US20190301272A1 - Systems for downhole separation of gases from liquids having interchangeable fluid conductors - Google Patents

Systems for downhole separation of gases from liquids having interchangeable fluid conductors Download PDF

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Publication number
US20190301272A1
US20190301272A1 US16/268,113 US201916268113A US2019301272A1 US 20190301272 A1 US20190301272 A1 US 20190301272A1 US 201916268113 A US201916268113 A US 201916268113A US 2019301272 A1 US2019301272 A1 US 2019301272A1
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United States
Prior art keywords
assembly
reservoir fluid
wellbore
counterpart
gas
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
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US16/268,113
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English (en)
Inventor
Jeff Saponja
Rob Hari
Tim Keith
Trystan WALL
Dave KIMERY
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Heal Systems Inc
Schlumberger Canada Ltd
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Heal Systems LP
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Priority to US16/268,113 priority Critical patent/US20190301272A1/en
Publication of US20190301272A1 publication Critical patent/US20190301272A1/en
Assigned to SCHLUMBERGER CANADA LIMITED, HEAL SYSTEMS INC. reassignment SCHLUMBERGER CANADA LIMITED MERGER (SEE DOCUMENT FOR DETAILS). Assignors: HEAL SYSTEMS LP
Assigned to SCHLUMBERGER CANADA LIMITED reassignment SCHLUMBERGER CANADA LIMITED MERGER (SEE DOCUMENT FOR DETAILS). Assignors: HEAL SYSTEMS INC.
Abandoned legal-status Critical Current

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    • 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
    • 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

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 production assembly for producing reservoir fluid from a subterranean formation via a wellbore that is lined with a wellbore string, wherein the wellbore includes a wellbore space, the wellbore space includes a downhole wellbore space and an uphole wellbore space, and the uphole wellbore space is disposed uphole relative to the downhole wellbore space, wherein the assembly includes:
  • a reservoir fluid production assembly for producing reservoir fluid from a subterranean formation via a wellbore that is lined with a wellbore string, wherein the wellbore includes a wellbore space, the wellbore space includes a downhole wellbore space and an uphole wellbore space, and the uphole wellbore space is disposed uphole relative to the downhole wellbore space, wherein the assembly includes:
  • a process for producing reservoir fluid from a subterranean formation comprising:
  • a reservoir fluid production assembly for producing reservoir fluid from a subterranean formation via a wellbore that is lined with a wellbore string, wherein the wellbore includes a wellbore space, the wellbore space includes a downhole wellbore space and an uphole wellbore space, and the uphole wellbore space is disposed uphole relative to the downhole wellbore space, wherein the assembly includes:
  • a reservoir fluid production assembly for producing reservoir fluid from a subterranean formation via a wellbore that is lined with a wellbore string, wherein the wellbore includes a wellbore space, the wellbore space includes a downhole wellbore space and an uphole wellbore space, and the uphole wellbore space is disposed uphole relative to the downhole wellbore space, wherein the assembly includes:
  • FIG. 1A is a schematic illustration of an embodiment of a reservoir fluid production assembly disposed within a wellbore
  • FIG. 1B is a schematic illustration of an embodiment of a flow diverter of embodiments of the system of the present disclosure
  • FIG. 2A is a schematic illustration of the flow diverter of the present disclosure
  • FIG. 2B is a schematic illustration of the flow diverter of the present disclosure
  • FIG. 3 is a side elevation view of the exterior of flow diverter
  • FIG. 4 is a sectional elevation view of the flow diverter in FIG. 3 taken along lines G-G, showing the flow diverter established by the disposition of a flow diverter-effecting insert within the passageway of the insert-receiving part, and with the flow diverter-effecting insert releasably coupled by a lock mandrel to the insert-receiving part;
  • FIG. 5 is an enlarged view of Detail “A” in FIG. 4 ;
  • FIG. 6A is a side elevation view of the insert-receiving part of a flow diverter
  • FIG. 6B is a sectional elevation view of the insert-receiving part illustrated in FIG. 6A , taken along lines A-A;
  • FIG. 6C is an axial view taken along lines B-B in FIG. 6A ;
  • FIG. 6D is an axial view taken along lines C-C in FIG. 6A ;
  • FIG. 6E is an axial view taken along lines D-D in FIG. 6A ;
  • FIG. 7 is an elevation view of one side of the flow diverter-effecting insert
  • FIG. 8 is a sectional elevation view of the flow diverter-effecting insert, taken along lines F-F in FIG. 7 ;
  • FIG. 9 is a schematic illustration of the flowpaths within the flow diverter illustrated in FIGS. 4 and 5 .
