CA2965130C

CA2965130C - Submersible pump stabilization

Info

Publication number: CA2965130C
Application number: CA2965130A
Authority: CA
Inventors: Alan Watt
Original assignee: Suncor Energy Inc
Current assignee: Suncor Energy Inc
Priority date: 2013-04-23
Filing date: 2014-04-23
Publication date: 2018-05-29
Anticipated expiration: 2034-04-23
Also published as: CA2998022C; CA2965130A1; CA2998022A1; CA2849685A1; CA2849685C

Abstract

Various techniques are described for reducing induced bending in submersible pump equipment employed for in situ recovery operations along a wellbore. A stabilization assembly that is mountable on the submersible pump is positioned, shaped and sized to provide support between the submersible pump and a segment of the wellbore and to alleviate bending of the submersible pump along the segment. The stabilization assembly can include a mounting component that can be attached to the submersible pump, as well as protruding components extending outwardly from the mounting component. Providing customized structural support between the submersible pump and the wellbore, based on any of several different deflection causes, thus helps reduce deflections during deployment and operation of the pump and reduce damages due to bending.

Description

SUBMERSIBLE PUMP STABILIZATION
TECHNICAL FIELD
[0001] The technical field generally relates to techniques for submersible pump stabilization, as well as submersible pump installation and operation for in situ hydrocarbon recovery.
BACKGROUND

[0002] There are a number of in situ techniques for recovering hydrocarbons, such as heavy oil and bitumen, from subsurface reservoirs. Thermal in situ recovery techniques often involve the injection of a heating fluid, such as steam, in order to heat and thereby reduce the viscosity of the hydrocarbons to facilitate recovery.

[0003] One technique, called Steam-Assisted Gravity Drainage (SAGD), has become a widespread process for recovering heavy oil and/or bitumen particularly in the oil sands of northern Alberta. The SAGD process involves well pairs, each pair having two horizontal wells drilled in the reservoir and aligned in spaced relation one on top of the other. The upper horizontal well is an injection well and the lower underlying horizontal well is a production well.

[0004] A SAGD operation typically begins in a startup mode, in order to establish fluid communication between the injection well and the production well. After this startup mode, which can typically take about three months for a SAGD production well, the production well can be recompleted for mechanical lift. Mechanical lift involves the installation of a pump, such as an electric submersible pump (ESP), to provide the hydraulic force for lifting production fluid to the surface.

[0005] The use of electric submersible pumps, such as ESPs, involves a number of challenges. In certain scenarios, a dogleg severity of a well can be between 6 and '14 degrees per 30 m (100 feet) which is higher than established ESP recommended limits.
Because of the nature of these SAGD wells, the ESPs are also landed in a nearly horizontal position. A number of premature failures in ESP operated wells have been related to equipment bending. Inspection of the units showed evidence of shaft breakage 2 =
caused by bending fatigue. Indeed, induced bending on components of the ESP
results in a shortened run life of ESP equipment.
SUMMARY

[0006] In some implementations, there is provided a stabilization assembly for use with a submersible pump employed for in situ recovery operations along a wellbore, the stabilization assembly comprising:
at least one mounting component mountable about an outer component of the submersible pump; and at least one protruding component protruding outwardly from the at least one mounting component, and being positioned, shaped and sized for providing support between the submersible pump and a segment of the wellbore and to alleviate bending of the submersible pump along the segment.

[0007] In some implementations, the at least one protruding component comprises at least one radially-extending component.

[0008] In some implementations, the at least one protruding component has a trapezoidal form.

[0009] In some implementations, the at least one protruding component is provided with at least one outer skidding component for skidding against walls of the wellbore.

[00010] In some implementations, the at least one outer skidding component is a sub-component of the at least one protruding component.

[00011] In some implementations, the at least one outer skidding component comprises at least one flange spanning across a corresponding radially-extending component.

[00012] In some implementations, the at least one outer skidding component and the corresponding radially-extending component form one integral piece made of a common material.

[00013] In some implementations, the at least one outer skidding component comprises a straight portion between two slanted portions.

[00014] In some implementations, the at least one outer skidding component comprises proximate and distal slanted portions.

[00015] In some implementations, the at least one protruding component is disposed circumferentially about the at least one mounting component.

[00016] In some implementations, the at least one protruding component comprises at least one bottom notch being positioned, shaped and sized for resting against the at least one mounting component.

[00017] In some implementations, the at least one bottom notch is substantially L-shaped.

[00018] In some implementations, the at least one mounting component comprises at least proximate and distal mounting components being longitudinally spaced apart from one another.

[00019] In some implementations, the at least one protruding component extends between the proximate and distal mounting components.

[00020] In some implementations, each mounting component comprises first and second sub-components being connectable to one another, about a corresponding peripheral outer section of the submersible pump, by means of at least one connecting component.

[00021] In some implementations, the at least one connecting component comprises a pair of connecting components, each connecting component interconnecting portions of the first and second sub-components of a given mounting component.

[00022] In some implementations, the at least one mounting component comprises an anti-rotation component for preventing rotational displacement of the stabilization assembly with respect to the submersible pump.

[00023] In some implementations, the anti-rotation component comprises an anti-rotation male component insertable into a corresponding anti-rotation female component provided about the submersible pump.

[00024] In some implementations, the anti-rotation component comprises an anti-rotation female component for receiving a corresponding anti-rotation male component provided about the submersible pump.

[00025] In some implementations, the anti-rotation component comprises an anti-rotation joining component weldable onto a corresponding outer component provided about the submersible pump.

[00026] In some implementations, the at least one mounting component comprises a blocking component for blocking axial displacement of the stabilization assembly with respect to the submersible pump.

[00027] In some implementations, the blocking component comprises a blocking male component insertable into a corresponding blocking female component provided about the submersible pump.

[00028] In some implementations, the blocking component comprises a blocking female component for receiving a corresponding blocking male component provided about the submersible pump.

[00029] In some implementations, the blocking component comprises a blocking joining component weldable onto a corresponding outer component provided about the submersible pump.

[00030] In some implementations, the anti-rotation component and the blocking component are the same component.

[00031] In some implementations, the protruding components of the stabilization assembly are positioned, shaped and sized for providing support between the submersible pump and the wellbore, to alleviate bending of the submersible pump when placed along a deviated segment of the wellbore.

[00032] In some implementations, the protruding components of the stabilization assembly are positioned, shaped and sized for providing support between the submersible pump and the wellbore, in order to adjust a centerline of the submersible pump when placed along a deviated segment of the wellbore.

[00033] In some implementations, the at least one protruding component comprises a plurality of protruding components.

[00034] In some implementations, the protruding components are spaced from one another about a given mounting component.

[00035] In some implementations, the protruding components define a passage for at least one of cabling and instrumentation extending along a length of the submersible pump.

[00036] In some implementations, the at least one mounting component is configured to be mountable about a distal component of the submersible pump.

[00037] In some implementations, the at least one mounting component is configured to be mountable about a peripheral outer component of the submersible pump.

[00038] In some implementations, the at least one mounting component is configured to be mountable about a motor component of the submersible pump.

[00039] In some implementations, the at least one mounting component is configured to be mountable about a seal component of the submersible pump.

