WO2018132927A1 - Systèmes pour améliorer la séparation en fond de trou de gaz de liquides tout en produisant un fluide de réservoir à l'aide d'une pompe électrique submersible - Google Patents

Systèmes pour améliorer la séparation en fond de trou de gaz de liquides tout en produisant un fluide de réservoir à l'aide d'une pompe électrique submersible Download PDF

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Publication number
WO2018132927A1
WO2018132927A1 PCT/CA2018/050077 CA2018050077W WO2018132927A1 WO 2018132927 A1 WO2018132927 A1 WO 2018132927A1 CA 2018050077 W CA2018050077 W CA 2018050077W WO 2018132927 A1 WO2018132927 A1 WO 2018132927A1
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WO
WIPO (PCT)
Prior art keywords
reservoir fluid
gas
wellbore
depleted
pump
Prior art date
Application number
PCT/CA2018/050077
Other languages
English (en)
Inventor
Jeff Saponja
Rob Hari
Ryan Chachula
Dave KIMERY
Original Assignee
Heal Systems Lp
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Heal Systems Lp filed Critical Heal Systems Lp
Publication of WO2018132927A1 publication Critical patent/WO2018132927A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/18—Pipes provided with plural fluid passages
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids

Definitions

  • the present disclosure relates to mitigating downhole pump gas interference during hydrocarbon production.
  • Downhole pump gas interference is a problem encountered while producing wells, especially wells with horizontal sections.
  • the presence of such gaseous material hinders production by contributing to sluggish flow.
  • a reservoir fluid conducting assembly for disposition within a wellbore string, that is lining a wellbore that is extending into a subterranean formation, such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly, wherein the assembly comprises: a pump; a flow diverter body comprising: a plurality of reservoir fluid-conducting conduits; a reservoir fluid receiver; a reservoir fluid discharge communicator; wherein each one of the reservoir fluid-conducting conduits, independently, is connected to both of the reservoir fluid receiver and the reservoir fluid discharge communicator such that reservoir fluid that is received by the reservoir fluid receiver is distributed to the reservoir fluid- conducting conduits and conducted by the reservoir fluid conducting-tubes to the reservoir fluid discharge communicator; a gas-depleted reservoir fluid receiver; wherein: the reservoir fluid receiver, the reservoir fluid-conducting conduits, the reservoir fluid discharge communicator, and the gas-depleted reservoir fluid receiver are co-operatively configured such
  • a reservoir fluid conducting assembly for disposition within a wellbore string, that is lining a wellbore that is extending into a subterranean formation, such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly, wherein the assembly comprises: a pump; a flow diverter body comprising: a plurality of diverter body-defined reservoir fluid conductors; a reservoir fluid receiver; a reservoir fluid discharge communicator; a gas-depleted reservoir fluid receiver; wherein each one of the diverter body-defined reservoir fluid conductors, independently, effects fluid coupling between the reservoir fluid receiver and the reservoir fluid discharge communicator such that reservoir fluid that is received by the reservoir fluid receiver is distributed to the diverter body-defined reservoir fluid conductors and conducted by the reservoir fluid conducting-tubes to the reservoir fluid discharge communicator; a gas-depleted reservoir fluid receiver; wherein: the reservoir fluid receiver, the diverter body-defined reservoir fluid conductors, the reservoir fluid discharge
  • gas-depleted reservoir fluid conductor is effecting fluid coupling between the gas-depleted reservoir fluid receiver and the pump for conducting gas-depleted reservoir fluid received by the gas-depleted reservoir fluid receiver to the pump.
  • a reservoir fluid conducting assembly for disposition within a wellbore string, that is lining a wellbore that is extending into a subterranean formation, such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly, wherein the assembly comprises: a pump assembly including a pump; and a flow diverter body including: a reservoir fluid receiver configured for receiving reservoir fluid flow; a reservoir fluid discharge communicator configured for discharging reservoir fluid that is received by the reservoir fluid receiver; a diverter body-defined reservoir fluid conductor effecting fluid coupling between the reservoir fluid receiver and the reservoir fluid discharge communicator; a gas-depleted reservoir fluid receiver; wherein: the reservoir fluid receiver, the diverter body-defined reservoir fluid conductor, the reservoir fluid discharge communicator, and the gas-depleted reservoir fluid receiver are co-operatively configured such that: (i) while the fluid conducting assembly is disposed within the wellbore string such that an intermediate wellbore passage is defined between the fluid
  • the gas-depleted reservoir fluid conductor bypass includes a first pump assembly aperture; and the pump assembly extends through the first pump assembly aperture; wherein: a first sealed interface is defined between the pump assembly and the gas-depleted reservoir fluid conductor bypass with effect that flow communication through the first pump assembly aperture of the gas-depleted reservoir fluid conductor bypass, between the pump assembly and the gas-depleted reservoir fluid conductor bypass, is sealed or substantially sealed.
  • a reservoir fluid conducting assembly for disposition within a wellbore string, that is lining a wellbore that is extending into a subterranean formation, such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly, wherein the assembly comprises: a pump assembly including a pump; and a flow diverter body, configured for disposition within a wellbore, including: a reservoir fluid receiver configured for receiving reservoir fluid flow; a reservoir fluid discharge communicator configured for discharging reservoir fluid that is received by the reservoir fluid receiver; a diverter body-defined reservoir fluid conductor effecting fluid coupling between the reservoir fluid receiver and the reservoir fluid discharge communicator; a gas-depleted reservoir fluid receiver; wherein: the reservoir fluid receiver, the diverter body-defined reservoir fluid conductor, the reservoir fluid discharge communicator, and the gas-depleted reservoir fluid receiver are co-operatively configured such that: (i) while the fluid conducting assembly is disposed within the wellbore string such that
  • the pump assembly further includes a pump intake that includes a pump intake receiver; the pump is fluidly coupled to the pump intake; and the pump intake is fluidly coupled to the gas-depleted reservoir fluid conductor, for receiving, via the pump intake receiver, the gas-depleted reservoir fluid being conducted by the gas-depleted reservoir fluid conductor, and conducting the received gas- depleted reservoir fluid to the pump;
  • the gas-depleted reservoir fluid conductor bypass includes a first pump assembly aperture; and the pump assembly is disposed in sealing, or substantially sealing, engagement with the gas-depleted reservoir fluid conductor bypass, while extending through the first pump assembly aperture, with effect that: (i) the pump intake receiver is fluidly coupled to the gas-depleted reservoir fluid receiver, and (ii) flow communication through the first pump assembly aperture of the
  • a reservoir fluid conduction assembly for disposition within a wellbore string, that is lining a wellbore that is extending into a subterranean formation, such that an intermediate wellbore space is defined within a space that is disposed between the wellbore string and the assembly, wherein the assembly comprises: a pump; a flow diverter body including (a) a diverter body-defined reservoir fluid conductor for conducting reservoir fluid, that is received by flow diverter body from the subterranean formation via a downhole wellbore space of the wellbore, to a reservoir fluid separation space of an uphole wellbore space of the wellbore, the uphole wellbore space being disposed uphole relative to the downhole wellbore space, and (b) a diverter body-defined gas-depleted reservoir fluid conductor, fluidly coupled to the pump, for receiving gas-depleted reservoir fluid and conducting the received gas-depleted reservoir fluid for effecting supplying of the gas-depleted reservoir fluid to the pump;
  • a reservoir fluid production assembly comprising: any one of the reservoir fluid conducting assemblies described above, and further including a sealed interface effector configured for interacting with a wellbore string, disposed within a wellbore, for defining a wellbore-disposed sealed interface within the wellbore, between: (a) the uphole wellbore space of the wellbore, and (b) the downhole wellbore space of the wellbore, for preventing, or substantially preventing, bypassing of the gas-depleted reservoir fluid receiver by the gas-depleted reservoir fluid; and a production string including: a production string inlet for receiving, via the wellbore, the reservoir fluid from the subterranean formation; and a production string outlet for discharging the gas-depleted reservoir fluid flow to the surface; wherein: the reservoir fluid conducting assembly is integrated within the production string; and the integration is with effect that: (i) while the production assembly is disposed within the wellbore string such that an intermediate wellbore passage is defined between the production assembly