  • FIG. 10 is a schematic illustration of an embodiment of a system of the present disclosure, showing a flow diverter body that is comprised of an insert-receiving part and a flow diverter-effecting insert part;
  • FIG. 11 is a schematic illustration of the system in FIG. 10 , after the pump and the flow diverter-effecting insert having been removed from the wellbore.
  • 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 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.
  • the term “horizontal”, when used to describe a wellbore portion refers to a horizontal or highly deviated wellbore portion as understood in the art, such as, for example, a wellbore portion having a longitudinal axis that is between about 70 and about 110 degrees from vertical.
  • 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. In some embodiments, for example, 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 .
  • 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.
  • a production 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 production assembly 10 includes a reservoir fluid-supplying conductor 12 and an uphole-disposed reservoir fluid-conducting assembly 14 .
  • the reservoir fluid-supplying conductor 12 is in the form of tubing, such as coiled tubing, or a substantial portion of the reservoir fluid-supplying conductor 12 is in the form of tubing, such as coiled tubing.
  • the reservoir fluid-supplying conductor 12 is in the form of a hose, such as, for example, a braided hose, or a substantial portion of the reservoir fluid-supplying conductor 12 is in the form of a hose, such as, for example, a braided hose.
  • the reservoir fluid-supplying conductor 12 is releasably retained relative to the reservoir fluid-supplying conductor 12 .
  • the uphole-disposed reservoir fluid-conducting assembly 14 defines a passage 14 A.
  • the reservoir fluid-supplying conductor 12 is configured for receiving and conducting reservoir fluid, received within the wellbore 102 from the subterranean formation, to the uphole-disposed reservoir fluid-conducting assembly 14 .
  • the uphole-disposed reservoir fluid-conducting assembly 14 includes a pump 300 for receiving reservoir fluid and, through mechanical action, pressurizing reservoir fluid such that the pressurized reservoir fluid is conducted uphole, via a reservoir fluid-producing conductor 210 , to an outlet 208 disposed at the surface 106 , and thereby effect production of the reservoir fluid.
  • the reservoir fluid being conducted uphole through the wellbore 102 , via the assembly 10 may be additionally energized by supplemental means, including by gas-lift.
  • the pump 300 is a sucker rod pump.
  • Other suitable pumps 300 include screw pumps, electrical submersible pumps, and jet pumps.
  • 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 uphole-disposed reservoir fluid-conducting assembly 14 includes a flow diverter 600 for receiving reservoir fluid flow from the reservoir fluid-supplying conductor 12 , effecting removal of at least a fraction of the gaseous material from the received reservoir fluid such that a gas-depleted reservoir fluid is obtained, and conducting the gas-depleted reservoir fluid to the pump.
  • the flow diverter 600 is disposed uphole relative to the reservoir fluid-supplying conductor 12 and is fluid coupled to the reservoir fluid-supplying conductor 12 for receiving reservoir fluid being conducted by the reservoir fluid-supplying conductor 12 .
  • the flow diverter is also disposed downhole relative to the pump 300 and is fluidly coupled to the pump suction 302 for supplying the pump 300 with the gas-depleted reservoir fluid.
  • 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 600 B and an assembly counterpart 600 C.
  • the wellbore string 113 defines the wellbore string counterpart 600 B
  • the assembly 10 defines the assembly counterpart 600 C.
  • 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 112 X of the wellbore 102 , with effect that a gas-depleted reservoir fluid is separated from the reservoir fluid within the reservoir fluid separation space 112 X 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 assembly counterpart 600 C includes a fluid diverter body 600 A.
  • the flow diverter body 600 A 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 600 A 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 reservoir fluid-supplying conductor 12 from its inlet 204 .
