DOWNHOLE SEPARATOR WITH MUD JOINT

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority from U.S. Provisional Patent Application Serial No. 63/697676, filed on Sep. 23, 2024, entitled “DOWNHOLE SEPARATOR WITH MUD JOINT”, the contents of which are incorporated herein in its entirety.

FIELD

The present disclosure relates to mitigating gas interference with downhole pump operation during hydrocarbon production.

BACKGROUND

Reservoir fluids often contain entrained gases and solids. In producing reservoir fluids containing a relatively substantial fraction of gaseous material, the presence of such gaseous material hinders production by contributing to sluggish flow, and interfering with pump operation. As well, the presence of solids interferes with pump operation, including contributing to erosion of mechanical components.

Separators are provided to help remedy or mitigate downhole pump gas interference during hydrocarbon production. However, separators often occupy relatively significant amounts of space within a wellbore, rendering efficient separation of gaseous and solid materials, that are entrained within the reservoir fluid, difficult. Some separators are complex structures and are associated with increased material and manufacturing costs.

SUMMARY

In one aspect, there is provided a reservoir fluid conducting assembly, for emplacement within a wellbore string passage of the wellbore string for conducting reservoir fluid obtained from a subterranean formation, comprising: a flow-diverting configuration, including a mud joint that includes a mud joint housing that defines a mud joint cavity including a mud joint flow passage configuration; and a solids-depleted reservoir fluid conducting configuration, including an upwardly-conducting flow conductor configuration; wherein: the reservoir fluid conducting assembly is configured for co-operation with the wellbore string such that, while flow of reservoir fluid flow to the reservoir fluid-receiving zone, of the wellbore string passage, from the subterranean formation, is being motivated, a reservoir fluid flow-derivative flow, derived from the reservoir fluid flow, is conducted upwardly to a gas separation zone, within the wellbore string passage, via a reservoir fluid conductor configuration, with effect that the reservoir fluid flow-derivative flow becomes emplaced within the gas separation zone, and, in response to the emplacement within the gas separation zone, the reservoir fluid flow-derivative flow is separated, in response to buoyancy forces, into at least a gas-depleted reservoir fluid and a gas-enriched reservoir fluid, with effect that the gas-depleted reservoir fluid is conducted downwardly, such that a flow of gas-depleted reservoir fluid derivative, derived from the downwardly-flowing gas-depleted reservoir fluid, becomes established within the flow-diverting configuration and is conducted through the flow passage configuration, with effect that solid material is depleted, via solid separation via at least gravity settling, from the gas-depleted reservoir fluid derivative flow: separated solid material is collected within a compartment configuration defined within the mud joint cavity; and a solids-depleted reservoir fluid flow is produced; the reservoir fluid conducting assembly and the solids-depleted reservoir fluid conducting configuration are co-operatively configured such that, while the solids-depleted reservoir fluid flow is being produced, the flow, of the solids-depleted reservoir fluid, changes direction, via flow diversion by the flow-diverting configuration, with effect that the flow of solids-depleted reservoir fluid is conducted by the upwardly-conducting flow conductor configuration in the upwardly direction; and the compartment configuration is defined by a co-operative configuration of at least the mud joint housing, the upwardly-conducting flow conductor configuration, and a partition configuration, wherein the partition configuration is mounted to the upwardly-conducting flow conductor configuration.

In another aspect, there is provided a reservoir fluid conducting assembly, for emplacement within a wellbore string passage of the wellbore string for conducting reservoir fluid obtained from a subterranean formation, comprising: a flow-diverting configuration including: a housing that includes a cavity-defining surface; a housing cavity defined by the cavity-defining surface; a flow passage configuration defined within the housing cavity; and a partition configuration disposed within the housing cavity; a solids-depleted reservoir fluid conducting configuration, including an upwardly-conducting flow conductor configuration; wherein: the reservoir fluid conducting assembly is configurable to define a mud joint in response to a displacement of the partition configuration towards the cavity-defining surface of the flow-diverting configuration housing, the displacement being motivated by the application of a gravitational force to the partition configuration and being with effect that a compartment configuration of the mud joint is established; the mud joint includes a mud joint housing, defined by the flow-diverting configuration housing, and a mud joint flow passage configuration, defined by the flow-diverting configuration flow passage configuration; the compartment configuration is established by a co-operative configuration of at least the mud joint housing and the partition configuration; and the reservoir fluid conducting assembly is configured for co-operation with the wellbore string such that, while flow of reservoir fluid flow to the reservoir fluid-receiving zone, of the wellbore string passage, from the subterranean formation, is being motivated, a reservoir fluid flow-derivative flow, derived from the reservoir fluid flow, is conducted upwardly to a gas separation zone, within the wellbore string passage, via a reservoir fluid conductor configuration, with effect that the reservoir fluid flow-derivative flow becomes emplaced within the gas separation zone, and, in response to the emplacement within the gas separation zone, the reservoir fluid flow-derivative flow is separated, in response to buoyancy forces, into at least a gas-depleted reservoir fluid and a gas-enriched reservoir fluid, with effect that the gas-depleted reservoir fluid is conducted downwardly, such that a flow of gas-depleted reservoir fluid derivative, derived from the downwardly-flowing gas-depleted reservoir fluid, becomes established within the flow-diverting configuration and is conducted through the mud joint flow passage configuration, with effect that solid material is depleted, via solid separation via at least gravity settling, from the gas-depleted reservoir fluid derivative flow: separated solid material is collected within the compartment configuration; and a solids-depleted reservoir fluid flow is produced; and the reservoir fluid conducting assembly and the solids-depleted reservoir fluid conducting configuration are co-operatively configured such that, while the solids-depleted reservoir fluid flow is being produced, the flow, of the solids-depleted reservoir fluid, changes direction, via flow diversion by the flow-diverting configuration, with effect that the flow of solids-depleted reservoir fluid is conducted by the upwardly-conducting flow conductor configuration in the upwardly direction.

