Completing a wellbore with multiple electrical submersible pump docking stations

1 . A wellbore completion assembly configured to support a first electrical submersible pump assembly and a second electrical submersible pump assembly, the wellbore completion assembly comprising:

a production tubing;

a first nipple positioned at a first location in the production tubing, the first nipple defining a first nipple profile, the first nipple configured to selectively receive a first nipple lock configured to support the first electrical submersible pump assembly at the first location within the wellbore completion assembly;

a first electrical connection at the first location, the first electrical connection configured to electrically couple to the first electrical submersible pump assembly;

a second nipple positioned at a second location in the production tubing, the second location different than the first location, the second nipple defining a second nipple profile different than the first nipple profile, the second nipple configured to selectively receive a second nipple lock configured to support the second electrical submersible pump assembly at the second location within the wellbore completion assembly; and

a second electrical connection at the second location, the second electrical connection configured to electrically couple to the second electrical submersible pump assembly.

2 . The wellbore completion assembly of claim 1 , further comprising the first nipple lock, the first nipple lock configured to be run into the wellbore completion assembly separately from the first electrical submersible pump assembly, the first nipple lock comprising:

a first outer surface; and

a first outer nipple profile defined in the first outer surface, the first outer nipple profile corresponding to the first nipple profile and configured to selectively engage the first nipple profile of the first nipple.

3 . The wellbore completion assembly of claim 2 , further comprising the second nipple lock, the second nipple lock configured to be run into the wellbore completion assembly separately from the second electrical submersible pump assembly, the second nipple lock comprising:

a second outer surface; and

a second outer nipple profile defined in the second outer surface, the second outer nipple profile different than the first outer nipple profile, the second outer nipple profile corresponding to the second nipple profile, the second outer nipple profile configured to selectively engage the second nipple profile of the second nipple.

4 . The wellbore completion assembly of claim 3 , wherein the second nipple lock further comprises a second landing profile configured to receive and support the second electrical submersible pump assembly within the wellbore completion assembly, and the second nipple lock comprises a threaded outer surface configured to threadedly coupled to the production tubing.

5 . The wellbore completion assembly of claim 3 , wherein the second nipple lock comprises a plurality of annular flow ports configured to pass a wellbore fluid through the second nipple lock from a first surface within the second nipple lock to an outer surface of the second nipple lock.

6 . The wellbore completion assembly of claim 3 , wherein the second nipple comprises a no-go diameter.

7 . The wellbore completion assembly of claim 3 , wherein the second nipple lock is configured to engage the second electrical submersible pump assembly to the second electrical connection when the second electrical submersible pump assembly is seated on the second nipple lock.

8 . The wellbore completion assembly of claim 2 , further comprising a sleeve configured to couple to the first nipple lock, the sleeve configured to seal the first electrical connection from a fluid within the production tubing.

9 . The wellbore completion assembly of claim 8 , wherein the sleeve comprises a polished outer bore, the polished outer bore configured to seal the first electrical connection from an inner void of the production tubing.

10 . The wellbore completion assembly of claim 8 , wherein the sleeve further comprises a corrosion protector.

11 . The wellbore completion assembly of claim 8 , wherein the sleeve further comprises a thermal compensation device configured to compensate for temperature expansion and contraction of a trapped volume between the sleeve and the first electrical connection.

12 . The wellbore completion assembly of claim 7 , further comprising:

a third nipple positioned at a third location in the production tubing, the third nipple defining a third nipple profile, the third location proximal the first electrical connection; and

a third nipple lock comprising:

a third outer surface; and

a third outer nipple profile defined in the first outer surface, the third outer nipple profile corresponding to the third nipple profile and configured to selectively engage the third nipple profile.

13 . A method of completing a wellbore, the method comprising:

disposing a completion assembly in the wellbore extending from a surface of the Earth to a subterranean hydrocarbon reservoir, the completion assembly comprising:

a first production tubing section;

a first nipple defining a first nipple profile, the first nipple coupled to the first production tubing section, the first nipple configured to receive a first nipple lock defining a first outer nipple profile;

a first electrical submersible pump shuttle docking station coupled to the first nipple, the first electrical submersible pump shuttle docking station configured to receive a first electrical submersible pump assembly;

a first power cable coupled to the first electrical submersible pump shuttle docking station, the first power cable extending from the first electrical submersible pump shuttle docking station to the surface;

a second nipple coupled to the first electrical submersible pump shuttle docking station, the second nipple defining a second nipple profile different that the first nipple profile, the second nipple configured to receive a second nipple lock defining a second outer nipple profile;