  • the reservoir fluid-supplying conductor 12 extends to the receiver 602 .
  • the reservoir fluid-supplying conductor 12 is fluidly coupled to the inlet 204 .
  • the reservoir fluid receiver 602 includes one or more ports 602 A for receiving reservoir fluid being conducted by the fluid-supplying conductor 12 .
  • the flow diverter body 600 A 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 600 A relative to the reservoir fluid receiver 602 .
  • the reservoir fluid discharge communicator 604 includes one or more ports 604 A.
  • the flow diverter body 600 A 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
  • 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 600 A relative to the gas-depleted reservoir fluid receiver 608 .
  • the gas-depleted reservoir fluid receiver 608 includes one or more ports 608 A.
  • the flow diverter body 600 A also includes a gas-depleted reservoir fluid conductor 610 that defines a gas-depleted reservoir fluid-conducting passage 610 A 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 600 A 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 610 A 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 604 B), 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 600 A is disposed.
  • the reservoir fluid discharge communicator 604 is oriented such that, a ray (see, for example ray 604 B), 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 604 B along a vertical axis).
  • the flow diverter body 600 A 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 600 A 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 600 C 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 uphole 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 uphole 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 uphole 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 240 A disposed between the wellbore string 113 and the polished bore receptacle 114 ), and (ii) a sealed, or substantially sealed, disposition of a flow diverter body portion 601 relative to the polished bore receptacle 114 .
  • 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 flow diverter body portion 601 relative to the polished bore receptacle 114 is effected by a latch seal assembly.
  • a suitable latch seal assembly is a Weatherford' Thread-Latch Anchor Seal AssemblyTM.
  • the sealed, or substantially sealed, disposition of the flow diverter body portion 601 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 flow diverter body portion 601 relative to the polished bore receptacle 114 is disposed in an interference fit with the polished bore receptacle.
  • the flow diverter body portion 601 is landed or engaged or “stung” within the polished bore receptacle 114 .
  • the flow diverter body portion 601 defines a passage, and the reservoir fluid-supplying conductor 12 is disposed within the passage.
  • the above-described disposition of the wellbore sealed interface 500 provide for conditions which minimize solid debris accumulation in the joint between the flow diverter body portion 601 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 102 A is disposed at an angle “ ⁇ ” 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 “ ⁇ ” 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-supplying conductor 12 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 12 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 :
  • At least a portion of the space within the intermediate wellbore space 112 , between the reservoir fluid discharge communicator 604 and the gas-depleted reservoir fluid receiver 608 defines at least a portion of the gas-depleted reservoir fluid-conducting passage 6004 .
  • 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 600 A 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 1121 X of the intermediate wellbore passage 112 , the uphole-disposed space 1121 X being disposed uphole relative to the reservoir fluid discharge communicator 604 .
  • the reservoir fluid separation space 112 X includes the uphole-disposed space 1121 X.
  • a flow diverter body-defined intermediate wellbore passage portion 1121 Y 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 1121 Y defines at least a portion of the gas-depleted reservoir fluid-conducting passage 6004 .
  • the space between the flow diverter body 600 A and the wellbore string 113 , within which the flow diverter body-defined intermediate wellbore passage portion 1121 Y 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 1121 Y.
  • at least a portion of the reservoir fluid separation space 112 X is co-located with at least a portion of the flow diverter body-defined intermediate wellbore passage portion 1121 Y.
  • 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 1121 X and the flow diverter body-defined intermediate wellbore passage portion 1121 Y.
  • the reservoir fluid is discharged from the reservoir fluid discharge communicator 604 into the uphole wellbore space 1121 X, 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 1121 X, through the flow diverter body-defined intermediate wellbore passage portion 1121 Y, and to the gas-depleted reservoir fluid receiver 608 .
  • the uphole-disposed space 1121 X is merged with the flow diverter body-defined intermediate wellbore passage portion 1121 Y
  • the reservoir fluid separation space 112 X 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 112 X 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 112 X 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 112 X to the maximum cross-sectional flow area of the fluid passage 12 A defined by the reservoir fluid-supplying conductor 12 is at least about 1.5.