In another aspect, there is provided a reservoir fluid conducting assembly, for emplacement within a wellbore string passage of the wellbore string for conducting reservoir fluid obtained from a subterranean formation, comprising: a flow-diverting configuration including: a housing that includes a cavity-defining surface; a housing cavity defined by the cavity-defining surface; a flow passage configuration defined within the housing cavity; and a partition configuration disposed within the housing cavity; a solids-depleted reservoir fluid conducting configuration, including an upwardly-conducting flow conductor configuration; wherein: the reservoir fluid conducting assembly is co-operable with the wellbore string such that, in response to an emplacement of the reservoir fluid conducting assembly within the wellbore string passage that is with effect that the partition configuration becomes emplaced within a wellbore string passage portion characterized by a longitudinal axis that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees, a mud joint, including a compartment configuration, becomes established; the mud joint includes: a mud joint housing defined by the flow-diverting configuration housing; and a mud joint flow passage configuration defined by the flow-diverting configuration flow passage configuration; the compartment configuration is established by a co-operative configuration of at least the mud joint housing and the partition configuration; and the reservoir fluid conducting assembly is configured for co-operation with the wellbore string such that, while flow of reservoir fluid flow to the reservoir fluid-receiving zone, of the wellbore string passage, from the subterranean formation, is being motivated, a reservoir fluid flow-derivative flow, derived from the reservoir fluid flow, is conducted upwardly to a gas separation zone, within the wellbore string passage, via a reservoir fluid conductor configuration, with effect that the reservoir fluid flow-derivative flow becomes emplaced within the gas separation zone, and, in response to the emplacement within the gas separation zone, the reservoir fluid flow-derivative flow is separated, in response to buoyancy forces, into at least a gas-depleted reservoir fluid and a gas-enriched reservoir fluid, with effect that the gas-depleted reservoir fluid is conducted downwardly, such that a flow of gas-depleted reservoir fluid derivative, derived from the downwardly-flowing gas-depleted reservoir fluid, becomes established within the flow-diverting configuration and is conducted through the mud joint flow passage configuration, with effect that solid material is depleted, via solid separation via at least gravity settling, from the gas-depleted reservoir fluid derivative flow: separated solid material is collected within the compartment configuration; and a solids-depleted reservoir fluid flow is produced; and the reservoir fluid conducting assembly and the solids-depleted reservoir fluid conducting configuration are co-operatively configured such that, while the solids-depleted reservoir fluid flow is being produced, the flow, of the solids-depleted reservoir fluid, changes direction, via flow diversion by the flow-diverting configuration, with effect that the flow of solids-depleted reservoir fluid is conducted by the upwardly-conducting flow conductor configuration in the upwardly direction.

I another aspect, there is provided a downhole tool for emplacement within a wellbore string passage of a wellbore string for depleting solid material from a solid-rich reservoir fluid obtained from a subterranean formation, comprising: a housing that includes a cavity-defining surface; a housing cavity defined by the cavity-defining surface; a flow passage configuration defined within the housing cavity; and a partition configuration disposed within the housing cavity; wherein: the downhole tool is configurable to define a solid separator in response to a displacement of the partition configuration towards the cavity-defining surface of the downhole tool housing, the displacement being motivated by the application of a gravitational force to the partition configuration and being with effect that a compartment configuration of the solid separator is established; the solid separator includes: a solid separator housing defined by the downhole tool housing; and a solid separator flow passage configuration defined by the downhole tool flow passage configuration; the compartment configuration is established by a co-operative configuration between at least the solid separator housing and the partition configuration; and the solid separator is configured for co-operation with the wellbore string such that, while flow of the solid-rich reservoir fluid is being conducted through the solid separator flow passage configuration, with effect that solid material is depleted, via at least gravity settling, from the solid-rich reservoir fluid flow: separated solid material is collected within the compartment configuration; and a solids-depleted reservoir fluid flow is produced.

In another aspect, there is provided a downhole tool for emplacement within a wellbore string passage of the wellbore string for depleting solid material from a solid-rich reservoir fluid obtained from a subterranean formation, comprising: a housing that includes a cavity-defining surface; a housing cavity defined by the cavity-defining surface; a flow passage configuration defined within the housing cavity; and a partition configuration disposed within the housing cavity; wherein: the downhole tool, configurable in co-operation with the wellbore string such that, in response to an emplacement of the downhole tool within the wellbore string passage that is with effect that the partition configuration becomes emplaced within a wellbore string passage portion characterized by a longitudinal axis that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees, a solid separator becomes established; the solid separator includes: a solid separator housing defined by the flow-diverting configuration housing; a solid separator flow passage configuration defined by the downhole tool flow passage configuration; and a compartment configuration established by a co-operative configuration of at least the solid separator housing and the partition configuration; and the solid separator is configured for co-operation with the wellbore string such that, while solid-rich reservoir fluid flow is conducted through the solid separator flow passage configuration, with effect that solid material is depleted, via at least gravity settling, from the solid-rich reservoir fluid flow: separated solid material is collected within the compartment configuration; and a solids-depleted reservoir fluid flow is produced.

In another aspect, there is provided a downhole tool that is configurable to define a solid separator in response to displacement of a partition configuration, towards a bottom portion of a housing of the downhole tool, that is motivated by gravitational forces while the downhole tool is emplaced within a wellbore string passage of a wellbore string.

BRIEF DESCRIPTION OF THE DRAWINGS

Reference will now be made, by way of example, to the accompanying drawings which show example embodiments of the present application, and in which:

FIG. 1 is a schematic illustration of an embodiment of a system for separating gases and solids from a reservoir fluid;

FIG. 2 is identical to FIG. 1, and further identifies supporting of the flow-diverting configuration effectuated by the pump suction via a structural support configuration;

FIG. 3 is a detailed view of an embodiment of the flow diverting configuration of the system illustrated in FIG. 1, and identifies features of the flow diverting configuration;

FIG. 4 is a detailed view of another embodiment of the flow diverting configuration for use in the system illustrated in FIG. 1;

FIG. 5 is identical to FIG. 3, and further identifies features of the embodiment of the flow diverting configuration illustrated in FIG. 3, including features of the partition configuration;

FIG. 6 is identical to FIG. 3, and further identifies features of the embodiment of the flow diverting configuration illustrated in FIG. 2, including features of the compartment configuration;

FIG. 7 is identical to FIG. 3, and illustrates the flow direction of fluids through the flow diverting configuration during implementation of a process via an embodiment of the system;

FIG. 8 is a schematic illustration of an embodiment of a flow diverting configuration of a reservoir fluid conducting assembly for deployment within a wellbore, illustrating the flow diverting configuration in an orientation wherein gravitational forces are ineffective for establishing the mud joint; and

FIG. 9 is a schematic illustration of another embodiment of a flow diverting configuration.

Similar reference numerals may have been used in different figures to denote similar components.

