Artificial lift assembly

1. A method comprising:

introducing into a wellbore an artificial lift assembly on a tubing string, wherein the artificial lift assembly comprises:

an electrical submersible pumping system having a permanent magnet motor;

a rupture disc located in the tubing string, wherein the rupture disc prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by the fluid flow during introduction of the artificial lift assembly; and

a sleeve located in the tubing string above the electrical submersible pump having an inner profile defined on an inner surface of the sleeve, wherein the inner profile is configured to mate with and lock in place a wellbore dart such that the wellbore dart engages the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by fluid flow;

rupturing the rupture disc after introduction of the artificial lift assembly into the wellbore so that fluid flow through the electrical submersible pumping system is allowed; and

operating the electrical submersible pumping system within the wellbore.

2. The method of claim 1 , wherein the rupture disc is made of steel or polymer and is configured to have a predetermined rupture pressure, and wherein the method further comprises introducing a fluid in the tubing string uphole of the rupture disc after the introduction of the artificial lift assembly into the wellbore such that the pressure uphole from the rupture disc exceeds the predetermined rupture pressure thus rupturing the rupture disc so that fluid flow through the electrical submersible pumping system is allowed.

3. The method of claim 2 , further comprising:

introducing the wellbore dart into the wellbore such that the wellbore dart engages the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by fluid flow, wherein the wellbore dart has an outer profile defined on an outer surface of the wellbore dart, the outer profile configured to mate with the sleeve such that the wellbore dart is held in place within the sleeve and prevents the fluid flow through the electrical submersible pumping system.

4. The method of claim 3 , further comprising:

removing the artificial lift assembly from the wellbore after the wellbore dart engages the sleeve.

5. The method of claim 4 , wherein the wellbore dart includes:

a plurality of collet fingers defined on the outer surface, wherein the collet fingers interact with the inner profile of the sleeve so as to lock the wellbore dart from moving upward in the sleeve and tubing; and

one or more polymeric sealing sections defined on the outer surface, wherein the sealing sections provide a fluid-tight seal with the inner surface of the sleeve.

6. The method of claim 5 , wherein the sleeve further has an upper end having a shoulder and wherein the shoulder interacts with the outer surface of the wellbore dart so as to prevent downward movement of the wellbore dart past the sleeve.

7. The method of claim 1 , wherein the rupture disc is made of a degradable material such that, after the introduction of the artificial lift assembly into the wellbore, the rupture disc degrades so as to allow fluid flow through the electrical submersible pumping system.

8. The method of claim 7 , further comprising:

introducing the wellbore dart into the wellbore such that the wellbore dart engages the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by fluid flow, wherein the wellbore dart has an outer profile defined on an outer surface of the wellbore dart, the outer profile configured to mate with the sleeve such that the wellbore dart is held in place within the sleeve and prevents the fluid flow through the electrical submersible pumping system.

9. The method of claim 8 , further comprising:

removing the artificial lift assembly from the wellbore after the wellbore dart engages the sleeve.

10. The method of claim 9 , wherein the wellbore dart includes:

a plurality of collet fingers defined on the outer surface, wherein the collet fingers interact with the inner profile of the sleeve so as to lock the wellbore dart from moving upward in the sleeve and tubing; and

one or more polymeric sealing sections defined on the outer surface, wherein the sealing sections provide a fluid-tight seal with the inner surface of the sleeve.

11. The method of claim 10 , wherein the rupture disk is located in the tubing string above the electrical submersible pump, and the sleeve further has an upper end having a shoulder and wherein the shoulder interacts with the outer surface of the wellbore dart so as to prevent downward movement of the wellbore dart past the sleeve.

12. An artificial lift assembly deployed on a tubing string for use in a wellbore, the artificial lift assembly comprising:

an electrical submersible pumping system having a permanent magnet motor;

a rupture disc located in the tubing string, wherein the rupture disc prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by the fluid flow; and

a sleeve located in the tubing string above the electrical submersible pump having an inner profile defined on an inner surface of the sleeve, wherein the inner profile is configured to mate with and lock in place a wellbore dart such that, when the wellbore dart is introduced into the sleeve, the wellbore dart is held in place within the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by the fluid flow.

13. The artificial lift assembly of claim 12 , wherein the rupture disc is made of steel or polymer and is configured to have a predetermined rupture pressure such that, when fluid pressure uphole of the rupture disc exceeds the predetermined rupture pressure, the rupture disc ruptures so that fluid flow through the electrical submersible pumping system is allowed.

14. The artificial lift assembly of claim 13 , further comprising:

the wellbore dart having an outer profile defined on an outer surface of the wellbore dart, the outer profile configured to mate with the sleeve such that, when the wellbore dart is introduced into the sleeve, the wellbore dart is held in place within the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by the fluid flow.

15. The artificial lift assembly of claim 14 , wherein the wellbore dart includes:

a plurality of collet fingers defined on the outer surface, wherein the collet fingers interact with the inner profile of the sleeve so as to lock the wellbore dart from moving upward in the sleeve and tubing; and

one or more polymeric sealing sections defined on the outer surface, wherein the sealing sections provide a fluid-tight seal with the inner surface of the sleeve.

16. The artificial lift assembly of claim 15 , wherein the sleeve further has an upper end having a shoulder and wherein the shoulder interacts with the outer surface of the wellbore dart so as to prevent downward movement of the wellbore dart past the sleeve.

17. The artificial lift assembly of claim 12 , wherein the rupture disc is made of a degradable material such that, after the introduction of the artificial lift assembly into the wellbore, the rupture disc degrades so as to allow fluid flow through the electrical submersible pumping system.

18. The artificial lift assembly of claim 17 , further comprising:

the wellbore dart having an outer profile defined on an outer surface of the wellbore dart, the outer profile configured to mate with the sleeve such that, when the wellbore dart is introduced into the sleeve, the wellbore dart is held in place within the sleeve and prevents fluid flow through the electrical submersible pumping system to thus prevent rotation of the permanent magnet motor by the fluid flow.

19. The artificial lift assembly of claim 18 , wherein the wellbore dart includes:

a plurality of collet fingers defined on the outer surface, wherein the collet fingers interact with the inner profile of the sleeve so as to lock the wellbore dart from moving upward in the sleeve and tubing; and

one or more polymeric sealing sections defined on the outer surface, wherein the sealing sections provide a fluid-tight seal with the inner surface of the sleeve.

20. The artificial lift assembly of claim 19 , wherein the rupture disk is located in the tubing string above the electrical submersible pump, and the sleeve further has an upper end having a shoulder and wherein the shoulder interacts with the outer surface of the wellbore dart so as to prevent downward movement of the wellbore dart past the sleeve.