GAS SEPARATOR

A reservoir fluid conducting system for use within a wellbore is disclosed. The system includes a flow diverter fluidly coupled to downhole disposed conductor and a pump fluidly coupled to the flow diverter. The flow diverter includes a flow diverter body that defines a reservoir fluid receiving space and a gas-depleted reservoir fluid receiving space separated and fluidly isolated from the reservoir fluid receiving space. In use, reservoir fluid is received within the reservoir fluid receiving space and conducted uphole to a reservoir fluid separation space via the flow diverter where, within the reservoir fluid separation space, a gas-depleted reservoir fluid is obtained and collects within the gas-depleted reservoir fluid receiving space. The pump is disposed in fluid communication with the gas-depleted reservoir fluid separation space such that the gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via a gas-depleted reservoir fluid-producing conductor.

FIELD

The present disclosure relates to mitigating downhole pump gas interference and the stresses applied to downhole wellbore equipment during coupling and de-coupling operations, as well as the adverse effects of solid particulate matter entrainment, during hydrocarbon production.

BACKGROUND

Downhole pump gas interference is a problem encountered while producing wells, especially wells with horizontal sections. In producing reservoir fluids containing a significant fraction of gaseous material, the presence of such gaseous material hinders production by contributing to sluggish flow. Additionally, solid particulate material is entrained in reservoir fluids, and such solid particulate matter can adversely affect production operations.

The installation or incorporation of gas separators into wellbore string components or equipment that include pump assemblies often requires fixed connections between sections of tubing or various fluid conductors. The connection and disconnection of these various tubing sections or fluid conductors with other wellbore tools or equipment, for example pump assemblies, for various wellbore operations and/or wellbore maintenance applies can, in some instance, apply stresses to the tubing and/or downhole wellbore equipment. Accordingly, wellbore equipment that minimizes the number of fixed connections between tubing strings and/or fluid conductors, etc. is desirable.

SUMMARY

In one aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the system comprises:a downhole-disposed conductor for receiving the reservoir fluid from a downhole wellbore space;a flow diverter fluidly coupled to the downhole disposed conductor, the flow diverter including a flow diverter body extending between an open lower end and an open upper end and defining an open interior space therebetween;a pump fluidly coupled to the flow diverter body; anda gas-depleted reservoir fluid-producing conductor fluidly coupled to the pump for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface;wherein:the downhole-disposed conductor, the pump, the flow diverter body, and the gas-depleted reservoir fluid-producing conductor are co-operatively configured such that the flow diverter body defines:a reservoir fluid receiving space disposed within the open interior space of the flow diverter body for receiving reservoir fluid discharged from the downhole disposed conductor;a gas-depleted reservoir fluid receiving space disposed within the open interior space of the flow diverter body uphole of the reservoir fluid receiving space; anda sealed interface fluidly isolating the gas-depleted reservoir fluid receiving space from the reservoir fluid receiving space;andwhile the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation:the reservoir fluid is conducted uphole to a reservoir fluid separation space via the flow diverter where, within the reservoir fluid separation space, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained;the gas-depleted reservoir fluid obtained within the reservoir fluid separation space is received by the flow diverter body and conducted to the pump via the gas-depleted reservoir fluid receiving space; andthe gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via the gas-depleted reservoir fluid-producing conductor.

In another aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string that includes a wellbore string-defined flow diverter counterpart, wherein the system comprises:a downhole-disposed conductor for receiving the reservoir fluid from a downhole wellbore space; anda production assembly, suspended within the wellbore, including:an assembly-defined flow diverter counterpart;a pump; anda gas-depleted reservoir fluid-producing conductor for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface;wherein:the assembly-defined flow diverter counterpart includes a flow diverter body, the flow diverter body extending between an open lower end and an open upper end and defining an open interior space therebetween; andthe wellbore string-defined flow diverter counterpart and the assembly-defined flow diverter counterpart are co-operatively configured to define a flow diverter;wherein:the pump is releasably connected to the flow diverter; andthe flow diverter body defines a reservoir fluid receiving space disposed within the open interior space of the flow diverter body for receiving reservoir fluid discharged from the downhole disposed conductor, and a gas-depleted reservoir fluid receiving space disposed within the open interior space of the flow diverter body uphole of the reservoir fluid receiving space, the reservoir fluid receiving space and the gas-depleted reservoir fluid receiving space being cooperatively configured such that the reservoir fluid receiving space is fluidly isolated from the gas-depleted reservoir fluid receiving space; andthe downhole-disposed conductor, the flow diverter body, the pump, and the gas-depleted reservoir fluid-producing conductor are co-operatively configured such that, while the downhole-disposed conductor is receiving reservoir fluid from the downhole wellbore space that has been received within the downhole wellbore space from the subterranean formation:the reservoir fluid is received within the reservoir fluid receiving space and conducted uphole to a reservoir fluid separation space via the flow diverter;within the reservoir fluid separation space, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained;the gas-depleted reservoir fluid obtained within the reservoir fluid separation space is received within the flow diverter body and conducted to the pump via the gas-depleted reservoir fluid receiving space; andthe gas-depleted reservoir fluid is pressurized by the pump and conducted to the surface via the gas-depleted reservoir fluid-producing conductor.