  • the flow diverter body 600 A further includes a shroud 620 co-operatively disposed relative to the gas-depleted reservoir fluid receiver 608 such that the shroud 620 projects below the gas-depleted reservoir fluid receiver 608 and interferes with conduction of the gas-depleted reservoir fluid to the gas-depleted reservoir fluid receiver 608
  • the shroud 620 provides increased residence time for separation of gaseous material within the intermediate fluid passage 112 .
  • the shroud 620 projects below the gas-depleted reservoir fluid receiver 608 , such that gas-depleted reservoir fluid being conducted downhole to the gas-depleted reservoir fluid receiver 608 is directed below the gas-depleted reservoir fluid receiver 608 by the shroud 620 .
  • the space between: (a) the gas-depleted reservoir fluid receiver 608 of the flow diverter body 600 A, 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 600 A, 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 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 210 A.
  • the length of the fluid-supplying conductor 12 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 102 C 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 102 B.
  • the central longitudinal axis of the passage 102 CC of the horizontal section 102 C 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 102 AA 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 102 B is disposed between the sections 102 A and 102 C.
  • the transition section 102 B joins the sections 102 A and 102 C.
  • the vertical section 102 A extends from the transition section 102 B to the surface 106 .
  • the reservoir fluid-supplying conductor 12 extends from the flow diverter 600 , in a downhole direction, into the horizontal section 102 C, such that the inlet 204 is disposed within the horizontal section 102 C.
  • the assembly 10 is configured such that, while the assembly 10 is disposed within the wellbore 10 , the reservoir fluid-supplying conductor 12 is releasable from the retention relative to the uphole-disposed reservoir fluid-conducting assembly 14 and replaceable with another reservoir fluid-supplying conductor 12 having a smaller minimum cross-sectional flow area.
  • parts for assembly to obtain the production assembly 10 include first, second, third, and fourth assembly counterparts 10 A, 10 B, 10 C, and 10 D.
  • the assembly-defined flow diverter counterpart 600 C includes first and second assembly-defined flow diverter counterparts 6002 , 6004 .
  • the first assembly counterpart 10 A includes the first assembly-defined flow diverter counterpart 6002
  • the second assembly counterpart 10 B includes the second assembly-defined flow diverter counterpart 6004 .
  • the third assembly counterpart 10 C includes a reservoir fluid-supplying conductor 12 that is a first reservoir fluid-supplying conductor 12
  • the first reservoir fluid-supplying conductor 12 defines a fluid passage having a minimum cross-sectional flow area.
  • the fourth assembly counterpart 10 D includes a reservoir fluid-supplying conductor 12 that is a second reservoir fluid-supplying conductor 12 , and the second reservoir fluid-supplying conductor 12 defines a fluid passage having a minimum cross-sectional flow area that is less than the minimum cross-sectional flow area of the fluid passage defined by the first reservoir fluid-supplying conductor 12 .
  • Each one of the second, third, and fourth assembly counterparts 10 B, 10 C, and 10 D is configured for releasable retention relative to the first assembly counterpart 10 A
  • the first, second, third, and fourth assembly counterparts 10 A, 10 B, 10 C, 10 D are co-operatively configured such that:
  • the third assembly counterpart 10 C is connected to the second assembly counterpart 10 B, such that release of the third assembly counterpart 10 C from retention relative to the first assembly counterpart 10 A is effected by the release of the second assembly counterpart 10 B relative to the first assembly counterpart 10 A.
  • both of the second and third assembly counterparts 10 B, 10 C become displaceable relative to the first assembly counterpart for defeating occlusion of a workstring-conducting passageway 626 such that the fourth assembly counterpart 10 D is conductible through the workstring-conducting passageway 626 for releasable coupling to the first assembly counterpart 10 A.
  • the releasable retention of the second assembly counterpart 10 B relative to the first assembly counterpart 10 A is independent of the releasable retention of the third assembly counterpart 10 C relative to the first assembly counterpart 10 A.
  • each one of the first and second assembly counterparts 10 B, 10 C, independently, is configured for releasable retention relative to the first assembly counterpart 10 A.