  • the reservoir fluid production assembly as described above, wherein the integration is with further effect that the gas-depleted reservoir fluid receiver is disposed downhole relative to the reservoir fluid discharge communicator, with effect that the separated gas-depleted reservoir fluid is conducted in a downhole direction to the gas-depleted reservoir fluid receiver.
  • a system comprising any one of the reservoir fluid production assemblies as described above, disposed within a wellbore.
  • Figure 1 A is a schematic illustration of an embodiment of a reservoir fluid production assembly disposed within a wellbore
  • Figure IB is a schematic illustration of an embodiment of a flow diverter of embodiments of the system of the present disclosure
  • Figure 2A is a side view of an embodiment of a flow diverter body of the reservoir fluid production assembly illustrated in Figure 1;
  • Figure 2B is a sectional view of the flow diverter body illustrated in Figure 2A, taken along lines A- A;
  • Figure 2C is a sectional view of the flow diverter body illustrated in Figure 2A, taken along lines B-B;
  • Figure 2D is a sectional view of the flow diverter body illustrated in Figure 2A, taken along lines C-C;
  • Figure 2E is a sectional view of the flow diverter body illustrated in Figure 2B, taken along lines D-D;
  • Figure 2F is a sectional view of the flow diverter body illustrated in Figure 2B, taken along lines E-E;
  • Figure 3 is a schematic illustration of the flow diverter body illustrated in Figures 2A to 2E, with portions of the shrouds removed for clarity, and showing the flow paths of fluids being conducted through the flow diverter body while the flow diverter body is part of a reservoir fluid production assembly disposed within a wellbore;
  • Figure 4 is a side view of a bypass of the flow diverter body illustrated in Figures 2A to 2E;
  • Figure 5 is a perspective view of a portion of a reservoir fluid production assembly, illustrating the coupling of the bypass, shown in Figure 4, to a pump assembly;
  • Figure 6 is a schematic illustration of a portion of the uphole fluid conductor of the flow diverter body illustrated in Figures 2 A to 2E, with the uphole fluid conductor portion shown in phantom to illustrate the arrangement of the fins;
  • Figure 7 is a view of one end of a downhole clamp of the flow diverter body illustrated in Figures 2A to 2E, with the pins, coupling the two sections of the clamp, shown in phantom;
  • Figure 8 is a view of one end of an uphole of the flow diverter body illustrated in Figures 2 A to 2E, with the pins, coupling the two sections of the clamp, shown in phantom;
  • Figure 9 is a fragmentary side view of a portion of another embodiment of the flow diverter body, illustrating the uphole shroud, bypass, and the downhole shroud;
  • Figure 10 is a sectional view of the flow diverter body illustrated in Figure 9, taken along lines A- A, with the pump assembly removed for clarity;
  • Figure 11 is a sectional view of the flow diverter body illustrated in Figure 9, taken along lines B-B, with the pump assembly removed for clarity;
  • Figure 12 is an exploded view of the bypass of the flow diverter body illustrated in Figure 9;
  • Figure 13 is an exploded view of the downhole connector of the bypass illustrated in Figure 12;
  • Figure 14 is an exploded view of the up hole connector of the bypass illustrated in Figure 12.
  • the terms “up”, “upward”, “upper”, or “uphole”, mean, relativistically, in closer proximity to the surface 106 and further away from the bottom of the wellbore, when measured along the longitudinal axis of the wellbore 102.
  • the terms “down”, “downward”, “lower”, or “downhole” mean, relativistically, further away from the surface 106 and in closer proximity to the bottom of the wellbore 102, when measured along the longitudinal axis of the wellbore 102.
  • systems 8 with associated apparatuses, for producing hydrocarbons from a reservoir, such as an oil reservoir, within a subterranean formation 100, when reservoir pressure within the oil reservoir is insufficient to conduct hydrocarbons to the surface 106 through a wellbore 102.
  • the wellbore 102 can be straight, curved, or branched.
  • the wellbore 102 can have various wellbore portions.
  • a wellbore portion is an axial length of a wellbore 102.
  • a wellbore portion 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.
  • vertical when used to describe a wellbore portion, refers to a vertical or highly deviated vertical portion as understood in the art, such as, for example, a wellbore portion having a longitudinal axis that is less than about 20 degrees from the vertical.
  • 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.
  • 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.
  • 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").
  • SAGD steam-assisted gravity drainage
  • CSS cyclic steam stimulation
  • the same wellbore is utilized for both stimulation and production operations, such as for hydraulically fractured formations or for formations subjected to CSS.
  • different wellbores are used, such as for formations subjected to SAGD, or formations subjected to waterflooding.
  • a wellbore string 113 is employed within the wellbore 102 for stabilizing the subterranean formation 100.
  • the wellbore string 113 also contributes to effecting fluidic isolation of one zone within the subterranean formation 100 from another zone within the subterranean formation 100.
  • the fluid productive portion of the wellbore 102 may be completed either as a cased- hole completion or an open-hole completion.
  • a cased-hole completion involves running wellbore casing down into the wellbore through the production zone.
  • the wellbore string 113 includes wellbore casing.
  • 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.
  • 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).
  • sealing, or substantial sealing, of 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.
  • the cement is disposed as a sheath within an annular region between the wellbore casing and the oil reservoir.
  • the cement is bonded to both of the production casing and the oil reservoir.
  • 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.
  • cementing is introduced to an annular region between the wellbore casing and the oil reservoir after the subject wellbore casing has been run into the wellbore. This operation is known as "cementing".
  • 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.
  • each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.
  • a wellbore typically 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 106. Typically, casing string sizes are intentionally minimized to minimize costs during well construction. Generally, smaller casing sizes make production and artificial lofting more challenging.
  • 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 116.
  • the annular region between the last casing string and the production tubing string may be sealed at the bottom by a packer.
  • the wellbore casing may be perforated, or otherwise include per-existing ports (which may be selectively openable, such as, for example, by shifting a sleeve), to provide a fluid passage for enabling flow of reservoir fluid from the reservoir to the wellbore.
  • the wellbore casing is set short of total depth.
  • 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 116.
  • 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.
  • this liner is perforated to effect flow communication between the reservoir and the wellbore.
  • the liner string can also be a screen or is slotted.
  • 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 wellhead 116.
  • no cemented liner is installed, and this is called an open hole completion or uncemented 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 string 113). 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.
  • an assembly 10 is provided for effecting production of reservoir fluid from the reservoir 104 of the subterranean formation 100.
  • a wellbore fluid conductor 113 such as, for example, the wellbore string 113 (such as, for example, the casing 113), is disposed within the wellbore 102.
  • the assembly 10 is configured for disposition within the wellbore fluid conductor 113, such that an intermediate wellbore passage 112 is defined within the wellbore fluid conductor 113, between the assembly 10 and the wellbore fluid conductor 113.
  • the intermediate wellbore passage 112 is an annular space disposed between the assembly 10 and the wellbore string 113.
  • the intermediate wellbore passage 112 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from the assembly 10 to the wellbore fluid conductor 113. In some embodiments, for example, the intermediate wellbore passage 112 extends longitudinally to the wellhead 116, between the assembly 10 and the wellbore string 113.
  • the assembly 10 includes a production string 202 that is disposed within the wellbore 102.