In another aspect, there is provided a reservoir fluid production assembly for disposition within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the reservoir fluid production assembly comprises:an assembly-defined flow diverter counterpart;a pump; anda gas-depleted reservoir fluid-producing conductor fluidly coupled to the pump for conducting gas-depleted reservoir fluid, that has been pressurized by the pump, to the surface;wherein the assembly-defined flow diverter counterpart includes:a pump-seating body for receiving and releasably-connecting with the pump; anda flow diverter body extending between an open upper end and an open lower end, the flow diverter body defining:a gas-depleted reservoir fluid receiver disposed at the open upper end of the flow diverter body for receiving gas-depleted reservoir fluid obtained within a reservoir fluid separation space;a gas-depleted reservoir fluid receiving space for receiving gas-depleted reservoir fluid from the gas-depleted reservoir fluid receiver;a reservoir fluid receiving space disposed downhole from the gas-depleted reservoir fluid receiving space for receiving reservoir fluid from the subterranean formation, the reservoir fluid receiving space being fluidly isolated from the gas-depleted reservoir fluid receiving space; anda reservoir fluid discharge opening disposed at the open lower end of the flow diverter body;anda first supporting member for suspending the flow diverter body from the pump seating body;wherein the pump-seating body, the flow diverter body, the pump, the gas-depleted reservoir fluid-producing conductor and the supporting member are co-operatively configured such that:the pump-seating body is disposed within the open upper end of the flow diverter body such that the pump-intake conducting passage is fluidly coupled to the gas-depleted reservoir fluid receiving space for conducting gas-depleted reservoir fluid to the pump for displacement uphole via the gas-depleted reservoir fluid-producing conductor; andthe flow diverter body is suspended from the pump-seating body by the supporting member such that a gas-depleted reservoir fluid conducting passage is disposed between the pump-intake conducting passage and the flow diverter body for conducting gas-depleted reservoir fluid received within the gas-depleted reservoir fluid receiver to the gas-depleted reservoir fluid receiving space.

DESCRIPTION OF EXAMPLE EMBODIMENTS

As used herein, the terms “up”, “upward”, “upper”, or “uphole”, mean, relativistically, in closer proximity to the surface106and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore102. The terms “down”, “downward”, “lower”, or “downhole” mean, relativistically, further away from the surface106and in closer proximity to the bottom of the wellbore102, when measured along the longitudinal axis of the wellbore102.

Referring toFIGS. 1 and 2, there are provided systems8, with associated apparatuses, for producing hydrocarbons from a reservoir, such as an oil reservoir, within a subterranean formation100, when reservoir pressure within the oil reservoir is insufficient to conduct hydrocarbons to the surface106through a wellbore102.

The wellbore102can be straight, curved, or branched. The wellbore102can have various wellbore sections. A wellbore section is an axial length of a wellbore102. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to “corkscrew” or otherwise vary. In some embodiments, for example, the central longitudinal axis of the passage102CC defined by a horizontal section102C is disposed along an axis that is between about 70 and about 110 degrees relative to the vertical “V”, the central longitudinal axis of the passage102AA of a vertical section102A is disposed along an axis that is less than about 20 degrees from the vertical “V”, and a transition section102B is disposed between the sections102A and102C. In some embodiments, for example, the transition section102B joins the sections102A and102C. In some embodiments, for example, the vertical section102A extends from the transition section102B to the surface106.

“Reservoir fluid” is fluid that is contained within an oil reservoir. Reservoir fluid may be liquid material, gaseous material, or a mixture of liquid material and gaseous material. In some embodiments, for example, the reservoir fluid includes water and hydrocarbons, such as oil, natural gas condensates, or any combination thereof.

Fluids may be injected into the oil reservoir through the wellbore to effect stimulation of the reservoir fluid. For example, such fluid injection is effected during hydraulic fracturing, water flooding, water disposal, gas floods, gas disposal (including carbon dioxide sequestration), steam-assisted gravity drainage (“SAGD”) or cyclic steam stimulation (“CSS”).

In some embodiments, for example, the same wellbore is utilized for both stimulation and production operations, such as for hydraulically fractured formations or for formations subjected to CSS. In some embodiments, for example, different wellbores are used, such as for formations subjected to SAGD, or formations subjected to waterflooding.

A wellbore string113is employed within the wellbore102for stabilizing the subterranean formation100. In some embodiments, for example, the wellbore string113also contributes to effecting fluidic isolation of one zone within the subterranean formation100from another zone within the subterranean formation100.

The fluid productive portion of the wellbore102may be completed either as a cased-hole completion or an open-hole completion.

A cased-hole completion involves running wellbore casing113A down into the wellbore through the production zone. In this respect, in the cased-hole completion, the wellbore string113includes wellbore casing113A.

The annular region between the deployed wellbore casing and the oil reservoir may be filled with cement for effecting zonal isolation (see below). The cement is disposed between the wellbore casing and the oil reservoir for the purpose of effecting isolation, or substantial isolation, of one or more zones of the oil reservoir from fluids disposed in another zone of the oil reservoir. Such fluids include reservoir fluid being produced from another zone of the oil reservoir (in some embodiments, for example, such reservoir fluid being flowed through a production tubing string disposed within and extending through the wellbore casing to the surface), or injected fluids such as water, gas (including carbon dioxide), or stimulations fluids such as fracturing fluid or acid. In this respect, in some embodiments, for example, the cement is provided for effecting sealing, or substantial sealing, of flow communication between one or more zones of the oil reservoir and one or more others zones of the oil reservoir (for example, such as a zone that is being produced). By effecting the sealing, or substantial sealing, of such flow communication, isolation, or substantial isolation, of one or more zones of the oil reservoir, from another subterranean zone (such as a producing formation), is achieved. Such isolation or substantial isolation is desirable, for example, for mitigating contamination of a water table within the oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or combinations thereof) being produced, or the above-described injected fluids.

In some embodiments, for example, the cement is disposed as a sheath within an annular region between the wellbore casing and the oil reservoir. In some embodiments, for example, the cement is bonded to both of the production casing and the subterranean formation100.

In some embodiments, for example, the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents, or substantially prevents, produced reservoir fluid of one zone from being diluted by water from other zones. (c) mitigates corrosion of the wellbore casing, (d) at least contributes to the support of the wellbore casing, and e) allows for segmentation for stimulation and fluid inflow control purposes.

The cement is introduced to an annular region between the wellbore casing and the subterranean formation100after the subject wellbore casing has been run into the wellbore102. This operation is known as “cementing”.

In some embodiments, for example, the wellbore casing includes one or more casing strings, each of which is positioned within the well bore, having one end extending from the well head. In some embodiments, for example, each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.

