Patent Grant
12320210
This disclosure relates to electric submersible pumps.
Electric submersible pumps are used in oil and gas production to lift hydrocarbons from a downhole location of a wellbore to the terranean surface of the wellbore. Electric submersible pumps have motors and other components that vibrate or move during production, which can lead to operational issues and reduce the life of the electric submersible pump. Methods and equipment to improve electric submersible pumps are sought.
Implementations of the present disclosure include an electric submersible pump assembly that has a motor, a pump, and a slip assembly. The motor is coupled to a wellbore string disposed within a wellbore. The pump is coupled to the wellbore string and resides between the motor and the wellbore string. The pump is driven by the motor to receive a production fluid from an intake of the electric submersible pump assembly and flow the production fluid up the wellbore through the wellbore string. The slip assembly is attached to the electric submersible pump assembly and resides downhole of the motor. The slip assembly has a first slip and a second slip. The first slip is coupled to the electric submersible pump assembly at or downhole of the motor. The first slip is flexible and engages, with the second slip set, the wall of the wellbore to dampen a vibration of the motor. The second slip is coupled to the electric submersible pump assembly at or downhole of the motor, and is set on a wall of the wellbore, securing the electric submersible pump assembly to the wall of the wellbore.
In some implementations, the electric submersible pump assembly further includes a third slip. The first slip, second slip, and third slip are substantially equidistant from each other. The third slip is coupled to the electric submersible pump assembly at or downhole of the motor. The third slip is rigid and sets on a wall of the wellbore, further securing the electric submersible pump assembly to the wall of the wellbore. In some implementations, the second slip and third slip prevent the motor from substantially moving axially, and the first slip reduces a radial and axial vibration of the motor. In some implementations, the first slip includes a damper including at least one of a rubber element or a spring configured to bear against the wall of the casing. The damper absorbs the kinetic energy released by the motor while vibrating.
In some implementations, the second slip includes a rigid slip has teeth that bite into the wall of the casing to fix the electric submersible pump assembly to the wall of the casing.
In some implementations, the second slip is set mechanically, hydraulically, or electrically.
In some implementations, the first slip and second slip reside at a common elevation along the electric submersible pump assembly. In some implementations, the slip assembly includes a tube coupled to a downhole end of the motor, and the first slip and second slip are attached to the tube.
Implementations of the present disclosure include an assembly that includes a wellbore tool disposed within a wellbore and a slip assembly attached to the wellbore tool. The slip assembly includes a first slip and a second slip. The first slip is coupled to wellbore tool and has a damper that resides between the first slip and a wall of the wellbore to absorb energy produced by vibration of the wellbore tool. The second slip is set on a wall of the wellbore, securing the wellbore tool to the wall of the wellbore.
In some implementations, the slip assembly further includes a third slip with the first slip, second slip, and third slip substantially equidistant from each other and residing along a common elevation with respect to the wellbore tool, the third slip being rigid and configured be set on a wall of the wellbore, further securing the electric submersible pump assembly to the wall of the wellbore. In some implementations, the second slip and third slip prevent the motor from substantially moving axially, and the first slip reduces or controls a radial and axial vibration of the motor.
In some implementations, the damper includes at least one of a rubber element or a spring configured to bear against the wall of the casing, the damper configured to absorb the kinetic energy released by the motor while vibrating.
In some implementations, the second slip includes a rigid slip including teeth configured to bite into the wall of the casing to fix the electric submersible pump assembly to the wall of the casing.
In some implementations, the wellbore tool includes a submersible pump, and the slip assembly is coupled to a downhole end of a motor of the submersible pump.
Implementations of the present disclosure include a method that includes obtaining a wellbore tool. The wellbore tool has a slip assembly including a first slip and a second slip. The first slip has a damper and the second slip can be set on a wall of the wellbore, securing the wellbore tool to the wall of the wellbore. The method also includes disposing the wellbore tool within a wellbore. The method also includes activating the second slip to engage a wall of the wellbore and secure the wellbore tool to a wall of the wellbore. The first slip bears, with the second slip set, against the wall of the wellbore and against the wellbore tool to dampen a vibration of the wellbore tool.
The present disclosure describes an electric submersible pump assembly that reduces or eliminates the vibration of the motor of the electric submersible pump. The electric submersible pump assembly has a damper with slips that dissipates the energy of oscillations at and below the motor to an acceptable level. Vibration can be an indirect measurement of the performance of electric submersible pumps. For example, like vibration can be cause by or include mechanical (e.g. sand, wear), electrical (e.g. frequency) and hydraulic (e.g. gas, viscosity) components. This makes it difficult to interpret an exact, absolute value of vibration of the motor. However, the trend of vibration of the motor can indicate a range of problem conditions or change in normal operating conditions. The electric submersible pump assembly of the present disclosure can reduce vibration of the motor and other components to reduce problems and maintain normal operating conditions.