  • the production string 202 includes a pump 300
  • the pump 300 is provided to, through mechanical action, pressurize and effect conduction of the reservoir fluid from the reservoir 104, through the wellbore 102, and to the surface 106, and thereby effect production of the reservoir fluid. It is understood that the reservoir fluid being conducted uphole through the wellbore 102, via the production string 202, may be additionally energized by supplemental means, including by gas-lift. In some embodiments, for example, the pump 300 is a sucker rod pump. Other suitable pumps 300 include screw pumps, electrical submersible pumps, and jet pumps.
  • the system also includes a flow diverter 600.
  • the flow diverter 600 is provided for, amongst other things, mitigating gas lock within the pump 300.
  • the flow diverter 600 is disposed within a vertical portion of the wellbore 102 that extends to the surface 106.
  • the flow diverter 600 includes a wellbore string counterpart 600B and an assembly counterpart 600C.
  • the wellbore string 113 defines the wellbore string counterpart 600B
  • the assembly 10 defines the assembly counterpart 600C.
  • the flow diverter 600 defines: (i) a reservoir fluid-conducting passage 6002 for diverted reservoir fluid, received within the downhole wellbore space from the reservoir 104, to a reservoir fluid separation space 112X of the wellbore 102, with effect that a gas-depleted reservoir fluid is separated from the reservoir fluid within the reservoir fluid separation space 112X in response to at least buoyancy forces; and (ii) a gas-depleted reservoir fluid-conducting passage 6004 for 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 diverter 600 in the uphole direction to the pump 300.
  • 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 disposable into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the reservoir 104.
  • the wellbore 102 is disposed for receiving reservoir fluid flow from the reservoir 104.
  • the production string inlet 204 is for receiving, via the wellbore, the reservoir fluid flow from the reservoir. In this respect, the reservoir fluid flow enters the wellbore 102, as described above, and is then conducted to the production string inlet 204.
  • the production string 202 includes a reservoir fluid-supplying conductor 206, disposed downhole relative to the flow diverter 600 for conducting the reservoir fluid (such as a reservoir fluid flow), that is being received by the production string inlet, such that the reservoir fluid, that is received by the inlet 204, is conducted to the flow diverter 600 via the fluid-supplying conductor 206.
  • the production string 202 also includes a gas-depleted reservoir fluid-producing conductor 210, disposed uphole relative to the flow diverter 600 for conducting a gas-depleted reservoir fluid (such as a gas- depleted reservoir fluid flow) from the flow diverter 600 to a production string outlet 208, located at the wellhead 116.
  • the flow diverter 600 is provided to, amongst other things, perform this function.
  • the flow diverter 600 is disposed downhole relative to the pump 300 and is fluidly coupled to the pump suction 302, such as, for example, by an intermediate fluid conductor that forms part of the fluid- producing conductor 210, such as piping.
  • the assembly counterpart 600C includes a fluid diverter body 600 A.
  • the flow diverter body 600A is configured such that the depletion of gaseous material from the reservoir fluid material, that is effected while the assembly 10 is disposed within the wellbore 102, is effected externally of the flow diverter body 600 A within the wellbore 102, such as, for example, within an uphole wellbore space 108 of the wellbore 102.
  • the flow diverter body 600A includes a reservoir fluid receiver 602 for receiving the reservoir fluid (such as, for example, in the form of a reservoir fluid flow) that is being conducted (e.g. flowed), via the fluid-supplying conductor 206 of the production string 202, from the production string inlet 204.
  • the fluid-supplying conductor 206 extends from the inlet 204 to the receiver 602.
  • the fluid-supplying conductor 206 is fluidly coupled to the inlet 204.
  • the reservoir fluid receiver 602 includes one or more ports 602A for receiving reservoir fluid being conducted by the fluid- supplying conductor 206.
  • the flow diverter body 600A also includes a reservoir fluid discharge communicator 604 that is fluidly coupled to the reservoir fluid receiver 602 via a reservoir fluid-conductor 603.
  • the reservoir fluid conductor 603 defines at least a portion of the reservoir fluid- conducting passage 6002.
  • the reservoir fluid conductor 603 defines one or more reservoir fluid conductor passages 603 A. In some of the embodiments described below, for example, the one or more reservoir fluid-conducting passages 603 A.
  • the reservoir fluid discharge communicator 604 is configured for discharging reservoir fluid (such as, for example, in the form of a flow) that is received by the reservoir fluid receiver 602 and conducted to the reservoir fluid discharge communicator 604 via the reservoir fluid conductor 603.
  • reservoir fluid discharge communicator 604 is disposed at an opposite end of the flow diverter body 600A relative to the reservoir fluid receiver 602.
  • the reservoir fluid discharge communicator 604 includes one or more ports 604A.
  • the flow diverter body 600A also includes a gas-depleted reservoir fluid receiver 608 for receiving a gas-depleted reservoir fluid (such as, for example, in the form of a flow), after gaseous material has been separated from the reservoir fluid (for example, a reservoir fluid flow), that has been discharged from the reservoir fluid discharge communicator 604, in response to at least buoyancy forces.
  • a gas-depleted reservoir fluid such as, for example, in the form of a flow
  • gaseous material has been separated from the reservoir fluid (for example, a reservoir fluid flow)
  • the reservoir fluid discharge communicator 604 in response to at least buoyancy forces.
  • the gas-depleted reservoir fluid receiver 608 and the reservoir fluid discharge communicator 604 are co-operatively configured such that the gas- depleted reservoir fluid receiver 608 is disposed for receiving a gas-depleted reservoir fluid flow, after gaseous material has been separated from the received reservoir fluid flow that has been discharged from the reservoir fluid discharge communicator 604, in response to at least buoyancy forces.
  • the reservoir fluid discharge communicator 604 is disposed at an opposite end of the flow diverter body 600A relative to the gas-depleted reservoir fluid receiver 608.
  • the gas-depleted reservoir fluid receiver 608 includes one or more ports 608A.
  • the flow diverter body 600A also includes a gas-depleted reservoir fluid conductor 610 that defines a gas-depleted reservoir fluid-conducting passage 610A configured for conducting the gas-depleted reservoir fluid (for example, a gas-depleted reservoir fluid flow), received by the receiver 608, to the gas-depleted reservoir fluid discharge communicator 611.
  • the gas-depleted reservoir fluid discharge communicator 611 is disposed at an opposite end of the flow diverter body 600A relative to the gas-depleted reservoir fluid receiver 608.
  • the gas-depleted reservoir fluid discharge communicator 611 is configured for fluid coupling to the pump 300, wherein the fluid coupling is for supplying the pump 300 with the gas-depleted reservoir fluid received by the receiver 610 and conducted through at least the gas-depleted reservoir fluid conductor 610.
  • the gas-depleted reservoir fluid- conducting passage 610A defines at least a portion of the gas-depleted reservoir fluid-conducting passage 6004.
  • the gas-depleted reservoir fluid discharge communicator includes one or more ports 611 A.
  • the reservoir fluid discharge communicator 604 is oriented such that, a ray (see, for example ray 604B), that is disposed along the central longitudinal axis of the reservoir fluid discharge communicator, is disposed in an uphole direction at an acute angle of less than 30 degrees relative to the central longitudinal axis of the wellbore portion within which the flow diverter body 600A is disposed.
  • the reservoir fluid discharge communicator 604 is oriented such that, a ray (see, for example ray 604B), that is disposed along the central longitudinal axis of the reservoir fluid discharge communicator 604, is disposed in an uphole direction at an acute angle of less than 30 degrees relative to the vertical (which includes disposition of the ray 604B along a vertical axis).
  • the flow diverter body 600A includes the reservoir fluid receiver 602, the reservoir fluid discharge communicator 604, and the reservoir fluid conductor 603 (such as, for example, in the form of a fluid passage or a network of fluid passages), for fluidly coupling the receiver 602 and the discharge communicator 604.
  • the flow diverter body 600A also includes the gas-depleted reservoir fluid receiver 608, gas-depleted reservoir fluid discharge communicator 611, and the gas-depleted reservoir fluid conductor 610 (such as, for example, in the form of a fluid passage or a network of fluid passages) for fluidly coupling the receiver 608 to the discharge communicator 611.