Typically, a wellbore contains multiple intervals of concentric casing strings, successively deployed within the previously run casing. With the exception of a liner string, casing strings typically run back up to the surface106. Typically, casing string sizes are intentionally minimized to minimize costs during well construction. Generally, smaller casing sizes make production and artificial lifting more challenging.

For wells that are used for producing reservoir fluid, few of these actually produce through wellbore casing. This is because producing fluids can corrode steel or form undesirable deposits (for example, scales, asphaltenes or paraffin waxes) and the larger diameter can make flow unstable. In this respect, a production string is usually installed inside the last casing string. The production string is provided to conduct reservoir fluid, received within the wellbore, to the116. In some embodiments, for example, the annular region between the last casing string and the production tubing string may be sealed at the bottom by a packer500.

The wellbore102is disposed in flow communication (such as through perforations provided within the installed casing or liner, or by virtue of the open hole configuration of the completion), or is selectively disposable into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the subterranean formation100. When disposed in flow communication with the subterranean formation100, the wellbore102is disposed for receiving reservoir fluid flow from the subterranean formation100, with effect that the system8receives the reservoir fluid.

In some embodiments, for example, the wellbore casing is set short of total depth. Hanging off from the bottom of the wellbore casing, with a liner hanger or packer, is a liner string. The liner string can be made from the same material as the casing string, but, unlike the casing string, the liner string does not extend back to the wellhead116. Cement may be provided within the annular region between the liner string and the oil reservoir for effecting zonal isolation (see below), but is not in all cases. In some embodiments, for example, this liner is perforated to effect flow communication between the reservoir and the wellbore. In this respect, in some embodiments, for example, the liner string can also be a screen or is slotted. In some embodiments, for example, the production tubing string may be engaged or stung into the liner string, thereby providing a fluid passage for conducting the produced reservoir fluid to the wellhead116. In some embodiments, for example, no cemented liner is installed, and this is called an open hole completion or un-cemented casing completion.

An open-hole completion is effected by drilling down to the top of the producing formation, and then lining the wellbore (such as, for example, with a wellbore string113). The wellbore is then drilled through the producing formation, and the bottom of the wellbore is left open (i.e. uncased), to effect flow communication between the reservoir and the wellbore. Open-hole completion techniques include bare foot completions, pre-drilled and pre-slotted liners, and open-hole sand control techniques such as stand-alone screens, open hole gravel packs and open hole expandable screens. Packers and casing can segment the open hole into separate intervals and ported subs can be used to effect flow communication between the reservoir and the wellbore.

Referring now toFIGS. 1 and 2there are shown example embodiments of reservoir fluid production systems according to example embodiments of the present disclosure.

In some embodiments, for example, the system8, includes a downhole disposed conductor202for receiving reservoir fluid from a downhole wellbore space110. A flow diverter600is fluidly coupled to the downhole disposed conductor202and a pump302is fluidly coupled to flow diverter600. In some embodiments, for example, the pump is releasably coupled to the flow diverter600. A gas-depleted reservoir fluid producing conductor204is fluidly coupled to the pump302for conducting gas-depleted reservoir fluid, that has been pressurized by the pump302, to the surface106. The downhole-disposed conductor202, the flow diverter600, the pump302, and the gas-depleted reservoir fluid-producing conductor204are co-operatively configured such that, while the downhole-disposed conductor202is receiving reservoir fluid from the downhole wellbore space110, which reservoir fluid has been received within the downhole wellbore space110from the subterranean formation100, the reservoir fluid is conducted uphole to a reservoir fluid separation space112X via the flow diverter600where, within the reservoir fluid separation space112X, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained.

The flow diverter600is provided for, amongst other things, mitigating gas lock within the pump302. In this respect, the flow diverter600is configured for receiving reservoir fluid that has been received by the wellbore102within the downhole wellbore space110from the subterranean formation100, and separating gaseous material from the received reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. In some embodiments, for example, the flow diverter600is disposed within a vertical portion102A of the wellbore102that extends to the surface106. The flow diverter600is fluidly coupled to the pump302for effecting supply of the gas-depleted reservoir fluid received within the flow diverter600to the pump302.

The pump302is provided to, through mechanical action, pressurize and effect conduction of the gas-depleted reservoir fluid to the surface106, and thereby effect production of the gas-depleted reservoir fluid via the gas-depleted reservoir fluid producing conductor204. In some embodiments, for example, the pump302is a sucker rod pump. Other suitable pumps302include screw pumps, electrical submersible pumps, jet pumps, and plunger lift, for example.

In some embodiments, for example, the system8includes a production assembly10. The production assembly10is suspended within the wellbore102from the wellhead116.

In some embodiments, for example, the assembly10includes the pump302and the gas-depleted reservoir fluid-producing conductor204, and the flow diverter600. The gas-depleted reservoir fluid-producing conductor204is fluidly coupled to the pump302for conducting the pressurized gas-depleted reservoir fluid that is received by the pump302, to the surface106.

The assembly10is disposed within the wellbore string113, such that an intermediate wellbore passage112is defined within the wellbore string113, between the assembly10and the wellbore string113. In some embodiments, for example, the intermediate wellbore passage112is an annular space disposed between the assembly10and the wellbore string113. In some embodiments, for example, the intermediate wellbore passage112is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly10, from the assembly10to the wellbore fluid conductor113. In some embodiments, for example, the intermediate wellbore passage112extends longitudinally to the wellhead116, between the assembly10and the wellbore string113.

In some embodiments, the flow diverter600includes a wellbore string counterpart600B and an assembly counterpart600C. The wellbore string113defines the wellbore string counterpart600B, and the assembly10defines the assembly counterpart600C. The flow diverter defines: (i) a reservoir fluid-conducting passage6002for conducting reservoir fluid that is received within a downhole wellbore space from the subterranean formation100, to the reservoir fluid separation space112X of the wellbore102, with effect that gas-depleted reservoir fluid is separated from the reservoir fluid within the reservoir fluid separation space112X in response to at least buoyancy forces; and (ii) a gas-depleted reservoir fluid conducting passage6004for receiving the separated gas-depleted reservoir fluid while the separated gas-depleted reservoir fluid is flowing in a downhole direction, and diverting the flow of the received gas-depleted reservoir fluid such that the received gas-depleted reservoir fluid is conducted by the flow diverter600in the uphole direction to the pump302.