DESCRIPTION OF EXAMPLE EMBODIMENTS

Referring to FIGS. 1 to 9, there are provided apparatuses, methods, and systems for producing hydrocarbon material from an oil reservoir within a subterranean formation 100.

A wellbore 102 of a subterranean formation 100 can be straight, curved or branched. The wellbore can have various wellbore sections. A wellbore section is an axial length of a wellbore 102. 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 passage of a horizontal section is disposed along an axis that is between about 70 and about 110 degrees relative to the vertical, while the central longitudinal axis of the passage of a vertical section is disposed along an axis that is less than about 20 degrees from the vertical “V”, and a transition section is disposed between the horizontal and vertical sections.

“Reservoir fluid” is fluid that is contained within an oil reservoir. Reservoir fluid includes a mixture of liquid material and gaseous material, and also includes, optionally, entrained solid particulate material. The reservoir fluid includes hydrocarbon material, such as oil, natural gas condensates, or any combination thereof. The reservoir fluid can also contain water. The reservoir fluid can also include fluids injected into the reservoir for effecting stimulation of resident fluids within the reservoir.

The term “fluid conductor configuration” refers to a configuration which conducts fluid. The configuration can be: (a) a single conductor (e.g. conduit), (b) a plurality of parallel conductors, (c) a network of interconnected conductors, or any combination of (a), (b), and (c).

A wellbore string 108 is emplaced within the wellbore 102 such that the wellbore string 108 is lining the wellbore 102 through which reservoir fluid is producible from a hydrocarbon reservoir within the subterranean formation 100. In some embodiments, for example, the wellbore string 108 is configured for stabilizing the subterranean formation 100. In some embodiments, for example, the wellbore string 108 also contributes to effecting fluidic isolation of one zone within the subterranean formation 100 from another zone within the subterranean formation 100. In some embodiments, for example, the wellbore string 108 is a casing string.

The fluid productive portion of the wellbore 102 may be completed either as a cased-hole completion or an open-hole completion.

With respect to a cased-hole completion, in some embodiments, for example, a wellbore string 108, in the form of a wellbore casing that includes one or more casing strings, each of which is positioned within the wellbore 102, having one end extending from the wellhead 106, is provided. 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 102 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 surface 104. 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 the 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 the wellhead 106.

The wellbore 102 is 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 emplaceable into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the subterranean formation 100. When disposed in flow communication with the subterranean formation 100, the wellbore 102 is disposed for receiving reservoir fluid flow from the subterranean formation 100, with effect that the system 10 receives 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 wellhead 106. 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 some embodiments, for example, the production tubing string may be engaged or stung into the liner string, thereby providing a flow passage for conducting the produced reservoir fluid to the wellhead 106.

An open-hole completion is established by drilling down to the producing formation, and then lining the wellbore (such as, for example, with a wellbore string 108). 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.

The system 10 receives, via the wellbore 102, the reservoir fluid flow from the subterranean formation 100. As discussed above, the wellbore 102 is 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 manipulated into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the subterranean formation 100. When disposed in flow communication with the subterranean formation 100, the wellbore 102 is disposed for receiving reservoir fluid flow from the subterranean formation 100, with effect that the system 10 receives the reservoir fluid.

In some embodiments, for example, the system 10 includes a production string, including a reservoir fluid conducting assembly 200, emplaced within a wellbore string passage 110 of the wellbore string 108. While emplaced within the wellbore string passage 110, the reservoir fluid conducting assembly 200 is suspended from a wellhead 106. The reservoir fluid conducting assembly 200 includes a flow-diverting configuration 300 and a solids-depleted reservoir fluid conducting configuration 400.

Referring to FIGS. 1 and 2, in some embodiments, for example, the flow-diverting configuration 300 includes a flow diverter 3001 that includes a base 314 (defining a closed lower end) and a continuous sidewall 315, extending upwardly from the base 314, such that a housing 302, of the flow diverter 3001, is defined. In some embodiments, for example, a cavity 301 is defined within the housing 302 by a cavity-defining surface 3021 of the housing 302.

The solids-depleted reservoir fluid-transporting configuration 400 includes an upwardly-conducting flow conductor configuration 401. In some embodiments, for example, the solids-depleted reservoir fluid-transporting configuration 400 further includes a pump 402 and a pressurized gas-depleted reservoir fluid conductor configuration 403. In some of these embodiments, for example, while the reservoir fluid conducting assembly 200 is emplaced within the wellbore string passage 110, the pressurized gas-depleted reservoir fluid conductor configuration 403 is connected to the discharge 402B of the pump 402, with effect that the pressurized gas-depleted reservoir fluid conductor configuration is fluidly coupled to the pump 402. In some of these embodiments, for example, while the reservoir fluid conducting assembly 200 is emplaced within the wellbore string passage 110, the upwardly-conducting flow conductor configuration 401 is connected to the suction 402A of the pump 402, with effect that the upwardly-conducting flow conductor configuration 401 is fluidly coupled to the pump. In this respect, in some embodiments, for example, the upwardly-conducting flow conductor configuration 401 includes, and, in some embodiments, for example, defines, a pump intake.

In some embodiments, for example, the pump 402 is a rod pump 402. The rod pump 402 includes a conveyor, such as a rod or a rod string, extending through the pressurized gas-depleted reservoir fluid conductor 403, and connected to surface equipment which causes reciprocating movement of the conveyor. In some embodiments, for example, the surface equipment includes a prime mover (e.g. an internal combustion engine or a motor), a crank arm, and a beam. The prime mover rotates the crank arm, and the rotational movement of the crank arm is converted to reciprocal longitudinal movement through the beam. In some embodiments, for example, the prime mover is a pumpjack. The beam is attached to a polished rod by cables hung from a horsehead at the end of the beam. The polished rod passes through a stuffing box and is attached to the conveyor. Accordingly, the surface equipment effects reciprocating longitudinal movement of the conveyor, and further defines the upper and lower displacement limits of the conveyor. Reservoir fluid is produced to the surface in response to reciprocating longitudinal movement of the rod by the pumpjack.

In some embodiments, for example, the flow-diverting configuration 300 is supported by the pump suction 402A. In this respect, while the reservoir fluid conducting assembly 200 is emplaced within the wellbore string passage 110, the supporting of the flow-diverting configuration 300 is effectuated by the pump suction 402A via a structural support configuration 802. In some embodiments, for example, the flow-diverting configuration 300 is hung from the pump suction 402A via the structural support configuration 802. In some embodiments, for example, the structural support configuration 802 includes a support member having a first end connected to the pump suction 402A and a second opposite end connected to the housing 302 of the apparatus 3001. In some of these embodiments, for example, the structural support configuration 802 is braced to the solids-depleted reservoir fluid-transporting configuration 400 via gusset braces 804.