Particular implementations of the subject matter described in this specification can be implemented so as to realize one or more of the following advantages. For example, the electric submersible pump assembly of the present disclosure can reduce operational issues related to vibration and extend the run life of the electric submersible pump assembly.
The pump 108 is coupled to the wellbore string 104. The pump 108 is driven by the motor 106 to receive a production fluid “F” from the intake 112 and flow the production fluid “F” up the wellbore 110 through the wellbore string 104. The production fluid “F” flows from a formation “M” and can include water, hydrocarbons, and other formation fluids.
The motor 106 is an electric ESP motor such as an induction AC motor or a permanent magnet motor. The motor 106 can be powered by a power source electrically connected to the motor 106 through one or more cables 120 (e.g., a power cable). Additionally, the one or more cables 120 can be used to transmit information or instructions to other parts of the ESP 102, such as the vibration suppressor 118 to activate the slips 103 of the vibration suppressor 118.
The vibration suppressor 118 is attached to a downhole end of the motor 106 or the sensor 116. In some implementations, the vibration suppressor 118 can be attached above the motor 106, at the motor, or in a different location along the ESP 102.
The vibration suppressor 118 has a tube 105 or housing and multiple slips 103 that extend from the housing 105. A horizontal slip 103 can be or include a damper to reduce noise and vibration. The tube 105 can be threadedly attached or otherwise coupled to the downhole end of the ESP 102, near the motor 106.
Referring also to
The second slip 103b and third slip 103c are rigid and extend to engage the wall 111 of the wellbore similar to traditional slips (e.g., packer slips). The second slip 103b and third slip 103c have teeth 109 that bite into the casing of the wellbore 110 to secure or fix the ESP 102 (and by extension the motor 106) to the wall 111 of the wellbore 110.
In some implementations, the three slips 103a, 103b, 103c are substantially equidistant from each other. The slips define a gap “G” between each other at the annulus between the tube 105 and the wellbore 110 to let fluid “F” flow substantially uninterrupted up to the intake of the ESP 102. The two rigid slips 103b, 103c together secure the ESP 102 to the wellbore 110, preventing the motor 106 from substantially moving axially. For example, referring back to
The slips 103a, 103b, 103c are set hydraulically, mechanically, or electrically. In some implementations, only the rigid slips 103b, 103c are set or extended while the floating slip 103b remains in one position. The tube 105 can be fluidly coupled to the wellbore string 104, and fluid from the wellbore string 104 can be flown at a sufficient pressure to expand the slips 103b, 103c. In some embodiments, the slips 103b, 103c can be set mechanically by pulling the ESP 102 uphole from the surface.
Although the following detailed description contains many specific details for purposes of illustration, it is understood that one of ordinary skill in the art will appreciate that many examples, variations and alterations to the following details are within the scope and spirit of the disclosure. Accordingly, the exemplary implementations described in the present disclosure and provided in the appended figures are set forth without any loss of generality, and without imposing limitations on the claimed implementations. For example, the implementations are described with reference to an electric submersible pump (ESP). However, the disclosure can be implemented with any wellbore equipment that is susceptible to vibration, such as production tubing, valves, or packers.
Although the present implementations have been described in detail, it should be understood that various changes, substitutions, and alterations can be made hereupon without departing from the principle and scope of the disclosure. Accordingly, the scope of the present disclosure should be determined by the following claims and their appropriate legal equivalents.
The singular forms “a”, “an” and “the” include plural referents, unless the context clearly dictates otherwise.
As used in the present disclosure and in the appended claims, the words “comprise,” “has,” and “include” and all grammatical variations thereof are each intended to have an open, non-limiting meaning that does not exclude additional elements or steps.
As used in the present disclosure, terms such as “first” and “second” are arbitrarily assigned and are merely intended to differentiate between two or more components of an apparatus. It is to be understood that the words “first” and “second” serve no other purpose and are not part of the name or description of the component, nor do they necessarily define a relative location or position of the component. Furthermore, it is to be understood that the mere use of the term “first” and “second” does not require that there be any “third” component, although that possibility is contemplated under the scope of the present disclosure.
| Number | Name | Date | Kind |
|---|---|---|---|
| 20160040517 | Lee | Feb 2016 | A1 |
| 20160061010 | Sears | Mar 2016 | A1 |
| Number | Date | Country | |
|---|---|---|---|
| 20240344408 A1 | Oct 2024 | US |