  • first, second, third, and fourth assembly counterparts 10 A, 10 B, 10 C, 10 D are co-operatively configured such that:
  • the preventing of the interchangeability of the third assembly counterpart 10 C with the fourth assembly counterpart 10 D includes preventing of release of the retention of the third assembly counterpart 10 C relative to the first assembly counterpart 10 A
  • the defeating of the preventing of the interchangeability of the third assembly counterpart 10 C with the fourth assembly counterpart 10 D includes defeating of the preventing of release of the retention of the third assembly counterpart 10 C relative to the first assembly counterpart 10 A such that the third assembly counterpart 10 C becomes releasable from the retention relative to the first assembly counterpart 10 A for effecting displacement of the third assembly counterpart 10 C relative to the first assembly counterpart such that occlusion to the workstring-conducting passageway 626 by the third assembly counterpart 10 C is defeated with effect that the fourth assembly counterpart 10 D is conductible through the workstring-conducting passageway 626 for effecting releasable coupling of the fourth assembly counterpart 10 D to the first assembly counterpart 10 A such that an assembly 10 is obtained that includes the second reservoir fluid-supplying conductor 12 .
  • the minimum cross-sectional flow area of the fluid passage defined by second reservoir fluid-supplying conductor 12 is less than the minimum cross-sectional flow area of the fluid passage defined by the first reservoir fluid-supplying conductor 12 .
  • the ratio of the minimum cross-sectional flow area of the fluid passage defined by the second reservoir fluid-supplying conductor 12 to the minimum cross-sectional flow area of the fluid passage defined by the second reservoir fluid-supplying conductor 12 is less than about 0.9, such as, for example, less than about 0.8, such as, for example, less than 0.7.
  • the first assembly-defined flow diverter counterpart 6002 includes an insert-receiving part 622 (see FIGS. 6, 6A, 6B, and 6C ).
  • the insert-receiving part 622 defines a reservoir fluid receiver 602 , a gas-depleted reservoir fluid discharge communicator 612 , and a passageway 626 extending from the reservoir fluid receiver 602 to the gas-depleted reservoir fluid receiver 612 .
  • the insert-receiving part 622 is configured for integration into the reservoir fluid conducting assembly 14 , such as, for example, by threaded coupling, such that the assembly 14 includes the insert-receiving part 622 .
  • the second assembly-defined flow diverter counterpart 6004 includes a flow diverter-effecting insert 624 (see FIGS. 7 and 8 ) configured for insertion within the passageway 626 .
  • the flow diverter-effecting insert 624 is co-operatively configured with the insert-receiving part 622 such that the flow diverter body 600 A is defined while the flow diverter-effecting insert 624 is disposed within the passageway 626 .
  • the flow diverter-effecting insert 624 is disposed in a flow diverter-defining position when the flow diverter-effecting insert 624 , while disposed within the passageway 626 of the insert-receiving part 622 , is disposed such that the flow diverter body 600 A is defined and functions as above-described.
  • the insert-receiving part 622 further defines both of the reservoir fluid discharge communicator 604 and the gas-depleted reservoir receiver 608 .
  • the reservoir fluid discharge communicator 604 is disposed in fluid communication with the passageway 626
  • the gas-depleted reservoir receiver 608 is also disposed in fluid communication with the passageway 626 .
  • the insert-receiving part 622 and the flow diverter-effecting insert 624 are co-operatively configured such that, while the assembly 10 , having the flow diverter-effecting insert 624 disposed within the passageway 626 of the insert-receiving part 622 , is disposed within the wellbore 102 such that the sealed interface 500 is defined, and the reservoir fluid-supplying conductor 12 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 gas-depleted reservoir fluid receiver 608 is disposed below the reservoir fluid discharge communicator 604 , in which case, the receiving of the obtained gas-depleted reservoir fluid flow by the gas-depleted reservoir fluid receiver 608 is effected by conduction of the obtained gas-depleted reservoir fluid flow to the gas-depleted reservoir fluid receiver 608 in a downhole direction.