In some embodiments, for example, the assembly counterpart600C includes a flow diverter body602and, in some embodiments, the flow diverter body602includes a shroud603. In this respect, the shroud603is cooperatively disposed relative to the wellbore string counterpart600B such that an intermediate reservoir fluid-conducting passage1112(such as, for example, an annular fluid passage) is disposed between the shroud603and the wellbore string counterpart600B. The intermediate reservoir fluid conducting passage1112forms part of the reservoir fluid conducting passage6002. In some embodiments, for example, the intermediate reservoir fluid-conducting passage1112includes the reservoir fluid-conducting passage6002and is disposed for conducting the received reservoir fluid to the reservoir fluid separation space112X. In some embodiments, for example, the intermediate wellbore passage112includes the intermediate reservoir fluid-conducting passage1112and the reservoir fluid-conducting passage6002.

In some embodiments, for example, the flow diverter body602or shroud603includes a tubular member that extends between an open upper end604and an open lower end606and defines an open interior space therebetween.

In some embodiments, for example, the wellbore string113or the wellbore string counterpart600B is defined by a 5½″ casing.

In some embodiments, the flow diverter body602or shroud603includes an opening605for receiving the separated gas-depleted reservoir fluid such that the separated gas-depleted reservoir fluid is conducted via the gas-depleted reservoir fluid conducting passage6004to the pump302. In this respect, the opening605defines a gas-depleted reservoir fluid receiver. In some embodiments, for example, the opening605is disposed at an uphole end of the shroud603or flow diverter body602, and the gas-depleted reservoir fluid-conducting passage6004extends downhole from the uphole end for conducting the received gas-depleted reservoir fluid in a downhole direction. In some embodiments, for example, the opening605includes the open upper end604of the flow diverter body602or shroud603, the flow diverter body602or shroud603being disposed within the wellbore102such that the opening upper end604is disposed for receiving the separated gas-depleted reservoir fluid, the open upper end604therefore serving as the gas-depleted reservoir fluid receiver. The reservoir fluid separation space112X is disposed uphole, such as vertically above, the opening605or open upper end604of the flow diverter body602or shroud603.

In some embodiments, the flow diverter body602, or shroud603, is disposed within the wellbore113such that it cooperates with a wellbore string counterpart602B defined by a corresponding portion of the wellbore string113. The flow diverter body602is disposed within the wellbore113and is cooperatively configured with the wellbore string counterpart602B to define the intermediate reservoir fluid-conducting passage6002for conducting reservoir fluid that is received within a downhole wellbore space110from the subterranean formation100and conducted to an uphole wellbore space108via the downhole disposed conductor202, to the reservoir fluid separation space112X of the wellbore102where, within the reservoir fluid separation space112X, the gas-depleted reservoir fluid is separated from the reservoir fluid in response to at least buoyancy forces. In some embodiments, for example, the reservoir fluid separation space112X is configured such that, in operation, while reservoir fluid is being supplied to the reservoir fluid separation space112X, the velocity of the gaseous portion of the reservoir fluid being conducted via the intermediate reservoir fluid conducting passage6002is greater than the critical liquid lifting velocity, and while the reservoir fluid is disposed within the reservoir fluid separation space112X, the velocity of the gaseous portion of the reservoir fluid is sufficiently low such that the above-described separation is effected.

In some embodiments, there is provided a pump assembly and the pump assembly includes the pump302and a pump-seating body700. The pump-seating body defines a pump-seating receptacle for receiving and releasably connecting with the pump302. The pump-seating body700also defines a pump-intake conducting passage704for conducting the gas-depleted reservoir fluid obtained within the reservoir fluid separation space112X to the pump302. In some embodiments, the pump-seating receptacle702includes a pump-seating nipple705for effecting the releasable coupling or releasable connection between the pump302and the pump-seating body700such that the pump302is disposed for receiving the gas-depleted reservoir fluid.

In some embodiments, the flow diverter body602or shroud603and the pump-seating body700are cooperatively configured such that the gas-depleted reservoir fluid conducting passage6004is disposed between the shroud603and the pump-seating body700for delivering the gas-depleted reservoir fluid obtained within the reservoir fluid separation space112X to the pump302via the pump-intake conducting passage704.

In some embodiments, for example, the flow diverter body602or shroud603and the pump-seating body700are cooperatively configured such that bypassing of the pump-intake conducting passage704by the gas-depleted reservoir fluid that is received and conducted by the gas-depleted reservoir fluid conducting passage6004is prevented or substantially prevented. In this respect, in some embodiments, for example, the flow diverter body602includes a flow-blocking member or sealed interface800disposed intermediate the open upper end604and the open lower end606for preventing or substantially preventing such bypassing. In some embodiments, the sealed interface800is disposed within the flow diverter body602or shroud603such that the sealed interface800divides the opening interior space into an upper open interior space608and a lower open interior space610, the upper open interior608being fluidly isolated from the lower open interior space610.

In some embodiments, the pump-seating receptacle702has a diameter that is greater than a diameter of the pump-intake conducting passage704.

In some embodiments, the pump-seating body700and the flow diverter body602are cooperatively configured such that the pump-seating receptacle702is disposed uphole of the open upper end604of the flow diverter body602with the pump-intake conducting passage704extending into the upper open interior space608of the flow diverter body602through the open upper end604such that the gas-depleted reservoir fluid-conducting passage6004is defined between the pump-intake conducting passage704of the pump-seating body700and the flow diverter body602or shroud603for conducting the separated gas-depleted reservoir fluid that is obtained within the reservoir fluid separation space112X to a gas-depleted reservoir fluid receiving space6006defined within the flow diverter body602uphole of the sealed interface800from where it is conducted to the pump302via the pump-intake conducting passage704where the fluid is pressurized by the pump302and conducted uphole to the surface106via the gas-depleted reservoir fluid producing conductor204. In this respect, the pump-seating body700is cooperatively configured with the flow diverter body602such that the pump-intake conducting passage704is fluidly coupled or disposed in fluid communication with the gas-depleted reservoir fluid receiving space6006.