A reservoir fluid-receiving zone 120 is disposed within the wellbore string passage 110 for receiving reservoir fluid flow 702 that is conducted from the subterranean formation 100 and into the wellbore 102. In this respect, reservoir fluid flow 702, from the subterranean formation 100, is received by the reservoir fluid-receiving zone 120 by virtue of flow communication between the subterranean formation 100 and the wellbore string passage 110. In some embodiments, for example, the flow communication is effectuated by actuating a valve (e.g. sliding sleeve). In some embodiments, for example, the flow communication is effectuated by a “plug and perf” operation.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is configured for co-operation with the wellbore string 108 while the reservoir fluid conducting assembly 200 is emplaced within the wellbore string passage 110 of the wellbore string 108. In some of these embodiments, for example, the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, includes emplacement within a wellbore string passage portion 110A characterized by a longitudinal axis 110AX that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees.

In this respect, in some embodiments, for example, the reservoir fluid conducting assembly 200 is configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200 is established within the wellbore string passage 110 of the wellbore string 108, an upwardly-conducting reservoir fluid conductor configuration 303 is established for conducting the reservoir fluid flow-derivative 704, derived from the reservoir fluid flow 702, from the receiving zone 120 to a gas separation zone 305, within the wellbore string passage 110. In some embodiments, for example, the reservoir fluid conductor configuration 303 is defined by a space 303A defined between the flow diverter 3001 (such as, for example, the continuous sidewall 315 of the flow diverter 3001) and the wellbore string 108. In some embodiments, for example, the space 303A is an annular space.

Also in this respect, in some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200 is established within the wellbore string passage 110 of the wellbore string 108, and while flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to a gas separation zone 305, within the wellbore string passage 110, with effect that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305. In some embodiments, for example, the reservoir fluid flow-derivative flow 704 is the reservoir fluid flow 702. In response to emplacement within the gas separation zone 305, the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least a gas-depleted reservoir fluid 708A and a gas-enriched reservoir fluid 706, with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, and with effect that the gas-enriched reservoir fluid 706 is conducted, within the wellbore string passage 110 of the wellbore string 108, in an upwardly direction.

The gas separation zone 305 has a sufficiently large cross-sectional flow area, relative to that of the upwardly-conducting reservoir fluid conductor configuration 303 through which the reservoir fluid-derived flow is conducted from the receiving zone 120, with effect that the flowrate of the reservoir fluid flow-derivative flow 704 is sufficiently reduced so as to promote the separation. In some embodiments, for example, the gas separation zone 305 is disposed within the vertical section of the wellbore 102.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established, and while flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300. In this respect, the flow-diverting configuration 300 is disposed in flow communication with the gas separation zone 305. In some embodiments, for example, the flow-diverting configuration 300 is disposed below the gas separation zone 305. In some embodiments, for example, the gas-depleted reservoir fluid derivative flow 708B is the produced downwardly-flowing gas-depleted reservoir fluid 708A. While the gas-depleted reservoir fluid derivative flow 708B is being conducted through the flow-diverting configuration 300, the gas-depleted reservoir fluid derivative flow 708B becomes depleted in solid material, via at least gravity settling, within the flow-diverting configuration 300, such that a flow of the solids-depleted reservoir fluid 708C is produced.

In some embodiments, for example, the apparatus 3001 further includes a flow-receiving communicator 3081. In this respect, in some embodiments, for example, the flow communication between the gas separation zone 305 and the cavity 301 of the apparatus is established via the flow-receiving communicator 3081. In some embodiments, for example, the flow-receiving communicator 3081 co-operates with the gas separation zone 305 such that, while the separation is being effectuated within the gas separation zone 305 such that the downwardly-flowing gas-depleted reservoir fluid 708A is produced, the gas-depleted reservoir fluid derivative flow 708B is received by the flow-receiving communicator 3081 such that the flow of gas-depleted reservoir fluid derivative 708B becomes established within the flow-diverting configuration 300.

In some embodiments, for example, the flow-diverting configuration 300 defines a flow passage configuration 3002. In some embodiments, for example, the flow passage configuration 3002 is defined within the cavity 301 of the housing 302 of the apparatus 3001, and is separated from the reservoir fluid conductor configuration 303, by the housing 302 (such as, for example, by the continuous sidewall 315 of the housing 302). In this respect, in some embodiments, for example, flow communication is established, between the flow passage configuration 3002 and the gas separation zone 305, via the flow-receiving communicator 3081. The flow passage configuration 3002 effects flow communication between the flow-receiving communicator 3081 and the upwardly-conducting flow conductor configuration 401.

Referring to FIGS. 3 to 7, in some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200 is established within the wellbore string passage 110 of the wellbore string 108, the flow-diverting configuration 300 further defines a mud joint 600. In some embodiments, for example, the mud joint 600 includes a housing 602. In some embodiments, for example, the mud joint housing 602 is part of, and defined by, the housing 302. The mud joint housing 602 defines a mud joint cavity 601, which, in some embodiments, for example, is part of, and defined by, the cavity 301. In some embodiments, for example, the mud joint cavity 601 is defined by a cavity-defining surface 6021 of the housing 602. In some embodiments, for example, the mud joint 600 includes a mud joint flow passage configuration 6011 that is defined within the mud joint cavity 601. In this respect, the flow of gas-depleted reservoir fluid derivative 708B, being conducted through the flow passage configuration 3002, is conducted through the mud joint flow passage configuration 6011. While being conducted through the mud joint flow passage configuration 6011, the flow of gas-depleted reservoir fluid derivative 708B becomes depleted in solid material by separation of solid material from the gas-depleted reservoir fluid derivative flow 708B via at least gravity settling within the mud joint 600, with effect that the flow of the solids-depleted reservoir fluid 708C is produced.

In this respect, the co-operation between the reservoir fluid conducting assembly 200 and the wellbore string 108 is effective for separating, from the reservoir fluid flow-derivative flow 704, the gas-depleted reservoir fluid flow 708A and the gas-enriched reservoir fluid flow 706, via at least buoyancy forces, and is also effective for effectuating depletion of solid material, from the gas-depleted reservoir fluid derivative flow 708B, by separation of solid material from the gas-depleted reservoir fluid derivative flow 708B via at least gravity settling within the mud joint 600.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established, and while flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300, there is an absence of bypassing of the mud joint flow passage configuration 6011 by the gas-depleted reservoir fluid derivative 708B.