  • the insert-receiving part 622 and the flow diverter-effecting insert 624 are further co-operatively configured such that, while the assembly 10 , having the flow diverter-effecting insert 624 disposed within the passageway 626 of the insert-receiving part 622 , is disposed within the wellbore 102 such that the sealed interface 500 is defined, and the reservoir fluid-supplying conductor 12 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 flow diverter-effecting insert 624 is further configured for disposition relative to the passageway 626 such that a passageway sealed interface 628 is established.
  • the insert-receiving part 622 and the flow diverter-effecting insert 624 are further co-operatively configured such that a passageway sealed interface 628 is established while the flow diverter-effecting insert 624 is disposed within the passageway 626 of the insert-receiving part 622 , with effect that:
  • the passageway sealed interface 628 is effected by sealing engagement, or substantially sealing engagement, of the flow diverter-effecting insert 624 with the insert-receiving part 622 .
  • the sealing engagement, or substantially sealing engagement, of the flow diverter-effecting insert 624 with the passageway 626 is effected by a sealing member 628 A that is coupled to the flow diverter-effecting insert 624 .
  • a sealing member 629 is also coupled to the flow diverter effecting insert 624 for protecting the sealing area (defined between sealing members 628 A and 629 ) from erosion and corrosion.
  • the flow diverter-effecting insert 624 is elongated and includes a first end 624 A and a second end 624 B.
  • the sealing member 628 A extends about an external surface 624 C of the flow diverter-effecting insert 624 .
  • the first end 624 A is shaped (such as, for example, cone-shaped) to urge the flow of reservoir fluid, received by the reservoir fluid receiver 602 , towards the reservoir fluid conductor branches 603 .
  • the ports 6245 (such as, for example, in the form of slots formed through the external surface 624 C of the part 624 ) are relatively closer to the first end 624 A, and the port 6243 is disposed at the second end 624 B.
  • a fluid passage 6244 extends along, or substantially along, the central longitudinal axis of the part 624 , from the ports 6245 to the port 6243 for conducting fluid received by the ports 6245 to the port 6243 .
  • the flow diverter-effecting insert 624 and the insert-receiving part 622 are further co-operatively configured such that:
  • the reservoir fluid flow, from the downhole wellbore space 610 is received by the reservoir fluid receiver 602 (in this embodiment, the inlet port 602 A), and conducted through the downhole passageway portion 630 to the reservoir fluid discharge communicator 604 (in the form of reservoir fluid outlet ports 604 ( a )-( f ), and the conduction from the downhole passageway portion 630 to the ports 604 ( a )-( f ) is effected via a plurality of reservoir fluid conductor branches 603 ( a )-( f ) extending between the downhole passageway portion 630 and the ports 604 ( a )-( f )), as is represented by flowpath 10 .
  • the passageway sealed interface 628 prevents, or substantially prevents, the received reservoir fluid flow within the passageway portion 630 from bypassing the reservoir fluid discharge communicator 604 such that a reservoir fluid flow is discharged through the reservoir fluid discharge communicator 604 .
  • the reservoir fluid flow becomes disposed within the uphole wellbore space 108 and, while the discharged reservoir fluid is disposed within the uphole wellbore space 108 , gaseous material is separated from the discharged reservoir fluid, in response to at least buoyancy forces, such that a gas-depleted reservoir fluid flow is obtained.
  • the wellbore sealed interface 500 is preventing, or substantially preventing, the bypassing of the gas-depleted reservoir fluid receiver 608 by the obtained gas-depleted reservoir fluid flow, the obtained gas-depleted reservoir fluid flow is conducted to the gas-depleted reservoir fluid receiver 608 .
  • the gas-depleted reservoir fluid flow received by the gas-depleted reservoir fluid receiver 608 (in the form of inlet ports 608 ( a )-( f )), is conducted to the uphole passageway portion 632 , via: (i) a plurality of gas-depleted reservoir fluid conductor branches 610 ( a )-( f ) extending between the gas-depleted reservoir fluid receiver 608 and the uphole passageway portion 632 ), (ii) the ports 6245 , (iii) the fluid passage 6244 of the flow diverter-effecting insert 624 , and (iv) the port 6243 , as is represented by flowpath 12 .