[00040] In some implementations, the at least one mounting component is configured to be mountable about an intake component of the submersible pump.

[00041] In some implementations, the at least one mounting component is configured to be mountable about a pump component of the submersible pump.

[00042] In some implementations, the submersible pump is an electric submersible pump.

[00043] In some implementations there is provided a kit with components for assembling a stabilization assembly as described above.

[00044] In some implementations, given components of the kit are provided with corresponding assembly interfaces for facilitating assembly of the given components with other components of the kit.

[00045] In some implementations, there is provided a method of stabilizing a submersible pump employed for in situ recovery operations along a segment of a wellbore, the method comprising:
mounting at least one stabilization assembly as defined above onto at least one corresponding outer component of the submersible pump for providing support between the submersible pump and the segment of the wellbore and to alleviate bending of the submersible pump along the segment; and deploying the submersible pump and the at least one stabilization assembly down the wellbore.

[00046] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about a distal component of the submersible pump.

[00047] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about a peripheral outer component of the submersible pump.

[00048] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about a motor component of the submersible pump.

[00049] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about a seal component of the submersible pump.

[00050] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about an intake component of the submersible pump.

[00051] In some implementations, the mounting step comprises mounting at least one of the at least one stabilization assembly about a pump component of the submersible pump.

[00052] In some implementations, the mounting step comprises:
mounting a plurality of stabilization assemblies; and providing a separation distance of about 10 feet to about 14 feet between each stabilization assembly.

[00053] In some implementations, the mounting step comprises securing each stabilization assembly about the submersible pump so as prevent rotation of the stabilization assembly with respect to the submersible pump.

[00054] In some implementations, the mounting step comprises securing each stabilization assembly about the submersible pump so as prevent axial displacement of the stabilization assembly with respect to the submersible pump.

[00055] In some implementations, the mounting step comprises mounting a plurality of stabilization assemblies, each stabilization assembly defining a passage for at least one of cabling and instrumentation extending along a length of the submersible pump, and further comprising the step of aligning the stabilization assemblies to align the cabling and instrumentation passages.

[00056] In some implementations, the method further comprises, prior to mounting:
collecting configuration data indicative of a configuration of the segment of the wellbore and a configuration of the submersible pump; and determining the size, shape and position of the at least one stabilization assembly based on the configuration data.

[00057] In some implementations, there is provided a method for stabilizing a submersible pump within a wellbore, comprising:
providing at least one stabilization assembly as described above, wherein the at least one stabilization assembly is attached to the submersible pump; and placing the submersible pump within a segment of the wellbore having a first dogleg severity;
wherein the at least one stabilization assembly is configured to reduce a deflection of the submersible pump, thus effectively subjecting the submersible pump to a second dogleg severity within the segment, the second dogleg severity being less than the first dogleg severity such that bending stress induced in the submersible pump is reduced.

[00058] In some implementations, the first and second dogleg severities comprise an =
inclination value.

[00059] In some implementations, the first and second dogleg severities comprise an azimuth value.

[00060] In some implementations, there is provided a method for reducing bending stress on a tool string positioned within a wellbore, comprising:
collecting configuration data indicative of a configuration of a segment of the wellbore having a first dogleg severity and of a configuration of the tool string;
providing at least one stabilization assembly as described above, with a size, shape and position of the at least one stabilization assembly being based on the configuration data;
attaching the at least one stabilization assembly to the tool string; and placing the tool string within the segment of the wellbore;
wherein the at least one stabilization assembly is configured to reduce bending of the tool string, thus effectively subjecting the tool string to a second dogleg severity within the segment, the second dogleg severity being less than the first dogleg severity such that bending stress induced in the tool string is reduced.

[00061] In some implementations, there is provided a method for stabilizing a submersible pump within a segment of a wellbore, the method comprising:
providing support between the submersible pump and walls of the segment of the wellbore to alleviate bending stress along the submersible pump within the segment.

[00062] In some implementations, the method further includes, prior to the providing support step:
collecting configuration data indicative of a configuration of the segment of the wellbore and a configuration of the submersible pump; and wherein support is provided based on the configuration data.
=

[00063] In some implementations:
the configuration data comprises data indicative of a dogleg severity at a location in the wellbore; and providing support based on the configuration data comprises providing support to reduce an impact of the dogleg severity on the submersible pump such that the bending stress the submersible pump is subjected to at the location in the wellbore of the dogleg severity is reduced.

[00064] In some implementations, the segment of the wellbore comprises a step change in inner diameter.

[00065] In some implementations, the segment of the wellbore is a deviated segment.

[00066] In some implementations, the segment of the wellbore has a configuration causing a cantilevered portion of the submersible pump; and the support is provided at the cantilevered portion to alleviate bending stress.

[00067] In some implementations, the method further includes:
deploying the submersible pump down a curved heel of the wellbore and providing support between the submersible pump and walls of the curved heel of the wellbore to alleviate bending stress along the submersible pump within the curved heel during the deployingstep.

[00068] In some implementations, the method further includes:
placing the submersible pump in a horizontal section of the wellbore, wherein the horizontal section positions the submersible pump in a deflected configuration in the absence of the providing support step.

[00069] In some implementations, the method further includes:
placing the submersible pump in a deviated section of the wellbore, wherein the deviated section positions the submersible pump in a deflected configuration in the absence of the providing support step.

[00070] In some implementations, the method further includes:
skidding the submersible pump along walls of the wellbore during deployment.

[00071] In some implementations, the method further includes:
skidding the submersible pump across obstacles along the wellbore during deployment.

[00072] In some implementations, the method further includes:
removing the submersible pump from the wellbore; and skidding the submersible pump across obstacles along the wellbore encountered during the removing step.

[00073] In some implementations, the method further includes:
positioning the submersible pump such that the seal component and the intake component of the submersible pump are subjected to a lowest dogleg severity within the wellbore.
BRIEF DESCRIPTION OF THE DRAWINGS

[00074] Fig. 1 is a side cross-sectional view schematic of a production well including a submersible pump.

[00075] Fig. 2 is a schematic representation of a submersible pump provided with stabilization assemblies.

[00076] Fig. 3 is a schematic representation of Dogleg Severity (DLS).

[00077] Figs. 4a to 4d are perspective views of four stabilization assemblies.

[00078] Fig. 5 is a schematic representation of a stabilization assembly in a wellbore, proximate a liner.

[00079] Fig. 6 is an exploded view of components of a stabilization assembly.

[00080] Fig. 7 is a front schematic view of a stabilization assembly.

[00081] Fig. 8 is a cross-sectional view of a mounting component.

[00082] Fig. 9 is a side view of a possible mechanism to prevent axial and/or rotational displacement of the stabilization assembly with respect to a submersible pump.

[00083] Fig. 10 is a side view of another possible mechanism to prevent axial and/or rotational displacement of the stabilization assembly with respect to a submersible pump.

[00084] Fig. 11 is a schematic representation of a submersible pump with stabilization assemblies.