Referring to FIG. 5, a compartment configuration 608, defined by a plurality of compartments 616, is defined within the mud joint cavity 601 of the established mud joint 600. In this respect, the compartment configuration 608 is disposed in flow communication with the gas separation zone 305. In some embodiments, for example, the plurality of compartments 616 are co-operatively configured to define a series of compartments 616, with effect that at least one pair of adjacent compartments 616 (and, in some embodiments, for example, a plurality of pairs of adjacent compartments 616) is established. In some of these embodiments, for example, the series of compartments 616 are spaced apart from one another along a longitudinal axis.

In some embodiments, for example, for each one of the at least one pair of adjacent compartments 616, of the compartment configuration 608, independently, flow communication between the pair of adjacent compartments 616 is established via an inter-compartment communicator 618, that is respective to the pair of adjacent compartments 616, such that at least one inter-compartment communicator 618 is defined by the compartment configuration 608, and such that the at least one inter-compartment communicator 618 defines an inter-compartment communicator configuration 6181 of the compartment configuration 608, and such that the flow communication, established across the compartment configuration 608, via the mud joint flow passage configuration 6011, includes the flow communication established across the compartment configuration 608 via the inter-compartment communicator configuration 6181. In this respect, in some embodiments, for example, the flow of gas-depleted reservoir fluid derivative 708B, being conducted through the mud joint flow passage configuration 6011, is conducted through the inter-compartment communicator configuration 6181.

In some embodiments, for example, each one of the at least one inter-compartment communicator 618, independently, defines a respective minimum total cross-sectional flow area, and, for each one of the at least one inter-compartment communicator 618, independently, the ratio of the minimum total cross-sectional flow area, that is respective to the inter-compartment communicator 618, to the minimum total cross-sectional flow area of the upwardly-conducting flow conductor configuration 401, is at least 0.5625, such as, for example, at least 0.6, such as, for example, at least 0.65, such as, for example, at least 0.7, such as, for example, at least 0.75, such as, for example, at least 0.8, such as, for example, at least 0.85, such as, for example, at least 0.9.

In some embodiments, for example, each one of the at least one inter-compartment communicator 618, independently, defines an upper flow communication passage configuration (defined by one or more passages) that is defined by an upper portion 601U of the mud joint cavity 601.

The upper portion 601U, of the mud joint cavity 601, is disposed within the upper ¾ of the total vertical extent of the mud joint cavity 601, only (such as, for example, within the upper ½ of the total vertical extent of the mud joint cavity 601, only, such as, for example, within the upper ¼ of the total vertical extent of the mud joint cavity 601, only). In some embodiments, for example, the upper ¾, of the total vertical extent of the mud joint cavity 601, defines the upper portion 601U of the mud joint cavity 601. In some embodiments, for example, the upper ½, of the total vertical extent of the mud joint cavity 601, defines the upper portion 601U of the mud joint cavity 601. In some embodiments, for example, the upper ¼, of the total vertical extent of the mud joint cavity 601, defines the upper portion 601U of the mud joint cavity 601.

In some embodiments, for example, the depletion of solid material, from the gas-depleted reservoir fluid derivative 708B, by separation of solid material from the gas-depleted reservoir fluid derivative flow 708B via at least gravity settling within the mud joint 600, is with effect that separated solid material is collected within the compartment configuration 608. In this respect, in some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, and while flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the separation is being effectuated within the gas separation zone 305, the gas-depleted reservoir fluid derivative flow 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes depleted in solid material, by separation of solid material from the gas-depleted reservoir fluid derivative flow 708B via at least gravity settling within the mud joint 600, with effect that separated solid material is collected within the compartment configuration 608 and with effect that the flow of solid material-depleted reservoir fluid 708C is produced and conducted to the upwardly-conducting flow conductor configuration 401.

Referring to FIG. 6, in some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, and while flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300, and the gas-depleted reservoir fluid derivative 708B is being depleted in solid material by solid separation via at least gravity settling within the mud joint 600, the separation of solid material, via at least gravity settling, is effectuated progressively, as the gas-depleted reservoir fluid derivative 708B flows through the mud joint flow passage configuration 6011 and across the compartment configuration 608, such that, for each one of the compartments 616, independently, a separated solid material “SM” is obtained and collected (and, in some embodiments, for example, contained) within the compartment 616. In this respect, sufficient residence time, for the solid material separation, via at least gravity settling, from the gas-depleted reservoir fluid derivative 708B being conducted through the mud joint flow passage configuration 6011, is established within the mud joint flow passage configuration, such that, for each one of the compartments 616, independently, while the gas-depleted reservoir fluid derivative 708B is being conducted through the mud joint flow passage configuration 6011, solid material, separated from the gas-depleted reservoir fluid derivative 708B, being conducted through the mud joint flow passage configuration 6011, via at least gravity settling, a separated solid material “SM” is obtained and collected (and, in some embodiments, for example, contained) as separated solid material “SM” within the compartment 616. As a necessary incident, for each one of the at least one pair of adjacent compartments 616, of the compartment configuration 608, independently, the gas-depleted reservoir fluid derivative 708B, that has become depleted in solid material that has separated via at least gravity settling within an uphole of the pair of adjacent compartments, and is characterized by a respective solid concentration “C1”, flows into a downhole one of the pair of adjacent compartments, such that the gas-depleted reservoir fluid derivative 708B is traversing (e.g. flowing through) the downhole one of the pair of adjacent compartments, and while traversing (e.g. flowing through) the downhole one of the pair of adjacent compartments 616, further solid material becomes becomes separated from the gas-depleted reservoir fluid derivative 708B via at least gravity settling within the downhole one of the pair of adjacent compartments, with effect that the gas-depleted reservoir fluid 708B becomes further depleted in solid material and is characterized by a respective solid concentration “C2”, which is lower than the solid concentration “C1”. In this respect, the solid concentration of the gas-depleted reservoir fluid 708B becomes progressively reduced with each succeeding compartment 616.

The upwardly-conducting flow conductor configuration 401 (in some embodiments, for example, defined by a single conduit only) is configured for conducting the solids-depleted reservoir fluid 708C in an upwardly direction (such as, for example, to the pump 402).