In some embodiments, for example, a supporting member900suspends the flow diverter body602from the pump-seating body700such that the gas-depleted reservoir fluid conducting passage6004is disposed between the pump seating body700and an inner surface601of the flow diverter body602or shroud603. Therefore, in some embodiments, the pump-seating body700, the supporting member900and the flow diverter body602are cooperatively configured such that the gas-depleted reservoir fluid-conducting passage6004is defined between the pump-seating body700and a corresponding inner surface601of the flow diverter body602. In some embodiments, for example, the gas-depleted reservoir fluid-conducting passage6004is an annular space disposed between the pump-seating body700and the flow diverter body602. In some embodiments, the gas-depleted reservoir fluid-conducting passage6004is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly10, from the pump-seating body700to the flow diverter body602. In some embodiments, the gas-depleted reservoir fluid-conducting passage6004extends longitudinally from the open upper end606of the flow diverter body602to the closed end defined within the flow diverter body602by the sealed interface800in the space between the pump seating body700and the flow diverter body602.

In some embodiments, for example, the sealed interface800is disposed within the flow diverter body602and divides the flow diverter body602, or shroud603, into the upper interior space608that extends between one side of the sealed interface800and the open upper end604of the flow diverter body602, and a lower interior space610that extends between the opposite side of the sealed interface800and the open lower end606of the flow diverter body602. Accordingly, in some embodiments the closed end of the gas-depleted reservoir fluid-conducting passage6004is defined by one side of the sealed interface800.

In some embodiments, the gas-depleted reservoir fluid receiving space6006is disposed within the upper interior space608of the flow diverter body602. In some embodiments, therefore, the gas-depleted reservoir fluid receiving space6006is defined at a bottom end of the upper interior space608of the flow diverter body602. In some embodiments, disposition of the flow blocking member or sealed interface800within the flow diverter body602, or shroud603, is such that a sealed interface is effected between the inner surface601of the flow diverter body602and the corresponding surface of flow-blocking member or sealed interface800such that the upper interior space608is fluidly isolated from the lower open interior space610.

In some embodiments, the supporting member900includes a hanger assembly. In some embodiments, the supporting member900is disposed uphole of the flow diverter flow blocking member800and is selected such that the supporting member900, or hanger assembly, does not impede fluid flow within the gas-depleted reservoir fluid conducting passage6004. Therefore, in some embodiments, the supporting member900, or hanger assembly, is selected such that suspension of the flow diverter body602from the pump-seating body700is with effect that fluid flow of the gas-depleted reservoir fluid from the wellbore separation space112X to the gas-depleted reservoir fluid receiving space6006across the supporting member900, or hanger assembly, is permitted. In some embodiments, the supporting member900, or hanger assembly, is selected such that suspension of the flow diverter body602from the pump-seating body700is with effect that interference to the flow of gas-depleted reservoir fluid within the gas-depleted reservoir fluid conducting passage6004to the gas-depleted reservoir fluid receiving space6006is prevented, or substantially prevented.

In some embodiments, a further supporting member902supports the assembly counterpart600C within the wellbore string113or relative to the wellbore counterpart600B. In some embodiments, for example, the supporting member902supports the flow diverter body602or shroud603within the wellbore102relative to a corresponding portion of the wellbore string113. In this respect, the supporting member902supports the flow diverter body602or shroud603relative to the corresponding portion of the wellbore string113such that it does not impede, or substantially does not impede, flow through the intermediate reservoir fluid conducting passage6002. In some embodiments, for example, the supporting member902includes a hanger assembly.

In some embodiments, for example as shown inFIG. 2, the sealed interface800includes the supporting member900, as will be described in further detail below in reference to the example embodiment illustrated inFIG. 2. In such embodiments, the sealed interface800prevents, or substantially prevents, fluid flow across the sealed interface800while supporting the flow diverter body602from the pump-seating body700.

Referring again toFIG. 1, in some embodiments, the pump-seating body700is disposed within the flow diverter body602, or shroud603, such that the pump-seating body700has a distal end706that is disposed within the open upper interior space608and is spaced apart from the flow diverter flow-blocking member or sealed interface800. In some embodiments, the gas-depleted reservoir fluid receiving space6006is defined within the upper interior space608of the flow diverter body602between the sealed interface800and the distal end706of the pump-seating body700.

In some embodiments, the pump-intake conducting passage704extends between the distal end706of the pump-seating body700and the pump-seating receptacle702, and disposition of the pump-seating body700within the flow diverter602is such that the pump-intake conducting passage704is disposed in fluid communication with the gas-depleted reservoir fluid receiving space6006. Therefore, while gas-depleted reservoir fluid is being received within the gas-depleted reservoir fluid receiving space6006from the wellbore separation space112X via the gas-depleted reservoir fluid conducting passage6004, gas-depleted reservoir fluid is supplied to the pump302via the pump-intake conducting passage704.

The flow diverter body602, or shroud603, further defines a reservoir fluid receiving space6008for receiving reservoir fluid that is conducted from the downhole wellbore space110to the uphole wellbore space108. In some embodiments, the downhole disposed conductor202and the flow diverter600are cooperatively configured such that the downhole disposed conductor202is disposed in fluid communication with the reservoir fluid receiving space6008such that the reservoir fluid that is received within the downhole wellbore space110from the subterranean100and is conducted uphole to the uphole wellbore space108via the downhole disposed conductor202is discharged into the reservoir fluid receiving space6008from where it is conducted to the wellbore separation space112X.