  • the assembly counterpart 600C also includes a wellbore sealed interface effector 400 configured for interacting with a wellbore feature for defining a wellbore sealed interface 500 within the wellbore 102, between: (a) an up hole wellbore space 108 of the wellbore 102, and (b) a downhole wellbore space 110 of the wellbore 102, while the assembly 10 is disposed within the wellbore 102.
  • a wellbore sealed interface effector 400 configured for interacting with a wellbore feature for defining a wellbore sealed interface 500 within the wellbore 102, between: (a) an up hole wellbore space 108 of the wellbore 102, and (b) a downhole wellbore space 110 of the wellbore 102, while the assembly 10 is disposed within the wellbore 102.
  • the disposition of the sealed interface 500 is such that flow communication, via the intermediate wellbore passage 112, between an up hole wellbore space 108 and a downhole wellbore space 110 (and across the sealed interface 500), is prevented, or substantially prevented.
  • the disposition of the sealed interface 500 is such that fluid flow, across the sealed interface 500, in a downhole direction, from the uphole wellbore space 108 to the downhole wellbore space 110, is prevented, or substantially prevented.
  • the disposition of the sealed interface 500 is effected by the combination of at least: (i) a sealed, or substantially sealed, disposition of the wellbore string 113 relative to a polished bore receptacle 114 (such as that effected by a packer
  • the sealed interface 500 functions to prevent, or substantially prevented, reservoir fluid flow, that is received within the wellbore 102 (that is lined with the wellbore string 113), from bypassing the reservoir fluid receiver 602, and, as a corollary, the reservoir fluid is directed to the reservoir fluid receiver 602 for receiving by the reservoir fluid receiver 602.
  • the sealed interface 500 functions to prevent, or substantially prevented, gas-depleted reservoir fluid flow, that has been separated from the reservoir fluid discharged into the wellbore 102 from the discharge communicator 604, from bypassing the gas-depleted reservoir fluid receiver 608 and, as a corollary, the gas-depleted reservoir fluid is directed to the gas-depleted reservoir fluid receiver 608 for receiving by the gas-depleted reservoir fluid receiver 608.
  • the sealed, or substantially sealed, disposition of the fluid-supplying conductor 206 relative to the polished bore receptacle 114 is effected by a latch seal assembly.
  • a suitable latch seal assembly is a WeatherfordTM Thread-Latch Anchor Seal AssemblyTM.
  • the sealed, or substantially sealed, disposition of the downhole fluid-supplying conductor 206 relative to the polished bore receptacle 114 is effected by one or more o-rings or seal-type Chevron rings.
  • the sealing interface effector 400 includes the o-rings, or includes the seal-type Chevron rings.
  • the sealed, or substantially sealed, disposition of the fluid-supplying conductor 206 relative to the polished bore receptacle 114 is disposed in an interference fit with the polished bore receptacle.
  • the fluid-supplying conductor 206 is landed or engaged or "stung" within the polished bore receptacle 114.
  • the above-described disposition of the wellbore sealed interface 500 provide for conditions which minimize solid debris accumulation in the joint between the downhole fluid- supplying conductor 206 and the polished bore receptacle 114 or in the joint between the polished bore receptacle 114 and the wellbore string 113.
  • conditions which minimize solid debris accumulation within the joint interference to movement of the separator relative to the liner, or the casing, as the case may be, which could be effected by accumulated solid debris, is mitigated.
  • the sealed interface 500 is disposed within a section of the wellbore 102 whose axis 14 A is disposed at an angle "a" of at least 60 degrees relative to the vertical "V". In some of these embodiments, for example, the sealed interface 500 is disposed within a section of the wellbore whose axis is disposed at an angle "a" of at least 85 degrees relative to the vertical "V". In this respect, disposing the sealed interface 500 within a wellbore section having such wellbore inclinations minimizes solid debris accumulation at the sealed interface 500.
  • the flow diverter body 600, the sealed interface effector 400, and the reservoir fluid conductor 206 are co-operatively configured such that, while the assembly 10 is disposed within the wellbore string 113 such that the sealed interface 500 is defined, and the reservoir fluid-supplying conductor 206 is receiving reservoir fluid from the downhole wellbore space 110 that has been received within the downhole wellbore space 110 from the subterranean formation 100: the reservoir fluid is conducted to the reservoir fluid receiver 602 via the reservoir fluid- supplying conductor 206; the reservoir fluid is conducted as a flow 802 to the reservoir fluid discharge communicator 604 by the reservoir fluid conductor 603 and discharged as a flow 804 to the reservoir fluid separation space 112X of the uphole wellbore space 108; within the reservoir fluid separation space 112X, a gas-depleted reservoir fluid is separated from the discharged reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained; the separated gas-
  • the gas-depleted reservoir fluid is pressurized by the pump 300 and conducted to the surface via the reservoir fluid-producing conductor 210.
  • the separation of gaseous material from the reservoir fluid 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) as a flow 810 via the intermediate wellbore passage 112 that is disposed between the assembly 10 and the wellbore string 113 (see above).
  • the reservoir fluid produced from the subterranean formation 100, via the wellbore 102, including the gas-depleted reservoir fluid, the liquid-depleted reservoir material, or both, may be discharged through the wellhead 116 to a collection facility, such as a storage tank within a battery.
  • the flow diverter body 600A is configured such that the gas-depleted reservoir fluid receiver 608 is disposed downhole relative to (such as, for example, vertically below) the reservoir fluid discharge communicator 604, with effect that the separated gas-depleted reservoir fluid is conducted in a downhole direction to the gas-depleted reservoir fluid receiver 608.
  • separation of gaseous material, from the reservoir fluid that is being discharged from the reservoir fluid discharge communicator 604, is effected within an uphole-disposed space 1121X of the intermediate wellbore passage 112, the uphole- disposed space 1121X being disposed uphole relative to the reservoir fluid discharge communicator 604.
  • the reservoir fluid separation space 112X includes the uphole-disposed space 112 IX.
  • a flow diverter body-defined intermediate wellbore passage portion 1121Y of the intermediate wellbore passage 112 is disposed within a space between the flow diverter body 600 A and the wellbore string 113, and effects flow communication between the reservoir fluid discharge communicator 604 and the gas-depleted reservoir fluid receiver 608 for effecting conducting of the gas-depleted reservoir fluid to the gas-depleted reservoir fluid receiver 608.
  • the flow diverter body-defined intermediate wellbore passage portion 1121Y defines at least a portion of the gas-depleted reservoir fluid-conducting passage 6004.
  • the space between the flow diverter body 600A and the wellbore string 113, within which the flow diverter body-defined intermediate wellbore passage portion 1121Y is disposed is an annular space.
  • the flow diverter body-defined intermediate space 1121 Y is defined by the entirety, or the substantial entirety, of the space between the flow diverter body 600 A and the wellbore string 113.
  • separation of gaseous material, from the reservoir fluid that is discharged from the reservoir fluid discharge communicator 604 is effected within the flow diverter body-defined intermediate wellbore passage portion 1121Y.
  • at least a portion of the reservoir fluid separation space 112X is co- located with at least a portion of the flow diverter body-defined intermediate wellbore passage portion 1121Y.
  • the separation of gaseous material, from the reservoir fluid that is being discharged from the reservoir fluid discharge communicator 604, is effected within both of the uphole-disposed space 112 IX and the flow diverter body-defined intermediate wellbore passage portion 1121Y.
  • the reservoir fluid is discharged from the reservoir fluid discharge communicator 604 into the uphole wellbore space 112 IX, and, in response to at least buoyancy forces, the gaseous material is separated from the discharged reservoir fluid, while the reservoir fluid is being conducted downhole, from the uphole-disposed space 112 IX, through the flow diverter body- defined intermediate wellbore passage portion 1 121Y, and to the gas-depleted reservoir fluid receiver 608.
  • the uphole-disposed space 112 IX is merged with the flow diverter body-defined intermediate wellbore passage portion 1121Y [0089]
  • the reservoir fluid separation space 112X spans a continuous space extending from the assembly to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the assembly 10.