In this respect, the flow-diverting configuration 300 and the solids-depleted reservoir fluid-transporting configuration 400 are co-operatively configured, such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, and while the flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 3001, and becomes depleted in solid material by solid separation via at least gravity settling, while being conducted through the mud joint flow passage configuration 6011, such that the solids-depleted reservoir fluid flow 708C is produced by the flow-diverting configuration 300: the flow of the solids-depleted reservoir fluid 708C changes direction, via flow diversion, with effect that the flow of solids-depleted reservoir fluid 708C is conducted by the upwardly-conducting flow conductor configuration 401 in the upwardly direction (for example, towards the pump 402).

In some embodiments, for example, the flow-diverting configuration 300 and the solids-depleted reservoir fluid-transporting configuration 400 are co-operatively configured, such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, and while the flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300, and becomes depleted in solid material by solid separation via at least gravity settling, while being conducted through the mud joint flow passage configuration 6011, such that the solids-depleted reservoir fluid flow 708C is produced by the flow-diverting configuration 300: there is an absence of bypassing of the upwardly-conducting flow conductor configuration 401 by the solids-depleted reservoir fluid 708C.

In some embodiments, for example, the flow-diverting configuration 300 and the solids-depleted reservoir fluid-transporting configuration 400 are co-operatively configured, such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, and such that the upwardly-conducting flow conductor configuration 401 is fluidly coupled to the pump 402 for supplying the pump 402 with the solids-depleted reservoir fluid 708C, and while the flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300, and becomes depleted in solid material by solid separation via at least gravity settling, while being conducted through the mud joint flow passage configuration 6011, such that the solids-depleted reservoir fluid flow 708C is produced by the flow-diverting configuration 300: there is an absence of bypassing of the pump 402 by the solids-depleted reservoir fluid 708C.

In some embodiments, for example, the upwardly-conducting flow conductor configuration 401 includes a flow-receiving communicator 4011 (defined by one or more ports), which functions as an inlet for the upwardly-conducting flow conductor configuration 401, for receiving the solids-depleted reservoir fluid 708C produced by the compartment configuration 608.

In some embodiments, for example, the flow-diverting configuration 300 and the solids-depleted reservoir fluid-transporting configuration 400 are co-operatively configured, such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, the flow-receiving communicator 4011 is disposed within a “gas and solids”-depleted reservoir fluid accumulating compartment 6162 of the compartment configuration 608, such that the “gas and solids”-depleted reservoir fluid accumulating compartment 6162 is a furthest downhole one of the plurality of compartments 616.

Referring to FIGS. 6 and 7, in one aspect, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the mud joint 600 is established, the compartment configuration 608 is established by a co-operative configuration of at least the mud joint housing 602, the upwardly-conducting flow conductor configuration 401, and a partition configuration 604, defined by at least one partition 606. In some embodiments, for example, the at least one partition 606 is a plurality of partitions 606, and the plurality of partitions 606 are co-operatively configured to define a series of partitions 606. In some embodiments, for example, the partition configuration 604 is mounted to the upwardly-conducting flow conductor configuration 401. In some embodiments, for example, the mounting is such that a partition configuration-mounted flow conductor configuration 900 is established, and the partition configuration-mounted flow conductor 900 includes a series of partitions 606 that are mounted to the upwardly-conducting flow conductor configuration 401.

In some embodiments, for example, for each one of the at least one partition 606, independently, the uphole-facing surface has a normal axis that is disposed, relative to the central longitudinal axis of the mud joint flow passage configuration 6011, at an acute angle of less than 30 degrees. In some embodiments, for example, for each one of the at least one partition 606, independently, the uphole-facing surface has a normal axis that is parallel to the central longitudinal axis of the mud joint flow passage configuration 6011.

In some embodiments, for example, the flow-diverting configuration 300 and the solids-depleted reservoir fluid-transporting configuration 400 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established, such that the compartment configuration 608 is established by a co-operative configuration of at least the mud joint housing 602 and the partition configuration 604, for each one of the at least one pair of adjacent compartments 616, independently, an uphole one of the pair of adjacent compartments 616 is separated from a downhole one of the pair of adjacent compartments 616 by a respective partition 606 of the partition configuration 604.

Referring to FIG. 7, in some embodiments, for example, for each one of the at least one partition 606 of the partition configuration 604, independently, the partition configuration 604 and the mud joint housing 602 are co-operatively configured such that a compartment space 616CS, of a compartment cavity 616C of the uphole one of a pair of adjacent compartments 616, is separated, by the partition 606, from a compartment space 616CS of a compartment cavity 616C of the downhole one of the pair of adjacent compartments 616.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established, such that the compartment configuration 608 is established by a co-operative configuration of at least the mud joint housing 602 and the partition configuration 604, the co-operation, between at least the mud joint housing 602 and the partition configuration 604, is with effect that, for each one of the at least one pair of adjacent compartments 616, independently, contact engagement (e.g. sealing engagement) of the partition 606, that is respective to the pair of adjacent compartments 616, with a bottom portion 6021B of the cavity-defining surface 6021 of the mud joint housing 602, is defined.