In some embodiments, for example, the downhole disposed conductor202includes a discharge end203from which reservoir fluid, that is received within the downhole wellbore space110from the subterranean formation100, is discharged uphole into the reservoir fluid receiving space6008defined by the flow diverter body602, or shroud603.

In some embodiments, the flow diverter body602and the downhole disposed conductor202are cooperatively configured such that a reservoir fluid conducting passage6010fluidly interconnects the reservoir fluid receiving space6008and the intermediate reservoir fluid conducting passage6002, the reservoir fluid receiving space6008being defined within the lower interior space610of the flow diverter body602downhole of the sealed interface800. In this respect, the reservoir fluid conducting passage6010extends between the closed, upper end of the lower interior space610, as defined by the sealed interface800to the open, lower end606of the flow diverter body602or shroud603, the open lower end606therefore, in some embodiments, serving as a received reservoir fluid outlet611.

As shown inFIG. 1, in some embodiments, the downhole disposed conductor202and the flow diverter body602are cooperatively configured such that the downhole disposed conductor202is disposed within the open lower end606of the flow diverter body602, or shroud603, such that the discharge end203of the downhole disposed conductor202is spaced apart from the sealed interface800. Therefore, in some embodiments, the flow diverter body602, the sealed interface800and the downhole disposed conductor202are cooperatively configured such that the discharge end203of the downhole disposed conductor202remains spaced apart from the flow diverter flow-blocking member or sealed interface800and free from any connection to or free from support from the flow diverter body602or shroud603. Therefore, in some embodiments, for example, there is an absence, or a substantial absence, of support to the downhole disposed conductor202by the assembly10. Therefore, in the subject example embodiment, for example, the downhole disposed conductor202is not subject to the same degree of stress that can be effected where there are fixed connections between the various fluid conducting members within the overall system8. Therefore, the absence of a fixed connection between the production assembly10and the downhole disposed conductor202serves to relieve stress that would otherwise be experienced by the downhole disposed conductor202caused by movement of either the pump-assembly or downhole disposed conductor202during maintenance and/or other downhole operations thereby leaving the downhole disposed conductor free from, or substantially free from, stresses typically associated with pump-connection/disconnection operations.

In some embodiments, the reservoir fluid receiving space6008is defined within the lower open space610of the flow diverter body602between the discharge end203of the downhole disposed conductor202and the sealed interface800while the reservoir fluid-conducting passage6010is defined between the downhole disposed conductor202and a corresponding inner surface of the flow diverter body602. In some embodiments, for example, the reservoir fluid-conducting passage6010is an annular space disposed between the downhole disposed conductor202and the flow diverter body602. In some embodiments, the reservoir fluid-conducting passage6010is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly10, from at least a vertical, or substantially vertical, portion of the downhole disposed conductor202to the flow diverter body602. In some embodiments, the reservoir fluid-conducting passage6010extends longitudinally from the sealed interface800to the open lower end606of the flow diverter body602between the downhole disposed conductor202and the flow diverter body602.

In some embodiments, for example, the system8also includes a wellbore string sealed interface500for preventing, or substantially preventing, bypassing of the reservoir fluid separation space112X by the reservoir fluid that is supplied to the uphole wellbore space108by the downhole-disposed conductor202. In some embodiments, for example, the sealed interface500is defined by a sealed interface effector502, such as, for example, a packer.

In some embodiments, for example, the sealed interface500is defined within the wellbore102, between: (a) the uphole wellbore space108of the wellbore102, and (b) the downhole wellbore space110of the wellbore102. In some embodiments, for example, the disposition of the sealed interface500is such that flow communication, via the intermediate wellbore passage112, between the uphole wellbore space108and the downhole wellbore space110(and across the sealed interface500), is prevented, or substantially prevented. In some embodiments, for example, the disposition of the sealed interface500is such that fluid flow, across the sealed interface500, in a downhole direction, from the uphole wellbore space108to the downhole wellbore space110, is prevented, or substantially prevented. In this respect, the sealed interface500functions to prevent, or substantially prevent, reservoir fluid flow, that is received within the uphole wellbore space108via the downhole disposed conductor202, from bypassing the reservoir fluid separation space112X, and, as a corollary, the reservoir fluid is directed to the reservoir fluid separation space112X, via the intermediate reservoir fluid conductor112, for facilitating separation of gaseous material from the reservoir fluid in response to at least buoyancy forces.

In some embodiments, for example, the downhole disposed conductor202, the flow diverter body602, the flow diverter body sealed interface800, the pump-seating body700, the pump302and the gas-depleted reservoir fluid producing conductor204are cooperatively configured such that, in operation, while the downhole disposed conductor202is receiving reservoir fluid from the downhole wellbore space110that has been received within the downhole wellbore space110from the subterranean formation100, the reservoir fluid is supplied to the uphole wellbore space108by the downhole disposed conductor202such that reservoir fluid is discharged from the discharge end203of the downhole disposed conductor202into the reservoir fluid receiving space6008. The reservoir fluid received within the reservoir fluid receiving space6008is then conducted downhole via the reservoir fluid conducting passage6010and delivered to the intermediate reservoir fluid conducting passage6002via the received reservoir fluid outlet611, where it is directed uphole to the reservoir fluid separation space112X. Bypassing of the reservoir fluid separation space112X by the reservoir fluid is prevented, or substantially prevented by the sealed interface500or sealed interface effector502, such that reservoir fluid is supplied to the reservoir fluid separation space112X by the intermediate reservoir fluid conductor6002. Within the reservoir fluid separation space112X, gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. The separated gas-depleted reservoir fluid is received by a gas depleted reservoir fluid receiver605of the flow diverter body602or shroud603(e.g. the open upper end604of the flow diverter body602or shroud603) and is conducted to the gas-depleted reservoir fluid receiving space6006via the gas-depleted reservoir fluid conducting passage6004. From the gas-depleted reservoir fluid receiving space6006, the separated gas-depleted reservoir fluid is conducted to the pump302via the pump-intake conducting passage704. Once received by the pump302, the gas-depleted reservoir fluid is pressurized by the pump302and is conducted uphole to the surface106as production flow via the gas-depleted reservoir fluid producing conductor204.