[00085] Fig. 12 is a process flow diagram.
DETAILED DESCRIPTION

[00086] Various techniques are described for reducing induced bending in submersible pump equipment employed for in situ recovery operations along a wellbore. A
stabilization assembly that is mountable on the submersible pump is positioned, shaped and sized to provide support between the submersible pump and a segment of the wellbore and to alleviate bending of the submersible pump along the segment. The stabilization assembly can include a mounting component that can be removably attached to the submersible pump, as well as one or several protruding components extending outwardly from the mounting component.

[00087] Deflection of the submersible pump with respect to its nominal straight configuration results in undesirable bending. Such deflections can result from several causes. Irregularities, cured segments, or dogleg severities within the wellbore can result in a deflection of the submersible pump. Moreover, positioning the submersible pump in a cantilevered configuration in a substantially straight segment of a wellbore can also result in deflections of the pump due to the weight of the unsupported free end.
Deflections created by positioning the submersible pump across a change in wellbore internal diameter can be alleviated by the use of stabilizers with varying outside diameters.
Asymmetric or varying positioning of equipment on the outside of a submersible pump can also result in irregular loading and deflections of the pump. Providing customized structural support between the submersible pump and the wellbore, based on any of the above-mentioned deflection causes, thus helps reduce such deflections during deployment and operation of the pump and reduce damages due to bending.

[00088] Such stabilization assemblies can also be used to reduce deflections in various other tool strings used in a wellbore by reducing the wear or fatigue caused by bending.
The reduction in bending thus results in an increased operational life of such equipment.
More regarding the various structural and operational features of the stabilization assemblies will be described in greater detail below.
Stabilization assembly implementations

[00089] Various stabilization assemblies can be used with various types of submersible pumps in various types o'f production wells. Fig. 1 shows the positioning of a submersible pump 10 within a SAGD production wellbore 12. For example, the pump 10 can be positioned within a substantially horizontal segment 14 of the wellbore 12 as shown in Fig.
1. However, the pump can also be positioned in an irregular or curved section of the wellbore 12. Moreover, the pump can also be positioned in any deviated section of the wellbore at any inclination.

[00090] Referring to Fig. 2, a step 16 in the wellbore 12 can present an irregular profile to the pump 10. A plurality of stabilization assemblies 20, 20' provide support between the pump 10 and the irregular segment 22 of the wellbore. Each stabilization assembly 20, 20' includes removable mounting components 24, 24' mountable about an outer component of the submersible pump 10. Each stabilization assembly 20, 20' also includes protruding components 26, 26' protruding outwardly from the mounting components 24. The support provided by the stabilization assemblies 20, 20' reduces deflections that can otherwise occur (as shown for example in dotted lines 30) with respect to a central axis 32 of the pump 10, in the absence of the stabilization assemblies. This reduction in deflections alleviates bending within components of the pump.

[00091] The present stabilization assembly 20 is different from "centralizers", in that a "centralizer" is a component which is used merely to centralize a tool within a wellbore. By contrast, the stabilization assembly 20 is not meant to try to centralize the submersible pump within the wellbore, which could defeat the purpose for which the present stabilization assembly 20 is intended. Indeed, if one simply centralizes the submersible pump within a section of the wellbore, the submersible pump would remain subjected to the same irregularity, curved portion or dogleg severity of that section of the wellbore.
Therefore, the stabilization assembly 20 reduces the deflection of the structure of the pump 10 when subjected to a non-linearity in the profile of the wellbore segment, including a high radius of curvature, step changes in internal diameter, high dogleg severity, among others.

[00092] The term "dogleg severity" (DLS) is generally meant to designate a bending between two points of a structure for every 30 meters, and is generally expressed in two-dimensional degrees per 30 meters, based on inclination (11,12) and azimuth (AZ1, AZ2), as exemplified in Fig. 3, for example. In a wellbore, a dogleg severity refers to a degree of bending within a curved segment of the wellbore. An ESP can operate in such a curved segment. However, bending occurs within the ESP as the ESP passes through the curved segment and behaves as a flexible structure. An ESP includes several distinct components that are linked by joints. These joints are weaker in bending than the components that constitute the ESP. As the ESP deflects when passing through a curved segment, bending stresses should be reduced in order to minimize resulting loads in the ESP that can result in premature failure. For a typical ESP being installed in a wellbore, one would want to have a dogleg severity of the wellbore to be a maximum of 2 degrees per 30 meters, to reduce bending of the ESP. A segment of the wellbore can have a first dogleg severity. A stabilization assembly 20 can be sized, shaped and positioned based on the profile of the segment or the first dogleg severity. Upon placement of the pump within, or deployment of the pump through the segment of the wellbore, the stabilization assembly is configured to reduce a deflection of the pump, thus effectively subjecting the pump to a second dogleg severity within the section, the second dogleg severity being less than the first dogleg severity such that bending stress induced in the pump is reduced.
That is, the stabilization assembly 20 operates to reduce the impact of the actual dogleg severity of the wellbore (the "first dogleg severity") to the impact of a lesser dogleg severity (the "second dogleg severity"). The actual dogleg severity of the wellbore has not changed, but the impact on the pump is as if the pump had been mounted in a wellbore that had a lesser dogleg severity, i.e., a wellbore having the second dogleg severity.
The stabilization assembly can be used in a segment of a wellbore having various degrees of dogleg severity. The same technique can be applied to various similarly elongated tool strings.

[00093] If one uses multiple stabilization assemblies 20, 20' as illustrated in Fig. 2, along the length of the submersible pump, the stabilization assemblies 20 will likely not all have the same geometry or dimensions, as the stabilization assemblies are generally configured in such a way that accounts for the profile of the segment of the wellbore 12 =

and the dimensions of the pump 10. Such a configuration will level out as much as possible deflections of the central axis 32 of the pump 10 and reduce bending stress, that would normally contribute to a shortened operating life of the pump, and other drawbacks associated to the use of submersible pumps, which would not occur with stabilization assemblies such as the ones described herein.

[00094] Although the present stabilization assembly 20 has been described in the context of a submersible pump 10, such an ESP used in a wellbore, the present stabilization assembly 20 could be used on various other types of elongated equipment or pumps, such as Progressing Cavity Pumps (PSP), to reduce deflections with respect to a central axis 32.

[00095] Moreover, although the present stabilization assembly 20 has been described in the context of use within a wellbore 12, the stabilization assembly can be particularly advantageous and useful in other tunnel-like structures, that are not necessarily underground, such as within pipelines that have a dogleg severity exceeding a maximum limit recommended for a tool being mounted therein.

[00096] As can be understood from Figs. 4a to 4d, for example, the at least one protruding component 26 and mounting component 24 can take on various different implementations, depending on the particular application for which these components are intended, and the desired end results.
Skidding Component Implementation

[00097] Figs. 5 and 6 show a detailed view of an implementation of a stabilization assembly 20. For example, the protruding component 26 can include at least one radially-extending component 40, having a trapezoidal form. The protruding component 26 can be provided with at least one outer skidding component 42 for skidding against walls of the wellbore 12.

[00098] As can also be understood from the accompanying drawings, the at least one outer skidding component 42 can take on various different implementations, depending on the particular application for which the skidding component is intended, and the desired end result.