  • the reservoir fluid separation space 112X spans a continuous space extending from the assembly to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the wellbore 102.
  • the reservoir fluid separation space 112X is disposed within a vertical portion of the wellbore 102 that extends to the surface 106.
  • the ratio of the minimum cross-sectional flow area of the reservoir fluid separation space 112X to the maximum cross-sectional flow area of the fluid passage 206A defined by the reservoir fluid-supplying conductor 206 is at least about 1.5.
  • the space between: (a) the gas-depleted reservoir fluid receiver 608 of the flow diverter body 600A, and (b) the sealed interface 500, defines a sump 700 for collection of solid particulate that is entrained within fluid being discharged from the reservoir fluid discharge communicator 604 of the flow diverter body 600A, and the sump 700 has a volume of at least 0.1 m 3 .
  • the volume is at least 0.5 m 3 .
  • the volume is at least 1.0 m 3 .
  • the volume is at least 3.0 m 3 .
  • a suitable space is provided for collecting relative large volumes of solid debris, from the gas-depleted reservoir fluid being flowed downwardly to the gas-depleted reservoir fluid receiver 608, such that interference by the accumulated solid debris with the production of oil through the system is mitigated.
  • This increases the run-time of the system before any maintenance is required.
  • the propensity for the collected solid debris to interfere with movement of the flow diverter body 600 A within the wellbore 102, such as during maintenance (for example, a workover) is reduced.
  • the reservoir fluid-producing conductor 210 extends from the gas-depleted reservoir fluid discharge communicator 611 to the wellhead 116 for effecting flow communication between the discharge communicator 611 and the earth's surface 106, such as, for example, a collection facility located at the earth's surface 106, and defines a fluid passage 21 OA.
  • reservoir fluid-supplying conductor 206 defines a fluid passage 206 A. The cross-sectional flow area of the fluid passage 210A is greater than the cross-sectional flow area of the fluid passage 206A.
  • the ratio of the cross-sectional flow area of the fluid passage 210A to the cross-sectional flow area of the fluid passage 206A is at least 1.1, such as, for example, at least 1.25, such as, for example, at least 1.5.
  • the reservoir fluid-supplying conductor 206 includes a velocity string 207, and, in some embodiments, for example, the entirety, or the substantial entirety of the reservoir fluid-supplying conductor 206 is a velocity string 207.
  • the velocity string 207 extends from the production string inlet 204.
  • the length of the velocity string 207, measured along the central longitudinal axis of the velocity string is at least 20 feet.
  • the velocity string 207 includes a fluid passage 207A, and the cross-sectional area of the entirety of the fluid passage 207A is less than the cross-sectional area of the entirety of the fluid passage 210A of the fluid-producing conductor 210.
  • the maximum cross-sectional area of the fluid passage 207 A is less than the minimum cross-sectional area of the fluid passage 210A.
  • the maximum cross-sectional area of the fluid passage 207A is less than about 75% (such as, for example 50%) of the minimum cross-sectional area of at least 75% (such as, for example, at least 80%, such as, for example, at least 85%, such as, for example, at least 90%), such as, for example, at least 95%>) of the length of the fluid-supplying conductor 206, as measured along the central longitudinal axis of the fluid-supplying conductor 206.
  • the length of the fluid-supplying conductor 206 is at least 500 feet, such as, for example, at least 750 feet, such as, for example at least 1000 feet.
  • the flow diverter 600 is disposed uphole of a horizontal section 102C of the wellbore 102, such as, in some embodiments, for example, within a vertical section 102 A, or, in some embodiments, for example, within a transition section 102B.
  • the central longitudinal axis of the passage 102CC of the horizontal section 102C 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 passage 102AA of the vertical section 102 A is disposed along an axis that is less than about 20 degrees from the vertical "V”
  • the transition section 102B is disposed between the sections 102 A and 102C.
  • the transition section 102B joins the sections 102 A and 102C.
  • the vertical section 102 A extends from the transition section 102B to the surface 106.
  • the reservoir fluid-supplying conductor 206 extends from the flow diverter 600, in a downhole direction, into the horizontal section 102C, such that the inlet 204 is disposed within the horizontal section 102C.
  • the flow diverter 600 further includes a gas-depleted reservoir fluid conductor bypass 612 for effecting bypassing of the gas-depleted reservoir fluid-conductor 610, by the reservoir fluid being conducted by the reservoir fluid-conductor 603.
  • the bypass 612 is provided for isolating, or substantially isolating, the reservoir fluid, being conducted by the flow diverter 600, from the gas-depleted reservoir fluid, also being conducted by the flow diverter 600, where the gas-depleted reservoir fluid becomes separated from the reservoir fluid after the reservoir fluid has been discharged into the uphole wellbore space 108 from the reservoir fluid discharge communicator 604, and is then conducted (such as, for example, in the downhole direction) to the gas-depleted reservoir fluid receiver 608.
  • the gas-depleted reservoir fluid conductor bypass 612 includes a plurality of fluid conduits 615.
  • Each one of the fluid conduits 615 independently, includes a respective fluid passage 615 A.
  • the plurality of fluid conduits 615 are configured for receiving reservoir fluid from the reservoir fluid receiver 602 and conducting the received reservoir fluid for supply to the reservoir fluid discharge communicator 608.
  • the fluid conduits 615 form at least part of the reservoir fluid conductor 603, and the fluid passages 615 A form part of a network of the reservoir fluid conductor passages 603 A.
  • each one of the fluid conduits 615 independently, includes a tube.
  • the tube is cylindrical or substantially cylindrical (see Figure 4).
  • the tube is not required to be cylindrical or substantially cylindrical.
  • the tube has a kidney-shaped cross-section (see Figure 9).
  • the fluid passage, defined by the tube is cylindrical or substantially cylindrical.
  • the fluid passage, defined by the tube has a kidney-shaped cross-section along its longitudinal axis.
  • each one of the fluid conduits 615 independently, is in the form of a tube.
  • the central longitudinal axes of the fluid conduits 615 are parallel, or substantially parallel, to one another.
  • the gas-depleted reservoir fluid receiver 608 includes one or more spaces 608 A between the fluid conduits 615.
  • each one of the fluid conduits 615 independently, has a length, measured along its central longitudinal axis, of at least two (2) feet, such as, for example, at least three (3) feet, such as, for example, at least four (4) feet, such as, for example, at least five (5) feet.
  • the gas-depleted reservoir fluid conductor bypass 612 includes a downhole connector 605 and an uphole connector 606 for mounting the fluid conduits 615 to the flow diverter body 600.
  • the connectors 605, 606 are in the form of a ring.
  • alignment rods 6121 extend between, and connect, the uphole and downhole connectors 605, 606.
  • the downhole connector 605 includes a plurality of bypass inlet ports 612A.
  • Each one of the bypass inlet ports 612A is respective to a one of the fluid conduits 615, such that each one of the fluid conduits 615, independently, is disposed in flow communication with a respective one of the bypass inlet ports 612A.
  • the reservoir fluid receiver 602 is disposed relative to the bypass inlet ports 612A such that reservoir fluid being received by the port 602 is conducted to the bypass inlet ports 612A via a fluid passage 620 A of a downhole fluid conductor 620.
  • the bypass inlet ports 612A are disposed for receiving fluid being conducted through the downhole fluid conductor 620.
  • the downhole fluid conductor 620 forms a portion of the reservoir fluid receiver 602.
  • the downhole connector 605 is configured for distributing reservoir fluid, received by its bypass inlet ports 612A, to the fluid conduits 615, with effect that the received reservoir fluid is conducted via the fluid conduits 615 to the reservoir fluid discharge communicator 604 via the uphole connector 606.
  • the uphole connector 606 includes a plurality of bypass outlet ports 612B.
  • Each one of the bypass outlet ports 612B is respective to a one of the fluid conduits 615, such that each one of the fluid conduits 615, independently, is disposed in flow communication with a respective one of the bypass outlet ports 612B.
  • Each one of the bypass outlet ports 612B independently, is configured for receiving reservoir fluid from the reservoir fluid receiver 602, via the respective fluid conduit 615, the bypass inlet port 612A that is respective to the respective fluid conduit 615, and the downhole fluid conductor 620.