In parallel, the separation of gaseous material from the reservoir fluid within the reservoir fluid separation space112X is with effect that a liquid-depleted reservoir fluid is obtained and is conducted uphole (in the gaseous phase, or at least primarily in the gaseous phase with relatively small amounts of entrained liquid), via a liquid-depleted reservoir fluid conducting passage6012that is disposed between the assembly10and a corresponding portion of the wellbore string113generally uphole of the reservoir fluid separation space112X.

The reservoir fluid produced from the subterranean formation100, via the wellbore102, including the gas-depleted reservoir fluid, the liquid-depleted reservoir fluid, or both, may be discharged through the wellhead116to a collection facility, such as a storage tank.

In some embodiments, for example, the reservoir fluid separation space112X spans a continuous space extending from the assembly10to the wellbore string113, and the continuous space extends outwardly relative to the central longitudinal axis of the assembly10.

In some embodiments, for example, the reservoir fluid separation space112X spans a continuous space extending from the assembly10to the wellbore string113, and the continuous space extends outwardly relative to the central longitudinal axis of the wellbore102.

In some embodiments, for example, the reservoir fluid separation space112X is disposed within a vertical portion102A of the wellbore102that extends to the surface106.

In some embodiments, for example, the ratio of the minimum cross-sectional flow area of the reservoir fluid separation space112X to the maximum cross-sectional flow area of the fluid passage defined by the reservoir fluid-supplying conductor202is at least about 1.5.

In some embodiments, for example, the uphole wellbore space108includes a sump space550, and the sump space550is disposed: (i) downhole relative to the reservoir fluid separation space112X (such as, for example, downhole relative to the intermediate reservoir fluid conducting passage6002), and (ii) uphole relative to the sealed interface500. The sump space550is provided for collecting solid particulate material that gravity separates from the reservoir fluid that is supplied to the uphole wellbore space108by the downhole-disposed conductor202. In some embodiments, for example, the discharge end203of the downhole-disposed conductor202is disposed uphole relative to the sump space550and is cooperatively configured with the flow diverter body602such that the discharge end203is oriented for discharging the conducted reservoir fluid in a downhole direction towards the sump space550. In this respect, as reservoir fluid is discharged from the discharge end203into the reservoir fluid receiving space6008defined by the flow diverter body602, the reservoir fluid flows in the downhole direction in the reservoir fluid conducting passage towards the sump space550, and after having flowed in the downhole direction, the reservoir fluid reverses direction and flows in an uphole direction to the reservoir fluid separation space112X via the intermediate reservoir fluid conducting passage6002. During the flow reversal, as the reservoir fluid is discharged from the open lower end606of the flow diverter body (or reservoir fluid outlet), at least a fraction of solid particulate material, that is entrained within the reservoir fluid, that is discharged into the uphole wellbore space108from the downhole-disposed conductor202, becomes separated from the reservoir fluid and gravity settles within the sump space550.

The pump-seating body700includes a gas-depleted reservoir fluid inlet710disposed uphole of the flow diverter sealed interface800that is disposed in fluid communication with the gas-depleted reservoir fluid receiving space6006such that the gas-depleted reservoir fluid is communicated to the pump-intake conducting passage704from the gas-depleted reservoir fluid receiving space6006through the gas-depleted reservoir fluid inlet710.

In some embodiments, for example, in reference to the embodiment illustrated inFIG. 1, the gas-depleted reservoir fluid inlet710includes the open, distal end706of the pump-seating body700. In this respect, the pump-seating body700is disposed within the flow diverter body602or shroud603such that the distal end706, and therefore the gas-depleted reservoir fluid inlet710is disposed uphole of the flow diverter flow blocking member800in fluid communication or fluidly coupled to the gas-depleted reservoir fluid receiving space6006.

Referring now in particular toFIG. 2, there is shown another example embodiment of the present disclosure, wherein the pump-seating body700is disposed within the flow diverter body602such that the pump-seating body700extends through the flow diverter body sealed interface800such that the distal end706of the pump-seating body700is disposed downhole of the sealed interface800. In such embodiment, the flow diverter flow-blocking member800serves as the supporting member900, the flow diverter body602therefore being suspended from the pump-seating body700by the flow-blocking member800. Therefore, in some embodiments, the pump-seating body700and the sealed interface800are cooperatively configured such that a first sealed interface802is effected between the flow diverter body602or shroud603and the sealed interface800, and a second sealed interface804is effected between the pump-seating body700and the flow diverter sealed interface800, wherein the first sealed interface802and the second sealed interface804, together, fluidly isolate the reservoir fluid receiving space6008(or lower open interior space610of the flow diverter body602) from the gas-depleted reservoir fluid receiving space6006(or upper open interior space608of the flow diverter body602).

Therefore, in the example embodiment illustrated inFIG. 2, the gas-depleted reservoir fluid inlet710is disposed within, or extends through, the pump-seating body700uphole of the open, distal end706of the pump-seating body700. In some embodiments, the gas-depleted reservoir fluid inlet710includes an aperture or opening defined within the sidewall of the pump-intake conducting passage704of the pump-seating body700for effecting fluid communication between the gas-depleted reservoir fluid receiving space6006and the pump-intake conducing passage704.

A pump-seating body flow-blocking member or sealed interface810is disposed within the pump-seating body700such that a sealed interface is effected between the pump-seating body700and a corresponding portion of the pump-seating body flow-blocking member or sealed interface810, the gas-depleted reservoir fluid inlet710disposed within the pump-seating body700uphole of the pump-seating body sealed interface810.

A reservoir fluid outlet720is disposed within the pump-seating body700downhole relative to the placement of the pump-seating body flow-blocking member810such that the reservoir fluid outlet720is in fluid communication with the reservoir fluid receiving space6008such that reservoir fluid that is conducted uphole from the downhole wellbore space110, via the downhole disposed conductor202, is communicated to the reservoir fluid receiving space6008through the reservoir fluid outlet720.