In some embodiments, for example, each one of the series of partitions 606, independently, defines a weir, such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established such that the compartment configuration 608 is established, and such that the upwardly-conducting flow conductor configuration 401 is fluidly coupled to the pump 402 for supplying the pump 402 with the solids-depleted reservoir fluid 708C, and while the flow of reservoir fluid flow 702 to the reservoir fluid-receiving zone 120, of the wellbore string passage 110, from the subterranean formation 100, is being motivated (e.g. by the pump 402), with effect that the reservoir fluid flow-derivative flow 704, derived from the reservoir fluid flow 702, is conducted upwardly, via the space 303A, to the gas separation zone 305, such that the reservoir fluid flow-derivative flow 704 becomes emplaced within the gas separation zone 305, with effect that the reservoir fluid flow-derivative flow 704 is separated, by buoyancy forces, into at least the gas-depleted reservoir fluid 708A and the gas-enriched reservoir fluid 706, and with effect that the gas-depleted reservoir fluid 708A is conducted, within the wellbore string passage 110 of the wellbore string 108, in a downwardly direction, such that the flow of gas-depleted reservoir fluid derivative 708B, derived from the downwardly-flowing gas-depleted reservoir fluid 708A, becomes established within the flow-diverting configuration 300, and the gas-depleted reservoir fluid derivative 708B is being progressively depleted in solid material by solid separation via at least gravity settling within the mud joint 600, as the gas-depleted reservoir fluid derivative 708B flows through the mud joint flow passage configuration 6011 and across the compartment configuration 608, such that, for each one of the compartments 616, independently, a separated solid material “SM” is obtained and collected (and, in some embodiments, for example, contained) within the compartment 616, and for each one of the at least one pair of adjacent compartments 616, independently, the gas-depleted reservoir fluid derivative 708B, that has become depleted in solid material that has separated via at least gravity settling within an uphole of the pair of adjacent compartments, flows over the weir, that separates the uphole one of the pair of adjacent compartments 616 from a downhole one of the pair of adjacent compartments 616, and into a downhole one of the pair of adjacent compartments, such that the gas-depleted reservoir fluid derivative 708B is traversing (e.g. flowing through) the downhole one of the pair of adjacent compartments, and while traversing (e.g. flowing through) the downhole one of the pair of adjacent compartments 616, further solid material becomes becomes separated from the gas-depleted reservoir fluid derivative 708B via at least gravity settling within the downhole one of the pair of adjacent compartments, with effect that the gas-depleted reservoir fluid 708B becomes further depleted in solid material, and with effect that the separated solid material is obtained and collected (and, in some embodiments, for example, contained) within the downhole one of the pair of adjacent compartments 616. In some embodiments, for example, establishing a mud joint 600, with a partition configuration 600 including a series of weirs, assists with breaking up solid material slugs within the gas-depleted reservoir fluid 708B, thereby increasing efficiency of solid separation and militating against solids bridging/plugging. Also, with respect to the breaking up of the solid material slugs, to the extent that some solid material remains in the solids-depleted reservoir fluid 708C, the remaining solid material is of a form that is less likely to be difficult to travel through the pump.

In another aspect, the reservoir fluid conducting assembly 200 is configurable to define the mud joint 600, within the flow diverting configuration 300, in response to a displacement of the partition configuration 604 towards the cavity-defining surface 3021 of the housing 302 (e.g. the cavity-defining surface 3021 of the bottom portion 3021B of the housing 302), of the flow-diverting configuration 300, such displacement being motivated by the application of a gravitational force to the partition configuration 604. In some embodiments, for example, the motivated displacement is by the application of a gravitational force, only. In some embodiments, for example, the displacement is with effect that each one of the at least one partition, independently, becomes emplaced in contact engagement (e.g. sealing engagement) with the cavity-defining surface 3021 of the housing 302 (e.g. the cavity-defining surface 3021 of the bottom portion 3021B of the housing 302).

In a further aspect, the reservoir fluid conducting assembly 200 is co-operable with the wellbore string 108 such that, in response to an emplacement of the reservoir fluid conducting assembly 200 within the wellbore string passage 110 that is with effect that the partition configuration 604 becomes emplaced within a wellbore string passage portion 110A characterized by a longitudinal axis 110AX that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees, the mud joint becomes established. In this respect, in some embodiments, for example, the mud joint is established in response to a displacement of the partition configuration 604 towards the bottom portion 302B of the housing 302. The displacement is motivated by a gravitational force applied to the partition configuration 604 in response to the emplacement of the reservoir fluid conducting assembly 200 within the wellbore string passage 110 that is with effect that the partition configuration 604 becomes emplaced within the wellbore string passage portion 110A characterized by a longitudinal axis 110AX that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees. In some embodiments, for example, the motivated displacement is by the application of a gravitational force, only. In some embodiments, for example, the displacement is with effect that each one of the at least one partition, independently, becomes emplaced in contact engagement (e.g. sealing engagement) with the cavity-defining surface 3021 of the bottom portion 3021B of the housing 302.

In those embodiments where: (i) the flow-diverting configuration 300 is supported by the solids-depleted reservoir fluid-transporting configuration 400 (e.g. the pump suction 402A) via a structural support configuration 802, and (ii) the partition configuration 604 is mounted to the upwardly-conducting flow conductor configuration 401 such that the partition configuration-mounted flow conductor 900 is established, the reservoir fluid conducting assembly 200 is configured for co-operation with the wellbore string 108 such that, in response to the emplacement of the reservoir fluid conducting assembly 200 within the wellbore string passage 110, of the wellbore string passage 110, such that the partition configuration-mounted flow conductor 900 becomes emplaced within a wellbore string passage portion 110A characterized by a longitudinal axis 110AX that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees: the partition configuration-mounted flow conductor 900 becomes emplaced, relative to the housing 302, of the flow diverting configuration 300, such that, for each one of the at least one partition 606, independently, the emplacement of the partition 606, in the contact engagement (e.g. sealing engagement) with the cavity-defining surface 3021 of the bottom surface 302B of the housing 302 (of the flow diverting configuration), is established, such that the mud joint 600 and, therefore, the compartment configuration 608, is established.

In some of these embodiments, for example, the housing 302, of the flow-diverting configuration 300, is urged, by a gravitational force, into engagement with a bottom portion 108B of the wellbore string 108, such that the housing 302 is supported by the bottom portion 108B of the wellbore string 108, and, in parallel, displacement of the partition configuration-mounted flow conductor configuration 900, towards the cavity-defining surface 3021 of the bottom portion 302B of the housing 302, is urged, by a gravitational force, with effect that, for each one of the at least one partition 606, independently, the emplacement of the partition 606, in the contact engagement (e.g. sealing engagement) with the cavity-defining surface 3021 of the bottom portion 302B of the housing 302, is effectuated, with effect that mud joint 600 and, therefore, the compartment configuration 608, is established.

Referring to FIG. 8, in some of these embodiments, for example, prior to the partition configuration-mounted flow conductor 900 becoming emplaced within a wellbore string passage portion 110A characterized by a longitudinal axis 110AX that is disposed, relative to a horizontal plane “HP”, at an acute angle “AA” having a value that is less than 30 degrees, the partition configuration-mounted flow conductor 900 is disposed in an orientation such that gravitational forces are ineffective for establishing the mud joint 600 (and, therefore, the compartment configuration 608). In some embodiments, for example, this occurs while the partition configuration-mounted flow conductor 900 is disposed within a vertical portion of the wellbore string passage 110, while the reservoir fluid conducting assembly 200 is being deployed downhole within the wellbore string passage 110. In such cases, there is an absence of an urging, by gravitational forces, of displacement of the partition configuration-mounted flow conductor 900 towards the cavity-defining surface 3021 of the housing 302, that is effective for establishing the mud joint 600, (and, therefore, the compartment configuration 608) such as by effectuating the contact engagement between the partition configuration 604 and the cavity-defining surface 3021 of the housing 302.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the mud joint 600, within the wellbore string passage portion 110A of the wellbore string 108, is established, such that the compartment configuration 608 is established by the co-operative configuration of at least the mud joint housing 602 and the partition configuration 604, the defeating of the establishment of the compartment configuration 608 is opposed by a gravitational force. In some of these embodiments, for example, the defeating of the establishment of the compartment configuration 608 is opposed by a gravitational force, only.