  • the bypass outlet ports 612B are configured to discharge reservoir fluid, being conducted by the conduits 615 from the inlet ports 612A.
  • the flow diverter body 600A includes an uphole fluid conductor 622 having a fluid passage 622A for conducting the reservoir fluid, that is being discharged from the bypass outlet ports 612A, to the reservoir fluid discharge communicator port
  • bypass outlet ports 612B are fluidly coupled to the reservoir fluid discharge communicator 604, and, therefore, the uphole wellbore space 108.
  • the uphole fluid conductor 622 is configured to effect aggregation of reservoir fluid being discharged from the bypass 612 via the bypass outlet ports 612B. In such embodiments, for example, the uphole fluid conductor 622 forms a portion of the reservoir fluid discharge communicator 604.
  • the reservoir fluid is conducted through a fluid passage 622A defined within the uphole fluid conductor 622 with effect that the flow characteristics of the conducted reservoir fluid are attenuated.
  • the uphole fluid conductor 622 is contoured with effect that the reservoir fluid being discharged from the reservoir fluid discharge communicator 604, into the uphole wellbore space 108, has a vortical flow component.
  • the uphole fluid conductor 622 is contoured for urging vortical flow of the reservoir fluid being discharged into the uphole wellbore space 108.
  • a plurality of fins 624 extend into the fluid passage 622A from the interior wall of the uphole fluid conductor 622, and the above-described attenuation of the flow characteristics is effected by the fins 624.
  • the plurality of fluid conduits 615 extend from the bypass inlet ports 612A to the bypass outlet ports 612B.
  • each one of the fluid conduits 615 independently, is welded at one end to the downhole connector 605 such that alignment with a respective one of the bypass inlet ports 612A is effected, and is welded at a second opposite end to the uphole connector 606 such that alignment with a respective one of the bypass outlet ports 612B is effected.
  • the welding effects definition of sealed interfaces between the ports 612A, 615B and the conduits 615.
  • the flow diverter 600 is mounted to a pump assembly 301 that includes the pump 300.
  • the pump assembly 301 also includes a pump intake
  • the pump intake receiver 303 is disposed in flow communication with the pump 300, and, more specifically, the pump suction 302.
  • the gas-depleted reservoir fluid receiver 608 is disposed in flow communication with the pump intake receiver 303 via at least the gas- depleted reservoir fluid-conductor 610, for supplying the gas-depleted reservoir fluid to the pump suction 302.
  • an axis that is normal to the pump intake receiver 303 is transverse (such as, for example, orthogonal, or substantially orthogonal) to the central longitudinal axis 301 A of the pump assembly 301.
  • the pump intake 306 and the fluid conduits 615 are co-operatively configured such that conduction of the gas-depleted reservoir fluid from the intermediate fluid passage 112 to the pump intake receiver 303 of the pump intake 306 includes conduction of the gas-depleted reservoir fluid through the one or more spaces 608A between the fluid conduits 615 and through the conductor 610.
  • the flow diverter 600 includes first and second spaced apart couplings, such as clamps 616, 618.
  • Each one of the downhole and uphole clamps 616, 618, independently, is configured for coupling to the pump assembly 301 by clamping onto the pump assembly 301.
  • each one of the downhole and uphole clamps 616, 618, independently, is configured for coupling to a pump intake 306 of the pump assembly 301, the pump intake 306 including the pump intake receiver 603.
  • the downhole clamp 616 is configured for coupling to a neck that joins a motor 308 to the pump intake 306.
  • the uphole clamp 618 is configured for coupling to a neck that joins the pump intake 306 to the pump 300.
  • the pump intake 306 is disposed between the downhole and uphole clamps 616, 618.
  • the downhole clamp 616 includes two downhole clamp sections 616A, 616B that are coupled by pins 616C which extend from one of the sections and are friction fitted into apertures provided in the other one of the sections.
  • the interface between the clamp sections 616A, 616B is sealed with a bead of room temperature vulcanization
  • the clamp sections 616A, 616B are co-operatively configured such that, while a neck, that is joining the motor 308 to the pump intake 306, is disposed between the clamp sections 616A, 616B, and the clamp sections 616A, 616B are drawn together for effecting coupling of the coupling sections 616A, 616B, upon coupling of the clamp sections 616A, 616B to obtain the downhole clamp 616, the neck becomes clamped between the clamp sections 616A, 616B.
  • the uphole clamp 618 includes two uphole clamp sections 618 A, 618B that are coupled by pins 618C which extend from one of the sections and are friction fitted into apertures provided in the other one of the sections.
  • the interface between the clamp sections 618 A, 618B is sealed with a bead of RTV silicone sealant.
  • the clamp sections 618 A, 618B are co-operatively configured such that, while a neck, that is joining the pump intake 306 to the pump 300, is disposed between the clamp sections 618 A, 618B, and the clamp sections 618 A, 618B are drawn together for effecting coupling of the coupling sections 618 A, 618B, upon coupling of the clamp sections 618 A, 618B to obtain the uphole clamp 618, the neck becomes clamped between the clamp sections 618 A, 618B.
  • the downhole clamp 616 is defined by the downhole connector 605
  • the uphole clamp 618 is defined by the uphole connector 606.
  • the downhole fluid conductor 620 is coupled to the downhole connector 605.
  • the downhole connector 605 includes the combination of a downhole mounting plate 605A and a downhole retaining ring 605B.
  • the downhole fluid conductor 620 is connected to a downhole retaining ring 605B (see Figures 2B and 2E) via one or more fasteners 6051, such as pins.
  • the downhole retaining ring 605B includes recesses 6052 for receiving bolts 306 A that are integral to the pump intake assembly 306.
  • the downhole retaining ring 605B is disposed downhole of the mounting plate 605A in an interference fit relationship between the plate 605A and a co-operating portion 301 A of the pump assembly 301, with effect that the downhole retaining ring 605B (and, therefore, the fluid conductor 620) is retained relative to the pump assembly 301.
  • the plate 605A is disposed in an interference fit relationship between the retaining ring 605B and a co-operating portion 30 IB of the pump assembly 301, which, in combination with its coupling to a neck of the pump assembly 301, is with effect that the plate 605A is retained relative to the pump assembly 301.
  • a sealed interface 6201 is provided between the downhole fluid conductor 620 and the downhole clamp 616, for preventing, or substantially preventing, flow communication between the downhole fluid conductor 620 and the wellbore via the space between the downhole fluid conductor 620 and the plate 605 A.
  • the sealed interface 6201 is defined by a bead of RTV silicone sealant.
  • the downhole connector 605 integrates the functionalities of both of the plate 605 A and the retaining ring 605B into a single unitary body.
  • the downhole connector 605 is coupled to the downhole fluid conductor 620 via fasteners 6051 in the form of set screws, that are threaded into receiving apertures defined in the downhole connector 605, and the sealed interface 6201 is established by a sealing member 6056 (such as, for example, an o-ring) that is retained within a groove 6052 disposed within the external surface 6053 of the downhole connector 605.
  • a sealing member 6056 such as, for example, an o-ring
  • the downhole fluid conductor 620 is in the form of a downhole shroud 621.
  • the downhole shroud 621 extends downhole from the downhole connector 605 and is integrated to the reservoir fluid-supplying conductor 206 via a cross-over sub 623.
  • the uphole fluid conductor 622 is coupled to the uphole connector 606.
  • the uphole connector 606 includes the combination of an uphole mounting plate 606A and an uphole retaining ring 606B.
  • the uphole fluid conductor 622 is connected to an uphole retaining ring 606B via one or more fasteners 6061, such as pins.
  • the uphole retaining ring 606B is disposed uphole of the plate 606A in an interference fit relationship between the plate 606A and a co-operating portion 301C of the pump assembly 301, with effect that the uphole retaining ring 606B (and, therefore, the fluid conductor
  • a sealed interface 6221 is provided between the uphole fluid conductor 622 and the uphole plate 606 A, for preventing, or substantially preventing, flow communication between the uphole fluid conductor and the wellbore via the space between the uphole fluid conductor 622 and the uphole plate 606A.
  • the sealed interface 6221 is defined by a bead of RTV silicone sealant.
  • the uphole connector 606 integrates the functionalities of both of the plate 606A and the retaining ring 606B into a single unitary body.