In some embodiments, the pump-seating body700and the pump-seating body sealed interface810are cooperatively configured such that the gas-depleted reservoir fluid inlet710is disposed uphole of the pump-seating body sealed interface810while the reservoir fluid outlet720is disposed downhole of the pump-seating body sealed interface810, the reservoir fluid outlet720being fluidly isolated from the gas-depleted reservoir fluid inlet710by the pump-seating body sealed interface810.

As shown inFIG. 2, in some embodiments, for example, the discharge end203of the downhole disposed conductor202is configured for releasably coupling to the pump-seating body700. In some embodiments, for example, the discharge end203of the downhole disposed conductor202is configured for releasably coupling to a reservoir fluid receiver of the production assembly10such that reservoir fluid that is received within the downhole wellbore space110and that is conducted uphole by the downhole disposed conductor202is discharged from the downhole disposed conductor202directly into a reservoir fluid receiver from where it is conducted or delivered to the reservoir fluid receiving space6008. In some embodiments, for example, the discharge end203of the downhole disposed conductor202is configured for releasably coupling to the open distal end706of the pump-seating body700, such that the downhole disposed conductor202is fluidly coupled to the pump-seating body700. In some embodiments, the discharge end203includes an on/off tool for effecting the releasable coupling of the downhole disposed conductor202to the distal end706of the pump-seating body700with effect that fluid coupling of the downhole disposed conductor202to the reservoir fluid receiving space6006via the reservoir fluid outlet720of the pump-seating body700is effected. In some embodiments, the on/off tool includes lugs.

The releasable coupling of the downhole disposed conductor202to the pump seating body700is such that a reservoir fluid discharge opening612(or received reservoir fluid outlet611) is defined, for example, by the annular gap or space defined between the downhole disposed conductor202and/or the pump-seating body700and the open lower end606of the flow diverter body602or shroud603, serves to fluidly interconnect the reservoir fluid conducting passage6010and the intermediate reservoir fluid conducting passage6002, the reservoir fluid conducting passage6010extending between the reservoir fluid receiving space6008and the reservoir fluid discharge opening612.

Therefore, in some embodiments, for example, in operation, while the downhole disposed conductor202is releasably coupled to the reservoir fluid receiver706of the pump-seating body700and is receiving reservoir fluid received within the downhole wellbore space110from the subterranean formation100, as shown inFIG. 2, the reservoir fluid is discharged into the reservoir fluid receiving space6008, via the reservoir fluid outlet720, disposed within the pump-seating body700uphole of the releasable connection between the downhole disposed conductor and the pump-seating body700. From the reservoir fluid receiving space6008, the reservoir fluid is conducted downhole through the reservoir fluid conducting passage6010before exiting the flow diverter body602through the reservoir fluid outlet612. As the reservoir fluid exits or is discharged from the reservoir fluid outlet612or open lower end606of the flow diverter body602, solid particulate may separate out of the fluid flow, in response to at least gravity, and collect on the sealed interface500so as not to interfere with the production of the wellbore113. The reservoir fluid that is free from, or substantially free from, the unnecessary or unwanted particular matter travels upward or uphole to the reservoir fluid separation space112X via the intermediate reservoir fluid conducting passage6002. Within the reservoir fluid separation space, the gas-depleted reservoir fluid is separated from the reservoir fluid and is received within the gas-depleted reservoir fluid receiver, or open top end606of the flow diverter body602. From the gas-depleted reservoir fluid receiver, the gas-depleted reservoir fluid is conducted downhole via the gas-depleted reservoir fluid conducting passage6004to the gas-depleted reservoir fluid receiving space6006. From the gas-depleted reservoir fluid receiving space6006, the gas-depleted reservoir fluid is delivered to the pump-intake conducting passage704through the gas-depleted reservoir fluid inlet710where it is conducted uphole to the pump302where the fluid is pressurized and conducted to the surface106or wellhead116via the gas-depleted reservoir fluid producing conductor204.

In some embodiments, the pump-seating body700and the flow diverter body602are cooperatively configured such that the reservoir fluid receiver disposed at the distal end706of the pump-seating body700is disposed uphole of the open lower end606of the flow diverter body602such that the downhole disposed conductor202is releasably coupled to the pump-seating body700at a location uphole of the open lower end606of the flow diverter body602.

In some embodiments, the pump-seating body700and the flow diverter body602are cooperatively configured such that the reservoir fluid receiver disposed at the distal end706of the pump-seating body700is disposed downhole of the open lower end606of the flow diverter body602such that the downhole disposed conductor202is releasably coupled to the pump-seating body700at a location downhole of the open lower end606of the flow diverter body602.

As described above, in some embodiments, for example, the pump-seating receptacle702includes an on/off tool or lugs703, or any other suitable on/off mechanism known in the art, for releasably coupling the pump302or pump assembly to the pump-seating body700. In the embodiment shown inFIG. 2, by having the pump-seating body700effect both the releasable coupling of the pump302and the releasable coupling of the downhole disposed conductor202within the system8, the pump302may be connected and disconnected from within the pump-seating receptacle702of the pump-seating body700without having to disconnect from the downhole disposed conductor202from the overall assembly10which may help to alleviate and/or minimize stresses on the downhole disposed conductor202during coupling/de-coupling processes.

In the above description, for purposes of explanation, numerous details are set forth in order to provide a thorough understanding of the present disclosure. However, it will be apparent to one skilled in the art that these specific details are not required in order to practice the present disclosure. Although certain dimensions and materials are described for implementing the disclosed example embodiments, other suitable dimensions and/or materials may be used within the scope of this disclosure. All such modifications and variations, including all suitable current and future changes in technology, are believed to be within the sphere and scope of the present disclosure. All references mentioned are hereby incorporated by reference in their entirety. Therefore, as certain adaptations and modifications of the described embodiments can be made, the above discussed embodiments are considered to be illustrative and not restrictive.