= CA 2965130 2017-04-26

[00099] For example, referring to Fig. 6, the at least one outer skidding component 42 can be part of a sub-component of the protruding component 26. The skidding component 42 can include at least one flange 44 spanning across a corresponding radially-extending component 40. The skidding component 42 and the corresponding radially-extending component 40 can form a single integral piece made of the same material. The skidding component 42 can include a straight skidding component 42a positioned between slanted skidding components 42b, 42c that can be proximate and distal slanted sections.

[000100] The radially-extending components 40 shown in the Figs. 5 and 6 are illustrated as full radially-extending components 40. However, such radially-extending components 40 can be haped and configured otherwise. The components 40 can be provided with corresponding orifices or other types of structures, as shown for example in Fig. 2, so as to reduce an overall weight of the stabilization assembly 20, depending on the particular applications for which the stabilization assembly 20 would be intended, and the desired end results. In the implementation shown in Fig. 2, the outer skidding component 42 is distanced with respect to the mounting component 24, the latter two being connected through support arms 46, such that the resulting protruding component 26 has reduced weight.

[000101] The skidding component 42 can have a suitable transversal width, so as to provide proper skidding or sliding of the stabilization assembly 20, against the walls or different segments of the wellbore 12.

[000102] The skidding component 42 and the protruding component 26 can be made of the same material and form an integral piece, or alternatively, can be two distinct components that are connected to one another, with appropriate assembling or affixing techniques, such as welding, for example.

[000103] Referring to Fig. 5, the provision of slanted skidding components 42b, 42c enables the stabilization assembly 20 and pump 10 or a corresponding elongated tool string, to be displaced more easily along varying profiles of the wellbore 12, and/or when subject to changes in inside diameter, or other obstacles. Thus, the presence of one or several stabilization assemblies 20 can enable a smoother entry of the submersible pump 10 into the liner section 50, shown in Fig. 5.

[000104] The provision of proximate and distal slanted sections for the outer skidding components 42 also enables the stabilization assembly 20 to conveniently be displaced frontwardly and rearwardly, that is "in and out" along the different segments of the wellbore 12 or other similar tunnel-like configurations, which can have wall variations or different geometrical profiles or cross-sections therealong. Hence, the stabilization assembly 20 can skid across obstacles encountered both during deployment and removal of the submersible pump.
Protruding Component Configurations

[000105] In some implementations, as shown in Fig. 7, the protruding components 26 are disposed circumferentially about the mounting component 24.
In doing so, the stabilization assembly 20 has a cage-like structure, which is substantially cylindrical. The protruding components 26 can be preferably configured so that variation between a disposition of the stabilization assembly 20 resting on two protruding components 26 against a flat surface, and the disposition of the stabilization assembly 20 resting on only one protruding component 26 against the same flat surface of the wellbore, would be minimized.

[000106] Referring back to Fig. 6, in some implementations, the stabilization assembly 20 includes at least proximate and distal mounting components 24p, 24d being longitudinally spaced apart from one another, and as a result, each protruding component 26 can extend between the proximate and distal mounting components 24p, 24d.

[000107] Each protruding component 26 can include at least one bottom notch being positioned, shaped and sized for resting against the mounting component 24. In the example illustrated in Fig. 6, the bottom notch 52 is substantially L-shaped, although various other suitable shapes and forms can be used, depending on the type of interaction or cooperation desired between protruding component 26 and mounting component 24.
The provision of such a bottom notch 52 on each protruding component 26 enables to advantageously and conveniently rest each protruding component 26 onto corresponding sections of the proximate and distal mounting components 24p, 24d, for appropriate affixing onto each mounting component 24, such as via welding, for example.

= 17

[000108] The presence of such a bottom notch 52 is not limited necessarily to when protruding components extend between "first" and "second" mounting components 24p, 24d, but can also be contemplated even when protruding components are disposed about a single mounting component 24, as exemplified in Fig. 4b.
In such instances, each protruding component 26 can be provided with a corresponding notch 52, that can allow an easier or more convenient positioning and securing of the protruding component 26 about the mounting component 24, for easier assembly and/or welding.
Mounting Component Configurations

[000109] Referring to Fig. 6, in some implementations, each mounting component 24 can include first and second sub-components 24a,24b being connectable to one another, about a corresponding peripheral outer section of the submersible pump 10, by means of at least one connecting component 54.

[000110] In some implementations, the connecting component 54 includes a pair of connecting components 54a, 54b, each connecting component 54a, 54b interconnecting portions of the first and second sub-components 24a, 24b of a given mounting component 24. The connecting component 54 can include a plate 56 with corresponding fasteners 58 for removably connecting the first and second sub-components 24a, 24b to one another, although other types of connecting components are also possible.

[000111] For example, the connecting component 54 can include a bolt 58 insertable into a corresponding passage 60 defined between first and second sub-components 24a, 24b of a given mounting component 24. A head 58a of the bolt 58 can be configured for abutting against a portion of the passage 60 defined within the first sub-component 24a, and a tip 58b of the bolt 58 can be threadedly engageable within a portion of the passage 60 defined within the second sub-component 24b, so that tightening of the bolt 58 secures the first and second sub-components 24a, 24b against one another, about a corresponding peripheral outer section of the submersible pump 10.

[000112] Referring to Fig. 6, in some implementations, the stabilization assembly 20 can be provided with a first mounting component 24p including a pair of plates 56 and corresponding fasteners 58 (e.g. bolt, washer) as a first type of connecting component 54, and the stabilization assembly is further provided with a second mounting component 24d including split-collars 62 and corresponding bolts used as a second type of connecting =
component 54. Various modifications can be made to the present stabilization assembly.
For example, a stabilization assembly could be provided with similar first and second mounting components 24, in which case, the first and second mounting components 24p,24d can be both provided with the same first type of connecting component 54. Alternatively, the first and second mounting components can be both provided with the second type of connecting component 54, or with any other suitable connecting component 54 that would enable a removable and securable mounting of the stabilization assembly 20 about a corresponding outer component or peripheral outer section of the submersible pump 10 or any other type of elongated equipment to be displaced along the wellbore 12.

[000113] In some implementations, each mounting component 24 is a collar, and each sub-component 24a,24b is a slip-collar.

[000114] In some implementations, a clamping assembly including first and second strap collars positioned at opposite extremities of the stabilization assembly can be provided. Each strap collar can be pivotably opened about a hinge and closed around a component of the submersible pump. A taper pin can be used to lock the complementary shaped open ends of the strap collar in a locked configuration on the submersible pump component. A plurality of ribs links the first and second strap collars. The ribs are shaped and positioned to pass between the protruding components of the stabilization assembly and prevent rotation of the stabilization assembly. The clamping assembly can further include stop elements to reduce any axial or rotational movement of the stabilization assembly. The clamping assembly can be installed on motor, seal, intake or pump sections of the submersible pump, while avoiding the use of split-ring connectors and anti-rotation components as detailed below. The clamping assembly can be used on long motor sections that are about 20 to 30 feet long in order to be able to add a stabilization assembly in the middle of the motor section to maintain a preferred 10 to 14 feet spacing between stabilization assemblies to reduce bending of the submersible pump.
Anti-rotation / blocking component implementations

[000115] In some implementations, components can be provided to prevent rotation and/or axial displacement of the stabilization assembly 20 with respect to the pump. Figs.
9 and 10 show two different implementations of such components. Each mounting component 24 includes' an anti-rotation component 70 for preventing rotational displacement of the stabilization assembly 20 with respect to the submersible pump and/or a blocking component 72 for blocking axial displacement of the stabilization assembly 20 with respect to the submersible pump 10.

