB)
• Inventors: Fielder, Lance I., Crowley, Matthew
• Granted Patent: US 8,534,366 B2
• Time in Patent Office: Days
• US Class Current: 417/410.3
• CPC Class Codes: E21B 19/002 specially adapted for underwater drilling E21B19/09, E21B19/143 take precedence
• CPC Class Codes: E21B 33/072 for cable-operated tools E21B33/076 takes precedence
• CPC Class Codes: E21B 33/076 specially adapted for underwater installations
• CPC Class Codes: E21B 43/128 Adaptation of pump systems with down-hole electric drives
• CPC Class Codes: F04B 47/02 the driving mechanisms being situated at ground level F04B47/12 takes precedence
• CPC Class Codes: F04D 13/10 adapted for use in mining bore holes
• CPC Class Codes: F04D 27/00 Control, e.g. regulation, of pumps, pumping installations or pumping systems specially adapted for elastic fluids
• CPC Class Codes: F04D 29/606 Mounting in cavities

Abstract

A method of installing or retrieving a pumping system into or from a live wellbore includes connecting a lubricator to a production tree of the live wellbore and raising or lowering one or more downhole components of the pumping system from or into the wellbore using the lubricator.

Claims

1. A method of installing or retrieving a pumping system into or from a live wellbore, comprising:

connecting a lubricator to a production tree of the live wellbore; and

raising or lowering one or more downhole components of the pumping system from or into the wellbore using the lubricator.

2. The method of claim 1, further comprising:

deploying a running tool into the tree using the lubricator;

engaging the running tool with a hanger of the pumping system;

raising the running tool and pump hanger into the lubricator, thereby also raising the downhole components of the pumping system;

raising the running tool and pump hanger out of the lubricator;

raising the downhole components into the lubricator; and

raising the downhole components out of the lubricator.

3. The method of claim 1, wherein the downhole components comprise a high speed motor, an isolation device operable to engage production tubing disposed in the wellbore, and a high speed pump.

4. The method of claim 3, wherein the downhole component further comprise a power conversion module (PCM) operable to receive a DC power signal from the pump cable.

5. The method of claim 3, wherein the pump comprises a rotor having one or more helicoidal vanes.

6. The method of claim 3, wherein the motor is a switched reluctance or brushless DC motor.

7. The method of claim 1, wherein the production tree is located at a floor of the sea and the method is performed riserlessly.

8. The method of claim 7, further comprising:

washing the component while in the lubricator using a washing fluid; and

discharging the spent washing fluid into the wellbore.

9. The method of claim 7, wherein the hanger is connected to an internal electrical system of the tree.

10. The method of claim 7, wherein the method is performed while maintaining a double barrier between the wellbore and the sea.

11. The method of claim 1, further comprising:

servicing or replacing the pumping assembly;

installing the serviced/replacement pumping assembly into the wellbore and tree using the lubricator; and

producing hydrocarbon fluid from the wellbore using the serviced/replacement pumping assembly.

12. The method of claim 2, further comprising:

engaging an upper seal of the lubricator with a deployment cable connected to the running tool;

engaging a lower seal of the lubricator with a pump cable of the pumping system;

disengaging the upper seal from the deployment cable;

engaging the upper seal with the pump cable;

disengaging the lower seal from the pump cable;

closing a valve of the lubricator;

disengaging the upper seal from the pump cable; and

raising the downhole components out of the lubricator.

13. A method of retrieving a pumping system from a live wellbore, comprising:

engaging an upper seal of a lubricator with a deployment cable;

connecting the lubricator to a production tree of the live wellbore;

deploying a running tool into the tree using the deployment cable;

engaging the running tool with a hanger of the pumping system;

raising the running tool and pump hanger into the lubricator;

engaging a lower seal of the lubricator with a pump cable of the pumping system;

disengaging the upper seal from the deployment cable;

raising the running tool and pump hanger out of the lubricator;

engaging the upper seal with the pump cable;

disengaging the lower seal from the pump cable;

raising downhole components of the pumping system into the lubricator;

closing a valve of the lubricator;

disengaging the upper seal from the pump cable; and

raising the downhole components out of the lubricator.