In some embodiments, for example, the reservoir fluid conducting assembly 200 is further configured for co-operation with the wellbore string 108 such that, while the emplacement of the reservoir fluid conducting assembly 200, within the wellbore string passage 110 of the wellbore string 108, is established, such that the compartment configuration 608 is established by the co-operative configuration of at least the mud joint housing 602 and the partition configuration 604, for each one of the at least one partition 606 of the partition configuration 604, independently, defeating of the contact engagement, by the partition 606, with the the cavity-defining surface 6021, is opposed by gravitational force. In some of these embodiments, for example, for each one of the at least one partition 606 of the partition configuration 604, independently, the defeating of the contact engagement, by the partition 606, with the cavity-defining surface 6021, is opposed by gravitational force, only.

In some embodiments, for example, each one of the at least one partition 606, independently, includes a respective sealing member 612. In this respect, in some embodiments, for example, for each one of the at least one partition 606, independently, the sealing member 612, that is respective to the partition 606, is defined by resilient material, such as an elastomeric material. In some embodiments, for example, each one of the at least one partition 606 includes a nitrile grommet, and the mounting of the nitrile grommet includes gluing of the nitrile grommet to the upwardly-conducting flow conductor configuration 401. In some embodiments, for example, for each one of the at least one partition, independently, the contact engagement, between the partition 606 and the cavity-defining surface 6021, is established by contact engagement between the sealing member 612, that is respective to the partition, and the cavity-defining surface 6021.

Referring to FIG. 9, in some embodiments, for example, each one of the at least one partition 606, independently, includes a respective assembly, and the assembly, that is respective to the partition 606, includes a respective support washer 6121, a respective sealing member 612, and a respective mount disc 6122. In some embodiments, for example, for each one of the at least one partition 606, independently, the mount disc 6122, that is respective to the partition, is welded to the upwardly-conducting flow conductor configuration 401, and the sealing member 612, that is respective to the partition, is pressed between the support washer 6121, that is respective to the partition 606, and the mount disc 6122, that is respective to the partition 606, as the support washer 6121, that is respective to the partition 606, is being retained against the sealing member 612, that is respective to the partition 606, by coupling of the support washer 6121, that is respective to the partition 606, to the mount disc 6122, that is respective to the partition 606, with mounting screws.

Referring to FIG. 3, in some embodiments, for example, the upwardly-conducting flow conductor configuration 401 extends from the cavity 301, of the housing 302 of the apparatus 3001, uphole relative to the apparatus 3001, via an opening 3083 defined at an upper end 3082 of the housing 302. In some embodiments, for example, the upwardly-conducting flow conductor configuration 401 includes an eccentrically-disposed configuration 401A. In some embodiments, for example, the eccentrically-disposed configuration 401A is disposed laterally outwardly relative to the central longitudinal axis 110X of the wellbore string passage 110. In some embodiments, for example, the eccentrically-disposed configuration 401A is defined by at least that portion of the upwardly-conducting flow conductor configuration 401 which extends from the cavity 301, of the housing 302 of the flow diverter 3001.

In some embodiments, for example, the flow-receiving communicator 3081 is defined by the space of the opening 3083 that is unoccupied by the upwardly-conducting flow conductor configuration 401. In this respect, in some embodiments, for example, the upwardly-conducting flow conductor configuration 401 and the opening 3083 co-operate to establish the flow-receiving communicator 3081 for receiving the downwardly-flowing gas-depleted reservoir fluid 708A from the separation zone 305. In this respect, in some embodiments, for example, the separation zone 305 is disposed externally of the apparatus 3001. Referring to FIG. 3, in some embodiments, for example, the flow-receiving communicator 3081 is oriented in an uphole facing direction, and, in some of these embodiments, for example, the central axis of the flow-receiving communicator 3081 is parallel to the central longitudinal axis 110X of the wellbore string passage 110. In some embodiments, for example, the downwardly-flowing gas-depleted reservoir fluid 708A, received by the flow-receiving communicator 3081, continues to become depleted in gaseous material.

Referring to FIG. 4, in some embodiments, for example, rather than sharing the opening 3083 with the upwardly-conducting flow conductor configuration 401, the flow-receiving communicator 3081 is defined by one or more ports extending through a side wall 315 of the flow diverter 3001, at an upper portion of the flow diverter 3001. In some embodiments, for example, the flow-receiving communicator 3081 has an axis that is transverse to the central longitudinal axis 110X of the wellbore string passage 110. The flow-receiving communicator 3081 effectuates flow communication between the space 303 and the cavity 301 defined within the housing 302. In some embodiments, for example, the separation zone 305 is disposed externally of the apparatus 3001, and above the flow-receiving communicator 3081, such that the flow-receiving communicator 3081 is disposed for receiving the gas-depleted reservoir fluid 708A from the externally-disposed separation zone 305. In some embodiments, for example, a portion of the separation zone 305 is disposed externally of the apparatus 3001 and above the flow-receiving communicator 3081, and another portion of the separation zone 305 is disposed within the cavity 301 of the apparatus 3001, such that a fraction of the separation is effected externally of the apparatus 3001 and another fraction of the separation is effected within the cavity 301. In either case, a flow of the gas-depleted reservoir fluid derivative 708B is processed by the flow-diverting configuration 300 within the apparatus 3001. In some of these embodiments, for example, the apparatus 3001 is a “poor boy separator”.

The preceding discussion provides many example embodiments. Although each embodiment represents a single combination of inventive elements, other examples may include all suitable combinations of the disclosed elements. Thus if one embodiment comprises elements A, B, and C, and a second embodiment comprises elements B and D, other remaining combinations of A, B, C, or D, may also be used.

Although the embodiments have been described in detail, it should be understood that various changes, substitutions and alterations could be made herein.

Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, and composition of matter, means, methods and steps described in the specification.

As one of ordinary skill in the art will readily appreciate from the disclosure of the present invention, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed, that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.

As can be understood, the examples described above and illustrated are intended to be examples only. The invention is defined by the appended claims.