[000116] As seen in Figs. 9 and 10, the anti-rotation component 70 and/or the blocking component 72 can take on various different implementations, depending on the particular applications for which the blocking component is intended, and the desired end results.

[000117] For example, as shown in Fig. 9, the anti-rotation component 70 can include a male component, such as an anti-rotation tab 74 (welded onto a split ring of the mounting component 24) insertable into a corresponding female component, such as spacing between external bolts 76 provided about the submersible pump 10. In other implementations, as shown in Fig. 10, a female component, such as a slot opening 78 is provided for receiving a corresponding male component, such as a rub bar 80 provided about and welded to the submersible pump. These components interfere between themselves, thus preventing relative rotation between the stabilization assembly and the pump.

[000118] Similarly, the blocking component 72 can include a male component insertable into a corresponding female component provided about the submersible pump, a female component for receiving a corresponding male component provided about the submersible pump or a component to be welded onto a corresponding outer component provided about the submersible pump. In Figs. 9 and 10, the anti-rotation components 70 and the blocking components 72 are the same components as the components act against relative rotation and axial displacement of the stabilization assembly 20 with respect to the pump 10.

[000119] In some implementations, a certain minimal relative moment can be required or desired in terms of rotational and/or rotational movement of the stabilization assembly with respect to.the pump. In such cases, the minimal range of movement can also be provided with suitable dampening means for providing shock absorption capabilities to the stabilization assembly. Hence, the stabilization assembly 20 can be provided with suitable shock absorption or dampening means operatively connected between the stabilization assembly 20 and the pump 10 on which the stabilization assembly is mounted, so' that any impacts and/or shocks transmitted to the stabilization assembly 20 would minimally be transmitted (or at the very least, in a reduced manner) to the corresponding pump components, which can contain instrumentation or components that are sensitive to shocks, impacts, or vibrations.
Pump cabling and instrumentation implementations

[000120] In the stabilization assembly 20 shown as way of an example in Fig. 7, there are provided eight protruding components 26, equidistantly spaced from one another about each mounting component 24. This spacing between adjacent protruding components 26 allows passage of cabling or instrumentation 82 therebetween (indicated as a dotted line in Fig. 7), with minimal deviations or bending. The protruding components 26 can effectively offset the submersible pump 10 from a wall 84 of the wellbore 12 to allow cabling or instrumentation to pass between the pump and wall without interference. The protruding components 26 are designed to provide a wide enough area for the ESP cabling or instrumentation lines to lay flat as the cabling or instrumentation lines pass through the stabilization assembly 20.

[000121] If several stabilization assemblies 20 are mounted onto a common submersible pump, the assemblies, once mounted, can be aligned between themselves such that spaces between adjacent protruding components allowing passage of cabling and instrumentation therebetween are aligned also, to avoid any undue bending or deviation of the cabling or instrumentation.
Pump equipment implementations

[000122] As can also be understood from the accompanying drawings, the stabilization assembly 20 can be placed about different locations on and/or about different components of a submersible pump, according to various different implementations, depending on the intended particular application(s), and the desired end result(s).

[000123] In some implementations, referring to Fig. 11, a submersible pump includes 4 principal components: a pump component 100, an intake component 102 at the base of the pump component, a motor component 104 for driving the pump component and a seal component 106 for equalizing hydrostatic pressure of the well fluid with internal lubricant in the motor component. Cabling or instrumentation 108 can extend along a length of the pump 10 and connect to the motor component 104. The stabilization assembly 20 can thus be provided about one or several different components of the pump 10, including a distal end 110 of the pump, the pump component 100, the intake component 102, the motor component 104 and the seal component 106. In yet other implementations, as shown in Fig. 11, the stabilization assembly 20 is not limited to mounting about a peripheral outer component or peripheral outer section 112 of the pump 10 or elongated equipment but could also be provided about a distal or leading component 114 of the pump, for providing a smoother entry or transition of the pump 10, from one section to another, within a given wellbore 12. The stabilization assemblies 20 provided on or mounted about the pump 10 need not have the same geometrical configuration (outside diameter, shape and form). The stabilization assemblies 20 on a same pump could be easily adapted so as to have different outer diameters, for example, which could be selectively suited depending on the particular applications for which the pump is intended for, and the particular profiles or deviated segments along which the pump 10 is intended to be deployed within a given wellbore 12.
Deployment of stabilization assembly implementations

[000124] Various strategies can be undertaken in order to deploy a stabilization assembly 20 and a submersible pump 10 within a wellbore segment, and to alleviate bending and a deflection of the submersible pump along the segment. Referring now to Fig. 12, the stabilization process and deployment of the stabilization assembly can include several steps that will be explained in further detail below.

[000125] Collecting configuration data step (200): The initial step is to collect configuration data indicative of the configuration of one or more segments of the wellbore and of the configuration of the submersible pump. The size, shape and position of one or more stabilization assemblies can then be determined based on the configuration data, which can take into account irregularities, changes in outer diameter, high curvature or high dogleg severity, among other factors.

[000126] Mounting on pump components step (202): Once the proper stabilization assemblies have been ictentified with respect to the configuration data, the stabilization assemblies 20 can be mounted onto the pump using various techniques. The stabilization assemblies can be mounted on one or several different components of the pump 10, including a distal end 110 of the pump, the pump component 100, the intake component 102, the motor component 104 and the seal component 106.

[000127] Providing separation distance step (204): In some implementations, a separation distance of about 10 feet to about 14 feet between each stabilization assembly mounted about a peripheral outer section of the submersible pump is provided.

[000128] Aligning step (206): In some implementations, each stabilization assembly defines a passage for cabling or instrumentation extending along a length of the submersible pump. Aligning the stabilization assemblies is required to align the cabling and instrumentation passages, to avoid undue deviations and bending of these components.

[000129] Securing step (208): In some implementations, each stabilization assembly is secured about the submersible pump so as prevent rotation and axial displacement of the stabilization assembly with respect to the submersible pump.

[000130] Deploying step (210): In some implementations, the stabilized submersible pump is deployed downhole. The stabilized submersible pump can be deployed down a curved heel of the wellbore.

[000131] Landing step (212): In some implementations, the stabilized submersible pump is landed in an operational location which can include irregularities, changes in outer diameter, high curvature, deviations at an inclination or high dogleg severity. The operational location can also include an obstacle, such as a liner hanger. The stabilization assembly can alleviate bending in the submersible pump due to the irregularities, step changes in internal diameter of the wellbore, high curvature, high dogleg severity, deviations at an inclination or obstacles.
Example -use of stabilization assembly introduction

[000132] To handle the high total fluid rates and downhole temperature from SAGD
wells, high capacity pumps, intakes, seals and motor assemblies are utilized, forming an electric submersible pump. The submersible pump can be landed in the heel of the production well where the angle to vertical is close to 90 degrees. The sections below describe examples of the use of the stabilization assemblies to reduce bending stresses in submersible pumps in such scenarios.
History of problem

[000133] In a particular example wellbore, a shaft failure was identified in an ESP
protector component that was pulled after 484 days of runlife. Analysis showed that shaft failure was caused by the failure of a thrust bearing. 484 days is considered a good runlife for ESPs in the harsh SAGD environment.