  • the uphole connector 606 is coupled to the uphole fluid conductor 622 via fasteners 6061, in the form of set screws, that are threaded into receiving apertures defined in the uphole connector 606, and the sealed interface 6221 is established by a sealing member 6066 (such as, for example, an o-ring) that is retained within a groove 6062 disposed within the external surface 6063 of the uphole connector 606.
  • the uphole fluid conductor 622 is in the form of an uphole shroud 626 that is extending uphole from the uphole connector 605.
  • the fins 624 are welded to the interior wall 626B of the uphole shroud 626.
  • the fins 624 are disposed below a terminal edge 626C of the uphole shroud 626, which defines the outlet of the uphole fluid conductor 622.
  • the fins 624 are disposed below the terminal edge 626C of the uphole shroud 626 by a minimum distance of at least six (6) inches, such as, for example, at least nine (9) inches, such as, for example, at least 12 inches.
  • the central longitudinal axes 615B of the fluid conduits 615 are parallel, or substantially parallel, to one another, and, in some of these embodiments, are also parallel to, or substantially parallel to, the central longitudinal axis 301 A of the pump assembly 301.
  • the fluid conduits 615 are disposed eccentrically about the pump intake 306 of the pump assembly 301. In some embodiments, for example, this configuration enables the provision of increased cross-sectional area within the intermediate fluid passage 112, without trading off cross-sectional flow area that is otherwise available for conducting fluids within the flow diverter 600.
  • the pump assembly 301 extends through the downhole connector 605.
  • the downhole connector 605 defines a pump assembly aperture 6050 through which the pump assembly 301 is configured to extend.
  • the pump assembly 301 extends into a space 621 A defined by the downhole shroud 621, and, in some embodiments, for example, the extension of the pump assembly 301 into the space 621 is such that the motor 308 is disposed within the space 621.
  • the downhole shroud 626 extends about the pump assembly 301.
  • the central longitudinal axis of the downhole shroud 621 is parallel to, or substantially parallel to, the central longitudinal axis of the pump assembly 301.
  • the central longitudinal axis of the downhole shroud 626 is disposed in alignment, or substantial alignment, with the central longitudinal axis 301 A of the pump assembly 301.
  • the uphole fluid conductor 622 includes a fluid passage 622A disposed between the downhole shroud 626 and the pump assembly 301.
  • a sealed interface is defined between the pump assembly 301 and the downhole connector 605, with effect that flow communication through the aperture 6050, between the pump assembly 301 and the downhole connector 605, is sealed or substantially sealed.
  • the sealed interface is effected by a sealing member 6057 (such as, for example, an o-ring that is retained within a groove 6053 defined within an inner surface 6054 of the connector 605 - see Figures 12 and 13) disposed between the pump assembly 301 and the downhole connector.
  • the sealed interface is defined by a bead of RTV silicone sealant.
  • the pump assembly 301 extends through the uphole connector 606.
  • the uphole connector 606 includes a pump assembly aperture 6060 through which the pump assembly 301 is configured to extend.
  • the uphole shroud 626 extends about the pump assembly 301. In some embodiments, for example, the uphole shroud 626 extends about at least a portion of the pump 300 of the pump assembly 301. In some embodiments, for example, the central longitudinal axis of the uphole shroud 626 is parallel to, or substantially parallel to, the central longitudinal axis of the pump assembly 301. In some embodiments, for example, the central longitudinal axis of the uphole shroud 626 is disposed in alignment, or substantial alignment, with the central longitudinal axis of the pump assembly 301. In this respect, the uphole fluid conductor 622 is defined at least by the upper shroud 626 and the pump assembly 301, and the fluid passage 622 A is disposed between the upper shroud 626 and the pump assembly 301.
  • a sealed interface is defined between the pump assembly 301 and the uphole connector 606, with effect that flow communication through the aperture 6060, between the pump assembly 301 and the uphole connector 606, is sealed or substantially sealed.
  • the sealed interface is effected by a sealing member 6067 (such as, for example, an o-ring that is retained within a groove 6063 defined within an inner surface 6064 of the uphole connector 606 - see Figures 12 and 13) disposed between the pump assembly 301 and the uphole connector 606.
  • the sealed interface is defined by a bead of RTV silicone sealant.
  • the central longitudinal axis of the aperture 6050 is coincident, or substantially coincident, with the central longitudinal axis of the aperture 6061.
  • each one of the central longitudinal axes of the fluid conduits 615 independently, is parallel to, or substantially parallel to, the central longitudinal axis of the aperture 6050, the central longitudinal axis of the aperture 6060, or both.
  • the pump assembly 301 includes the pump 300, the pump intake receiver 303, and the motor 308, where the pump intake receiver 303 is disposed between the pump 300 and the motor 308, and the pump assembly 301 extends through the gas-depleted reservoir fluid conductor bypass 612 such that: (i) the pump 300 is disposed externally of the bypass 612, (ii) the pump intake receiver 303 is fluidly coupled to the gas-depleted reservoir fluid receiver 608, and (iii) the motor 308 is disposed externally of the bypass 612, while the pump assembly 301 is sealingly, or substantially sealingly, disposed relative to the gas-depleted reservoir fluid conductor bypass 612 such that bypassing of the pump assembly inlet receiver 303 by gas-depleted reservoir fluid within the gas-depleted reservoir fluid conductor 610, via space between the pump assembly 301 and the gas-depleted reservoir fluid conductor bypass 612, is prevented or substantially prevented.
  • the pump motor 308 is coupled to the pump 300, such as by a shaft, for effecting operation of the pump 300.
  • the pump motor 308 is electrically coupled to a power and voltage source disposed at the surface 106 via an electrical conductor 310, such as, for example, an electrical cable.
  • the electrical conductor 310 extends through the downhole and uphole connectors 605, 606 for effecting electrical connection to the motor 308.
  • the downhole connector 605 includes a downhole electrical conductor aperture 6050A through which the electrical conductor 310 is configured to extend.
  • a sealed interface is defined between the electrical conductor 310 and the downhole connector 605, with effect that flow communication through the aperture 6050A, between the electrical conductor 310 and the downhole connector 605, is sealed or substantially sealed.
  • the sealed interface is effected by a sealing member (such as, for example, an o- ring, suitably retained within a groove defined within an inner surface of the connector 605) disposed between the electrical conductor 310 and the downhole connector 605).
  • the sealed interface is defined by a bead of RTV silicone sealant.
  • the uphole connector 606 includes an uphole electrical conductor aperture 6060 A through which the electrical conductor 310 is configured to extend.
  • a sealed interface is defined between the electrical conductor and the uphole connector 606, with effect that flow communication through the aperture 6060A, between the electrical conductor 310 and the uphole connector 606, is sealed or substantially sealed.
  • the sealed interface is effected by a sealing member disposed (such as, for example, an o-ring retained within a groove defined within an inner surface of the uphole connector 606) between the electrical conductor 310 and the uphole connector 606.
  • the sealed interface is defined by a bead of RTV silicone sealant.
  • the central axis of the downhole electrical conductor aperture 6050A is aligned, or substantially aligned, with the central axis of the uphole electrical conductor aperture 6060A.
  • the pump assembly 301 includes the pump 300, the pump intake receiver 303, and the motor 308, where the pump intake receiver 303 is disposed between the pump 300 and the motor 308, and the pump assembly 301 extends through the gas- depleted reservoir fluid conductor bypass 612 as described above, and an electrical conductor 310 is further provided for effecting electrical coupling of the motor 308 to a power and voltage source disposed at the surface 106.
  • the electrical conductor 310 also extends through the gas- depleted reservoir fluid conductor bypass 612, and the electrical conductor 310 is sealingly, or substantially sealingly, disposed relative to the gas-depleted reservoir fluid conductor bypass 612 such that bypassing of the pump intake receiver 303 by gas-depleted reservoir fluid within the gas-depleted reservoir fluid conductor 610, via space between the electrical conductor 310 and the gas-depleted reservoir fluid conductor bypass 612, is prevented or substantially prevented.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Filling Or Discharging Of Gas Storage Vessels (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)

