Powered wellbore bailer

• US 9,334,704 B2
• Filed: 09/27/2012
• Issued: 05/10/2016
• Est. Priority Date: 09/27/2012
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Mineo, Richard, Bellotte, Dominick Joseph
• Primary Examiner(s): GAY, JENNIFER HAWKINS
• Application Number:
  US14/429,260
• Publication Number:
  US 20150240583A1
• Time in Patent Office: 1,321 Days
• US Class Current: 1/1
• CPC Class Codes: E21B 2200/04 Ball valves
• CPC Class Codes: E21B 27/04 where the collecting or depositing means include helical conveying means
• CPC Class Codes: E21B 34/06 in wells
• CPC Class Codes: E21B 34/063 Valve or closure with destructible element, e.g. frangible disc E21B34/103 takes precedence

Abstract

A wellbore bailer has a rotary motor coupling, a cylinder having an open end, and a pump in the cylinder coupled to the rotary motor coupling and configured to pump fluid when rotated via the coupling. A closure of the bailer is changeable between sealing and allowing flow through the open end.

Claims

1. A wellbore bailer, comprising:

a rotary motor coupling;

a rotary downhole motor coupled to the rotary motor coupling, the rotary downhole motor comprising a downhole power unit configured to provide power to operate the rotary downhole motor in response to an actuation signal from an electrical conductor of a well wireline;

a cylinder having an open end;

a pump in the cylinder coupled to the rotary motor coupling and configured to pump fluid when rotated via the coupling, where the pump comprises a central shaft carrying a helical blade that extends outward from the shaft and defining a helical fluid chamber substantially the length of pump, and where the helical blade seals with an interior wall of the cylinder; and

a closure changeable between sealing and allowing flow through the open end.

2. The wellbore bailer of claim 1, wherein the downhole power unit comprises a battery.

3. The wellbore bailer of claim 1, further comprising an electrical coupling coupled to the downhole motor and adapted to couple to the electrical conductor of the well wireline.

4. The wellbore bailer of claim 1, where the closure comprises a check valve.

5. The wellbore bailer of claim 4, where the check valve comprises a ball in the cylinder that seals the opening against flow out of the cylinder.

6. The wellbore bailer of claim 1, where the closure comprises a frangible plate.

7. The wellbore bailer of claim 6, where the pump is axially moveable into the frangible plate to break the frangible plate.

8. The wellbore bailer of claim 1, where the pump is configured to pump fluid out of the cylinder when rotated via the coupling.

9. The wellbore bailer of claim 1, where the pump is configured to pump solids entrained in fluid into the cylinder when rotated via the coupling.

10. The wellbore bailer of claim 1, further comprising an actuator to trigger the motor based on pressure or time.

11. The wellbore bailer of claim 1, where the downhole power unit is configured to provide electric power to operate the rotary downhole motor.

12. The wellbore bailer of claim 11, where the downhole power unit is configured to provide electric power to operate the rotary downhole motor independent of power provided through the well wireline.

13. The wellbore bailer of claim 1, where the pump is configured to operate independently of a jerking movement of the well wireline.

14. A method, comprising:

rotating a pump of a wellbore bailer with a downhole motor, the downhole motor comprising a downhole power unit that provides power to operate the downhole motor in response to an actuation signal from an electrical conductor of a well wireline, where rotating the pump of a wellbore bailer with the downhole motor comprises rotating a central shaft carrying a helical blade that extends outward from the shaft defining a helical fluid chamber substantially the length of the pump, and where the helical blade seals with an interior wall of a cylinder of the pump;

in response to rotating the pump, pumping fluids between a wellbore and the helical fluid chamber, where pumping fluids between a wellbore and a chamber of the wellbore bailer comprises pumping fluids out of the chamber into the wellbore; and

shifting the pump axially to break a frangible plate sealing the chamber.

15. The method of claim 14, where rotating the pump of the wellbore bailer with the downhole motor comprises powering the downhole motor with a battery of the downhole power unit.

16. A wellbore bailer, comprising:

a cylinder having a central bore, an open end, and a vent hole;

a pump residing in the central bore of the cylinder, the pump comprising a rotatable central shaft carrying a helical blade that extends outward from the shaft and defining a helical fluid chamber substantially the length of pump, the helical blade sealing with an interior wall of the cylinder,

a closure changeable between sealing and allowing flow through the open end of the cylinder;

a rotary downhole motor operatively coupled to the shaft of the pump via a rotary motor coupling and configured to rotate the shaft to pump fluid and solids entrained in the fluid into the bore of the cylinder towards the vent hole, and further configured to rotate the shaft at a speed that allows the helical blade to cause the solids entrained in the fluid to settled out of the fluid within the helical fluid chamber as the fluid is pumped towards the vent hole.

17. The wellbore bailer of claim 16, wherein the rotary downhole motor comprises a downhole power unit configured to provide power to operate the rotary downhole motor in response to an actuation signal.

18. The wellbore bailer of claim 17, wherein the downhole power unit comprises a battery.

19. The wellbore bailer of claim 16, wherein the rotary motor coupling comprises a gear system to drive the shaft at a different rotational speed than the rotary downhole motor.