[000134] SAGD wells were originally drilled under the premise that a gas lift would be used as the lift method. Hence, dogleg severities between 6 and 14 degrees per 30 m in such scenarios are common. These values are drastically above established ESP
operating recommended limits.

[000135] These operational conditions have resulted in an increased number of early failures of ESPs in certain SAGD wells. The runlives of those ESPs were short and only averaged about 40 days. The location of the failure was either the seal, intake or gas handler sections of the ESP.
Initial analysis

[000136] An investigation including stress calculations and failure analyses was performed to determine the main contributors of these failures. The investigation demonstrated that equipment outer diameter does not play an important role in ESP
bending when horizontally deployed. ESPs deployed horizontally have enough weight to follow even extreme casing curvature, irrespective of ESP string outer diameter or length.
Second, a significant contributor to high bending stress levels is ESP
equipment outer diameter miss-match between adjacent components. This can cause a cantilever bend on adjacent equipment, an effect that can only happen in horizontal or deviated segments. In several examples, failures were located between the pump component and the seal component. This cantilever bend produced a highly concentrated stress in the location of the shaft failures.

Experiments to determine failure points

[000137] Bending experiments were carried out on failing ESP systems. In order to investigate how much an ESP will bend, several experiments were performed. The first test was to confirm the stiffness of the assembled ESP string. A used ESP
system was assembled and placed on the floor to check the cantilever effect. This system was then blocked at both ends to determine the maximum amount of bend at room temperature conditions. The ESP system was then constrained at both ends to simulate an 8 degrees per 30 meter DLS.

[000138] The tests showed that the intake and seal components experience the highest bending stresses. Hence, for placement of ESP systems in a deviated well with a dogleg severity, the intake and seal sections should be positioned in the lowest dogleg severity section available.

[000139] Another bending experiment showed that a cantilever effect can result in a curvature of submersible pump that is equivalent to a 1 degree per 30 meter dogleg severity.
Laboratory bending stress reduction experiment with stabilization assemblies

[000140] In an example, ESP systems were constrained to simulate an 8 degrees per 30 meter dogleg severity. This system was then constrained to simulate stabilization assemblies placed at several points to reduce the bending of the system. The first system used a single support. In one example, the best location for the stabilization assembly was 21.5 feet from the pump end of a 44 foot long ESP system.

[000141] For the second longer 54-foot long ESP system, two supports were placed until the minimum bending occurred. On this 54-foot system, the best locations were determined to be at 15 feet and 29 feet from the pump end of the ESP system.
Onsite bending stress reduction experiment with stabilization assemblies

[000142] In another example, an ESP system was positioned in a well with an 8 degrees per 30 meter dogleg severity. The well had a history of short run lives for submersible pumps due to bearing and shaft seal failures from the high dogleg severity in which the pump was landed. In this example, the dogleg severity of the well was entirely inclination rather than azimuthal such that stabilization assemblies could be placed on the ESP system, support the weight of the ESP system, and reduce bending. The intermediate casing of the well was 13.375 inches with a 12.4 inch drift internal diameter.
Stabilization assemblies, with protruding components to allow instrumentation and ESP
cabling to pass through, were designed with a 12 inch outer diameter. The stabilization assemblies were welded to the top of the seal and motor components. Based on this design, the submersible pump was subjected to a maximum effective dogleg severity of the centerline that dropped from 8 degrees per 30 meters without the stabilization assembly to 5 degrees per 30 meters. The equipment was installed and operated for a one year period.
Analysis showed the pump shaft bearings and seals showed much less wear than previous ESP
systems with similar run life that did not have stabilization assemblies.

[000143] In another example, many wells were drilled with the following configuration of 13.375 inch intermediate casing with a liner hanger and 10.75 inch blank crossing over to a 9.625 inch blank before the slotted liner. A 5.5 inch tailpipe is landed just before the slots with a debris seal packer. In many of these wells, the lowest dogleg severity is in this area, but unfortunately the profile of the well presents steps in inner diameters which can induce bending on the submersible pump. In order to place an ESP system across the step changes, stabilization assemblies were designed to reduce deflections of the ESP
system. Stabilization assemblies were placed about 10 feet to about 14 feet apart and were shown to minimize the amount of bending between them.
Conclusion

[000144] Studies on premature submersible pump shaft failures identified that contributors to the failure were cantilever effects and high dogleg severity of the wells at the submersible pump setting depth. The use of stabilization assemblies has been shown to reduce the effect of these contributors to failure of submersible pumps.

[000145] Various modifications can be made to the disclosed implementations and still be within the scope of the following claims.
=

Claims

26

1. A stabilization assembly for use with a submersible pump employed for in situ recovery operations along a wellbore, the stabilization assembly comprising:
at least one mounting component mountable about an outer component of the submersible pump; and at least one protruding component protruding outwardly from the at least one mounting component, and being positioned, shaped and sized for providing support between the submersible pump and a segment of the wellbore and to alleviate bending of the submersible pump along the segment.

2. The stabilization assembly according to claim 1, wherein the at least one protruding component comprises at least one radially-extending component.

3. The stabilization assembly according to claim 1 or 2, wherein the at least one protruding component has a trapezoidal form.

4. The stabilization assembly according to any one of claims 1 to 3, wherein the at least one protruding component is provided with at least one outer skidding component for skidding against walls of the wellbore.

5. The stabilization assembly according to claim 4, wherein the at least one outer skidding component is a sub-component of the at least one protruding component.

6. The stabilization assembly according to claim 4 or 5, wherein the at least one outer skidding component comprises at least one flange spanning across a corresponding radially-extending component.

7. The stabilization assembly according to claim 6, wherein the at least one outer skidding component and the corresponding radially-extending component form one integral piece made of a common material.

8. The stabilization assembly according to any one of claims 4 to 7, wherein the at least one outer skidding component comprises a straight portion between two slanted portions.

9. The stabilization assembly according to any one of claims 4 to 8, wherein the at least one outer skidding component comprises proximate and distal slanted portions.

10. The stabilization assembly according to any one of claims 1 to 9, wherein the at least one protruding component is disposed circumferentially about the at least one mounting component.

11. The stabilization assembly according to any one of claims 1 to 10, wherein the at least one protruding component comprises at least one bottom notch being positioned, shaped and sized for resting against the at least one mounting component.

12. The stabilization assembly according to claim 11, wherein said at least one bottom notch is substantially L-shaped.

13. The stabilization assembly according to any one of claims 1 to 12, wherein the at least one mounting component comprises at least proximate and distal mounting components being longitudinally spaced apart from one another.

14. The stabilization assembly according to claim 13, wherein the at least one protruding component extends between the proximate and distal mounting components.

15. The stabilization assembly according to any one of claims 1 to 14, wherein each mounting component comprises first and second sub-components being connectable to one another, about a corresponding peripheral outer section of the submersible pump, by means of at least one connecting component.