Abstract

Un système de production de fluide de réservoir pour produire un fluide de réservoir à partir d'une formation souterraine est prévu pour atténuer une interférence de gaz par séparation en fond de trou d'une phase gazeuse des fluides de réservoir, tout en atténuant l'entraînement d'un matériau hydrocarboné liquide dans la phase gazeuse.
PCT/CA2018/050077 2017-01-23 2018-01-23 Systèmes pour améliorer la séparation en fond de trou de gaz de liquides tout en produisant un fluide de réservoir à l'aide d'une pompe électrique submersible WO2018132927A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201762449258P 2017-01-23 2017-01-23
US62/449,258 2017-01-23

Publications (1)

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WO2018132927A1 true WO2018132927A1 (fr) 2018-07-26

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PCT/CA2018/050077 WO2018132927A1 (fr) 2017-01-23 2018-01-23 Systèmes pour améliorer la séparation en fond de trou de gaz de liquides tout en produisant un fluide de réservoir à l'aide d'une pompe électrique submersible

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AR (1) AR110772A1 (fr)
WO (1) WO2018132927A1 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11566507B2 (en) 2020-08-26 2023-01-31 Saudi Arabian Oil Company Through-tubing simultaneous gas and liquid production method and system

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140332219A1 (en) * 2013-05-07 2014-11-13 Halliburton Energy Services, Inc. Intrawell Fluid Injection System and Method
US20150075772A1 (en) * 2013-09-13 2015-03-19 Triaxon Oil Corp. System and Method for Separating Gaseous Material From Formation Fluids
US20160265332A1 (en) * 2013-09-13 2016-09-15 Production Plus Energy Services Inc. Systems and apparatuses for separating wellbore fluids and solids during production

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20140332219A1 (en) * 2013-05-07 2014-11-13 Halliburton Energy Services, Inc. Intrawell Fluid Injection System and Method
US20150075772A1 (en) * 2013-09-13 2015-03-19 Triaxon Oil Corp. System and Method for Separating Gaseous Material From Formation Fluids
US20160265332A1 (en) * 2013-09-13 2016-09-15 Production Plus Energy Services Inc. Systems and apparatuses for separating wellbore fluids and solids during production

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11566507B2 (en) 2020-08-26 2023-01-31 Saudi Arabian Oil Company Through-tubing simultaneous gas and liquid production method and system

Also Published As

Publication number Publication date
AR110772A1 (es) 2019-05-02

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