14. A method of retrofitting a production tree for compatibility with a pumping system, comprising:

connecting a marine riser to a production tree of the wellbore;

retrieving a first production tubing hanger from the tree through the riser;

replacing the first tubing hanger with a second tubing hanger having an electrical interface disposed along an inner surface thereof;

installing an electric submersible pump assembly (ESP) into the tree and the wellbore, wherein a pump hanger of the ESP engages the electrical interface; and

operating the ESP by supplying electricity from the tree to a pump cable of the pumping system via the electrical interface.

15. A pumping system, comprising:

a submersible high speed electric motor operable to rotate a drive shaft;

a high speed pump rotationally connected to the drive shaft and comprising a rotor having one or more helicoidal vanes;

an isolation device operable to expand into engagement with a production tubing string, thereby fluidly isolating an inlet of the pump from an outlet of the pump and rotationally connecting the motor and the pump to the casing string;

a cable having two or less conductors and a strength sufficient to support the motor, the pump, the isolation device, and a power conversion module (PCM); and

the PCM operable to receive a DC power signal from the cable, and supply a second power signal to the motor.

16. The pumping system of claim 15, further comprising a pump hanger having electrical contacts disposed along an outer surface thereof.

17. The pumping system of claim 15, wherein:

the pump further comprises a stator having a housing and a diffuser, and

a Venturi passage is formed between the rotor and the housing and between the housing and the diffuser.

18. The pumping system of claim 17, wherein:

the diffuser has one or more vanes located at a throat of the Venturi, and the diffuser vanes are operable to negate swirl imparted by the helicoidal vanes.

19. The pumping system of claim 15, further comprising a lubricator comprising a tool housing operable to contain the pump, motor, isolation device, and PCM.

20. The pumping system of claim 19, wherein:

the lubricator further comprises first and second seals,

each seal is operable between an extended position and a retracted position, and

each seal clears a bore in the retracted position,

and seals against the cable in the extended position.

21. The pumping system of claim 20, wherein:

the lubricator further comprises a lander operable to fasten to a profile of a production tree, and

a bypass conduit extending between the tool housing and the lander.

22. The pumping system of claim 20, wherein the lubricator further comprises:

one or more blow out preventers, and

a shutoff valve.

23. The pumping system of claim 15, wherein the pump further comprises one or more stages, each stage comprising:

a tubular housing;

a mandrel disposed in the housing and comprising;

the rotor rotatable relative to the housing and having;

an impeller portion,

a shaft portion,

the helicoidal vanes extending along the impeller portion, a diffuser;

connected to the housing,

having the shaft portion extending therethrough, and

having one or more vanes operable to negate swirl imparted to

fluid pumped through the impeller portion; and

a fluid passage formed between the housing and the mandrel and having a nozzle section, a throat section, and a diffuser section.

24. A submersible pump having one or more stages, each stage comprising:

a tubular housing;

a mandrel disposed in the housing and comprising;

a rotor rotatable relative to the housing and having;

an impeller portion,

a shaft portion, and

one or more helicoidal vanes extending along the impeller portion, and

a diffuser;

connected to the housing,

having the shaft portion extending therethrough, and

having one or more vanes operable to negate swirl imparted to fluid pumped through the impeller portion; and

a fluid passage formed between the housing and the mandrel and having a nozzle section, a throat section, and a diffuser section.

25. A subsea production tree, comprising:

a head having a bore therethrough and a production passage formed through a wall thereof;

a wellhead connector; and

a production tubing hanger oriented within and fastened to the head and having;

an outer electrical interface providing electrical communication between the head and the tubing hanger,

an inner electrical interface for providing electrical communication with a pump hanger of an electric submersible pump assembly,

one or more leads extending between the interfaces,

a bore therethrough, and

a production passage formed through a wall thereof, wherein the tubing hanger is oriented so that the tubing hanger production passage is aligned with the head production passage.