16. The stabilization assembly according to claim 15, wherein said at least one connecting component comprises a pair of connecting components, each connecting component interconnecting portions of the first and second sub-components of a given mounting component.

17. The stabilization assembly according to any one of claims 1 to 16, wherein the at least one mounting component comprises a blocking component for blocking axial displacement of the stabilization assembly with respect to the submersible pump.

18. The stabilization assembly according to claim 17, wherein the blocking component comprises a blocking male component insertable into a corresponding blocking female component provided about the submersible pump.

19. The stabilization assembly according to claim 17, wherein the blocking component comprises a blocking female component for receiving a corresponding blocking male component provided about the submersible pump.

20. The stabilization assembly according to any one of claims 17 to 19, wherein the blocking component comprises a blocking joining component weldable onto a corresponding outer component provided about the submersible pump.

21. The stabilization assembly according to any one of claims 1 to 20, wherein the protruding components of the stabilization assembly are positioned, shaped and sized for providing support between the submersible pump and the wellbore, and to alleviate bending of the submersible pump when placed along a deviated segment of the wellbore.

22. The stabilization assembly according to any one of claims 1 to 21, wherein the protruding components of the stabilization assembly are positioned, shaped and sized for providing support between the submersible pump and the wellbore, in order to adjust a centerline of the submersible pump when placed along a deviated segment of the wellbore.

23. The stabilization assembly according to any one of claims 1 to 22, wherein the at least one protruding component comprises a plurality of protruding components.

24. The stabilization assembly according to claim 23, wherein the protruding components are spaced from one another about a given mounting component.

25. The stabilization assembly according to claim 23 or 24, wherein the protruding components define a passage for at least one of cabling and instrumentation extending along a length of the submersible pump.

26. The stabilization assembly according to any one of claims 1 to 25, wherein the at least one mounting component is configured to be mountable about a distal component of the submersible pump.

27. The stabilization assembly according to any one of claims 1 to 26, wherein the at least one mounting component is configured to be mountable about a peripheral outer component of the submersible pump.

28. The stabilization assembly according to any one of claims 1 to 27, wherein the at least one mounting component is configured to be mountable about a motor component of the submersible pump.

29. The stabilization assembly according to any one of claimsl to 28, wherein the at least one mounting component is configured to be mountable about a seal component of the submersible pump.

30. The stabilization assembly according to any one of claims 1 to 29, wherein the at least one mounting component is configured to be mountable about an intake component of the submersible pump.

31. The stabilization assembly according to any one of claimsl to 30, wherein the at least one mounting component is configured to be mountable about a pump component of the submersible pump.

32. The stabilization assembly according to any one of claims 1 to 31, wherein the submersible pump is an electric submersible pump.

33. A kit with components for assembling a stabilization assembly according to any one of claims 1 to 32.

34. The kit according to claim 33, wherein given components of the kit are provided with corresponding assembly interfaces for facilitating assembly of said given components with other components of the kit.

35. A method of stabilizing a submersible pump employed for in situ recovery operations along a segment of a wellbore, the method comprising:
mounting at least one stabilization assembly as defined in any one of claims 1 to 32 onto at least one corresponding outer component of the submersible pump for providing support between the submersible pump and the segment of the wellbore and to alleviate bending of the submersible pump along the segment; and deploying the submersible pump and the at least one stabilization assembly down the wellbore.

36. The method according to claim 35, wherein the mounting step comprises mounting at least one of the at least one stabilization assembly about a distal component of the submersible pump.

37. The method according to claim 35 or 36, the mounting step comprises mounting at least one of the at least one stabilization assembly about a peripheral outer component of the submersible pump.

38. The method according to any one of claims 35 to 37, wherein the mounting step comprises mounting at least one of the at least one stabilization assembly about a motor component of the submersible pump.

39. The method according to any one of claims 35 to 38, wherein the mounting step comprises mounting at least one of the at least one stabilization assembly about a seal component of the submersible pump.

40. The method according to any one of claims 35 to 39, wherein the mounting step comprises mounting at least one of the at least one stabilization assembly about an intake component of the submersible pump.

41. The method according to any one of claims 35 to 40, wherein the mounting step comprises mounting at least one of the at least one stabilization assembly about a pump component of the submersible pump.

42. The method according to any one of claims 35 to 41, wherein the mounting step comprises:
mounting a plurality of stabilization assemblies; and providing a separation distance of about 10 feet to about 14 feet between each stabilization assembly.

43. The method according to any one of claims 35 to 42, wherein the mounting step comprises securing each stabilization assembly about the submersible pump so as prevent axial displacement of the stabilization assembly with respect to the submersible pump.

44. The method according to any one of claims 35 to 43, wherein the mounting step comprises mounting a plurality of stabilization assemblies, each stabilization assembly defining a passage for at least one of cabling and instrumentation extending along a length of the submersible pump, and further comprising the step of aligning the stabilization assemblies to align the cabling and instrumentation passages.

45. The method according to any one of claims 35 to 44, further comprising, prior to mounting:
collecting configuration data indicative of a configuration of the segment of the wellbore and a configuration of the submersible pump; and determining the size, shape and position of the at least one stabilization assembly based on the configuration data.

46. A method for stabilizing a submersible pump within a wellbore, comprising:
providing at least one stabilization assembly according to any one of claims 1 to 32, wherein the at least one stabilization assembly is attached to the submersible pump; and placing the submersible pump within a segment of the wellbore having a first dogleg severity;
wherein the at least one stabilization assembly is configured to reduce a deflection of the submersible pump, thus effectively subjecting the submersible pump to a second dogleg severity within the segment, the second dogleg severity being less than the first dogleg severity such that bending stress induced in the submersible pump is reduced.

47. The method according to claim 46, wherein the first and second dogleg severities comprise an inclination value.

48. The method according to claim 46 or 47, wherein the first and second dogleg severities comprise an azimuth value.

49. A method for reducing bending stress on a tool string positioned within a wellbore, comprising:
collecting configuration data indicative of a configuration of a segment of the wellbore having a first dogleg severity and of a configuration of the tool string;
providing at least one stabilization assembly according to any one of claims 1 to 32, with a size, shape and position of the at least one stabilization assembly being based on the configuration data;
attaching the at least one stabilization assembly to the tool string; and placing the tool string within the segment of the wellbore;
wherein the at least one stabilization assembly is configured to reduce bending of the tool string, thus effectively subjecting the tool string to a second dogleg severity within the segment, the second dogleg severity being less than the first dogleg severity such that bending stress induced in the tool string is reduced.

50. A stabilization assembly for use with a submersible pump employed for in situ recovery operations along a wellbore, the stabilization assembly comprising:
a first mounting component mountable to a first outer section of the submersible pump;
a second mounting component mountable to a second outer section of the submersible pump in longitudinal spaced-apart relation to the first mounting component along the submersible pump; and at least one protruding component connected to the first mounting component and the second mounting component and extending therebetween, and protruding radially outward from the submersible pump, to provide support between the submersible pump and a segment of the wellbore and to alleviate bending of the submersible pump.

51. The stabilization assembly of claim 50, wherein the first mounting component comprises a first collar component mounted about a corresponding first section of the submersible pump.