a second production tubing section coupled to the second nipple;

a third nipple coupled to the second production tubing section, the third nipple defining a third nipple profile different than the first nipple profile and the second nipple profile, the third nipple spaced apart from the second nipple by the second production tubing section, the third nipple configured to receive a third nipple lock defining a third outer nipple profile;

a second electrical submersible pump shuttle docking station coupled to the third nipple, the second electrical submersible pump shuttle docking station configured to receive a second electrical submersible pump assembly;

a second power cable coupled to the second electrical submersible pump shuttle docking station, the second power cable extending from the second electrical submersible pump shuttle docking station to the surface;

a fourth nipple coupled to the second electrical submersible pump shuttle docking station, the fourth nipple defining a fourth nipple profile, the fourth nipple configured to receive a fourth nipple lock defining a fourth outer nipple profile; and

a packer positioned at a downhole end of the completion assembly;

engaging the packer to an inner surface of the wellbore;

disposing the second nipple lock in the completion assembly, the second nipple lock defining the second outer nipple profile corresponding to the second nipple profile, the second outer nipple profile configured to selectively engage the second nipple profile;

engaging the second outer nipple profile to the second nipple profile;

disposing the second electrical submersible pump assembly within the completion assembly;

coupling the second electrical submersible pump assembly to the fourth nipple lock;

engaging the second electrical submersible pump assembly to the second electrical submersible pump shuttle docking station; and

producing, by the second electrical submersible pump assembly, a hydrocarbon fluid from the wellbore to the surface.

14 . The method of claim 13 , further comprising sealing, by a sleeve, the first electrical submersible pump shuttle docking station from an inner volume of the completion assembly.

15 . The method of claim 14 , further comprising:

reducing a corrosion rate within a volume defined by the sleeve and the first electrical submersible pump shuttle docking station; and

responsive to a change in temperature of the sleeve, adjusting the sleeve.

16 . The method of claim 14 , further comprising:

disposing an electrical test tool in the wellbore by a downhole conveyance coupled to a running tool connector of the electrical test tool, the electrical test tool comprising a common jumper lead coupled to the running tool connector, the common jumper lead comprising pins configured to engage the first electrical submersible pump shuttle docking station;

coupling the electrical test tool to the first electrical submersible pump shuttle docking station;

determining, based on a condition of the common jumper lead, a condition of first electrical submersible pump shuttle docking station indicating a failure of first electrical submersible pump shuttle docking station;

based on determining the condition of first electrical submersible pump shuttle docking station indicating the failure of first electrical submersible pump shuttle docking station, removing the first electrical submersible pump assembly from the completion assembly;

disposing a third nipple lock in the completion assembly at the third nipple, the third nipple lock defining a third landing profile corresponding to the third nipple profile, the third landing profile configured to selectively engage the third nipple profile;

engaging the third landing profile to the third nipple profile;

disposing a second electrical submersible pump assembly within the completion assembly;

coupling the second electrical submersible pump assembly to the third nipple lock;

engaging the second electrical submersible pump assembly to the second electrical submersible pump shuttle docking station; and

producing, by the second electrical submersible pump assembly, a hydrocarbon fluid from the wellbore to the surface.

17 . The wellbore completion assembly of claim 3 , wherein the first nipple profile is defined on an inner surface of the first nipple oriented toward a center axis of the first nipple, and wherein the second nipple profile is defined on an inner surface of the second nipple oriented toward a center axis of the second nipple.

18 . A side pocket mandrel electrical test tool comprising:

a running tool connector;

a common jumper lead coupled to the running tool connector, the common jumper lead comprising pins configured to engage an electrical connection of a side pocket mandrel for an electrical submersible pump assembly; and

a controller electrically coupled to the common jumper lead, the controller configured to perform operations comprising based on a condition of the common jumper lead, determining a condition of the electrical connection, wherein determining the condition of the electrical connection comprises:

determining a first condition of the common jumper lead when the common jumper lead is not in contact with the electrical connection;

determining a second condition of the common jumper lead when the common jumper lead is in contact with the electrical connection;

comparing the first condition to the second condition; and

based on a result of the comparison, determining the condition of the electrical connection.

19 . The side pocket mandrel electrical test tool of claim 18 , wherein determining the condition of the electrical connection comprises determining a location and a type of fault of the electrical connection.

20 . The side pocket mandrel electrical test tool of claim 18 , wherein the condition of the electrical connection comprises one or more of a condition of an insulation of an electrical submersible pump power cable, a resistance of the electrical connection, or a time domain reflectometry condition of the electrical connection.