52. The stabilization assembly of claim 51, wherein the first collar component comprises a first pair of sub-components connectable together.

53. The stabilization assembly of claim 52, wherein the first collar component comprises a connection mechanism configured to connect the first pair of sub-components.

54. The stabilization assembly of claim 53, wherein the connection mechanism comprises at least two plates and at least two sets of fasteners for removably connecting the first pair of sub-components.

55. The stabilization assembly of any one of claims 50 to 54, wherein the second mounting component comprises a second collar component mounted about a corresponding second section of the submersible pump.

56. The stabilization assembly of claim 52, wherein the second collar component comprises a second pair of sub-components connectable together.

57. The stabilization assembly of any one of claims 50 to 56, wherein the first and second mounting components are configured for mounting about the first and second outer sections that have a substantially constant diameter.

58. The stabilization assembly of any one of claims 50 to 57, wherein the at least one protruding component comprises multiple protruding components arranged about each of the first and second mounting components.

59. The stabilization assembly of claim 58, wherein the protruding components are configured in radially spaced-apart relation each other.

60. The stabilization assembly of claim 59, wherein the protruding components are evenly spaced apart with respect to each other.

61. The stabilization assembly of claim 59 or 60, wherein the protruding components define passages between adjacent pairs of the protruding components, the passages extending longitudinally between the first and second mounting components.

62. The stabilization assembly of claim 61, wherein the protruding components are arranged such that the passages are sized to allow deployment of cabling or instrumentation extending along the submersible pump.

63. The stabilization assembly of any one of claims 58 to 62, wherein each of the protruding components is formed as an integral piece of the same material.

64. The stabilization assembly of any one of claims 58 to 62, wherein each of the protruding components comprises an inward-facing surface proximate to the submersible pump, and an outward-facing surface available for contacting the wellbore.

65. The stabilization assembly of claim 64, wherein the inward-facing surface is configured to be substantially parallel with respect to an opposed surface of the submersible pump.

66. The stabilization assembly of claim 64 or 65, wherein the inward-facing surface is configured to be flat and planar, and to extend between the first and second mounting components.

67. The stabilization assembly of any one of claims 64 to 66, wherein the outward-facing surface comprises two opposed end regions and a middle region, the middle region being substantially parallel with respect to the inward-facing surface and the end regions extending obliquely toward each other from respective first and second mounting components.

68. The stabilization assembly of any one of claims 64 to 67, wherein each of the protruding components comprises a radially-extending component having two opposed end regions respectively connected to the first and second mounting components, the radially-extending component comprising the inward-facing surface.

69. The stabilization assembly of claim 68, wherein each of the protruding components comprises an outer skidding component connected to the radially-extending component.

70. The stabilization assembly of claim 69, wherein the outer skidding component comprises a flange spanning across the corresponding radially-extending component.

71. The stabilization assembly of claim 69 or 70, wherein the outer skidding component and the radially-extending component form an integral piece.

72. The stabilization assembly of any one of claims 50 to 71, wherein the at least one protruding component has a greater length along the submersible pump compared to that of each of the first and second mounting components.

73. The stabilization assembly of any one of claims 50 to 72, wherein the first and second mounting components are configured for mounting to a motor of the submersible pump.

74. The stabilization assembly of any one of claims 50 to 72, wherein the first and second mounting components are configured for mounting to a seal of the submersible pump.

75. The stabilization assembly of any one of claims 50 to 72, wherein the first and second mounting components are configured for mounting to an intake of the submersible pump.

76. The stabilization assembly of any one of claims 50 to 72, wherein the first and second mounting components are configured for mounting to a pump section of the submersible pump.

77. A system for stabilizing a submersible pump deployed in a wellbore, the system comprising:
a first stabilization assembly as defined in any one of claims 50 to 76, mountable with respect to a first part of the submersible pump;
a second stabilization assembly as defined in any one of claims 50 to 76 mountable with respect to a second part of the submersible pump and longitudinally spaced-apart from the first stabilization assembly.

78. The system of claim 77, wherein the first and second stabilization assemblies are configured to have different external diameters defined by respective protruding components.

79. The system of claim 77 or 78, wherein the first and second stabilization assemblies are respectively mountable to two distinct parts of the submersible pump.

80. The system of any one of claims 77 to 79, wherein the first stabilization assembly is configured to be mounted to a motor part of the submersible pump.

81. The system of any one of claims 77 to 79, wherein the first stabilization assembly is configured to be mounted to a seal part of the submersible pump.

82. The system of any one of claims 77 to 79, wherein the first stabilization assembly is configured to be mounted to an intake part of the submersible pump.

83. The system of any one of claims 77 to 79, wherein the first stabilization assembly is configured to be mounted to a pump component part of the submersible pump.

84. The system of claim 80, wherein the second stabilization assembly is configured to be mounted to a seal part of the submersible pump.

85. The system of claim 80, wherein the second stabilization assembly is configured to be mounted to an intake part of the submersible pump.

86. The system of claim 80, wherein the second stabilization assembly is configured to be mounted to a pump component part of the submersible pump.

87. The system of claim 81, wherein the second stabilization assembly is configured to be mounted to a motor part of the submersible pump.

88. The system of claim 81, wherein the second stabilization assembly is configured to be mounted to an intake part of the submersible pump.

89. The system of claim 81, wherein the second stabilization assembly is configured to be mounted to a pump component part of the submersible pump.

90. The system of claim 82, wherein the second stabilization assembly is configured to be mounted to a motor part of the submersible pump.

91. The system of claim 82, wherein the second stabilization assembly is configured to be mounted to a seal part of the submersible pump.

92. The system of claim 82, wherein the second stabilization assembly is configured to be mounted to a pump component part of the submersible pump.

93. The system of claim 83, wherein the second stabilization assembly is configured to be mounted to a motor part of the submersible pump.

94. The system of claim 83, wherein the second stabilization assembly is configured to be mounted to a seal part of the submersible pump.

95. The system of claim 83, wherein the second stabilization assembly is configured to be mounted to an intake part of the submersible pump.

96. The system of any one of claims 77 to 95, further comprising a third stabilization assembly as defined in any one of claims 50 to 76, the third stabilization assembly being mountable with respect to a third part of the submersible pump and longitudinally spaced-apart from the first and second stabilization assemblies.

97. The system of claim 96, wherein the first, second and third stabilization assemblies are respectively mountable to three distinct parts of the submersible pump.

98. The system of claim 97, wherein the three distinct parts are selected from the motor part, the seal part, the intake part and the pump component part.

99. A system for stabilizing a submersible pump deployed in a wellbore, the system comprising:
a first stabilization assembly as defined in any one of claims 1 to 32 or 50 to 76, mountable with respect to a first part of the submersible pump;
a second stabilization assembly mountable with respect to a second part of the submersible pump and longitudinally spaced-apart from the first stabilization assembly.

100. The system of claim 99, further comprising a third stabilization assembly mountable with respect to a third part of the submersible pump and longitudinally spaced-apart from the first stabilization assembly and the second stabilization assembly.

101. The system of claim 100, wherein the second and third stabilization assemblies are respective stabilization assemblies as defined as the in any one of claims 1 to 32 or 50 to 76.