  • the passageway sealed interface 628 prevents, or substantially prevents, the gas-depleted reservoir fluid flow from bypassing the ports 6245 such that the gas-depleted reservoir fluid flow is discharged through the gas-depleted reservoir fluid discharge communicator 612 .
  • the flow diverter-effecting insert 624 is disposed for becoming releasably retained relative to the insert-receiving part 622 via a coupler 804 incorporated in the reservoir fluid conducting assembly 14 such that the flow diverter-effecting insert is disposed within the passageway in the flow diverter-defining position.
  • the releasable retention is effected with a lock mandrel 802 that has been integrated within the reservoir fluid conducting assembly 14 .
  • the flow diverter-effecting insert 624 is releasably retained to the insert-receiving part 622 via a lock mandrel 802 that has been integrated within the reservoir fluid conducting assembly 14 uphole of the insert-receiving part 622 , such that the flow diverter-effecting insert is disposed in the flow diverter-defining position, the flow diverter-effecting insert 624 while being releasably retained relative to the insert-receiving part 622 .
  • the flow diverter-effecting insert 624 is run downhole with the lock mandrel 802 with a running tool and set within the reservoir fluid conducting assembly 14 by coupling the lock mandrel 802 to a corresponding nipple 804 within the reservoir fluid conducting assembly 14 .
  • Exemplary lock mandrels 802 include the Otis XNTM lock mandrel that is available from Halliburton Company.
  • the corresponding nipple for the Otis XNTM lock mandrel is the Otis XNTM nipple.
  • the flow diverter-effecting insert 624 Upon release from retention relative to the insert-receiving part 622 with a suitable tool, the flow diverter-effecting insert 624 is displaceable, relative to the insert-receiving part 622 (such as, for example, in an uphole direction through the passage 14 A such that the flow diverter-effecting insert 624 is removed from the assembly 10 ) such that occlusion of the passageway of the insert-receiving part, by the flow diverter-effecting insert 624 , is defeated, or at least partially defeated (such as, for example, removed or at least partially removed), and such that the insert-receiving part 622 becomes disposed in a non-occluded condition.
  • the first reservoir fluid-supplying conductor 12 is releasably retained relative to the first assembly counterpart 10 A, such as, for example, the diverter body portion 601 , by coupling between a lock mandrel 806 and a corresponding nipple 808 .
  • the first reservoir fluid-supplying conductor 12 is run downhole with the lock mandrel with a running tool, through the passageway of the insert receiving part 622 , and set within a passage defined within the diverter body portion 601 by coupling the lock mandrel to a corresponding nipple within the diverter body portion 601 , such that the reservoir fluid-supplying conductor 12 is hung from the nipple.
  • Exemplary lock mandrels include the Otis XNTM lock mandrel that is available from Halliburton Company.
  • the corresponding nipple for the Otis XNTM lock mandrel is the Otis XNTM nipple.
  • the first assembly counterpart 10 A further includes the wellbore sealed interface effector 400 , and the reservoir fluid-supplying conductor 12 is removable from the assembly 10 , without having to remove other components, such as the wellbore sealed interface effector 400 .
  • the first reservoir fluid-supplying conductor 12 is removed from the wellbore via the passageway of the insert-receiving part 622 and the reservoir fluid-producing conductor 210 .
  • the flow diverter-effecting insert 624 is removed from the wellbore, and prior to the removal of the insert 624 from the wellbore, the pump 300 is removed from the wellbore.
  • the first reservoir fluid-supplying conductor 12 is removable via slickline.
  • the first reservoir fluid-supplying conductor 12 is rod retrievable.
  • the second reservoir fluid-supplying conductor 12 is run-in-hole, via the passage 14 A, including the passageway 626 of the insert-receiving part 622 , and coupled to the same nipple used at which the first reservoir fluid-supplying conductor 12 had been releasably retained (using a corresponding lock mandrel) such that the second reservoir fluid-supplying conductor 12 is releasably retained relative to the insert-receiving part 622 .
  • the flow diverter-effecting insert 624 and then the pump 300 , are conveyed downhole through the passage 14 A and correspondingly re-deployed within the reservoir fluid conducting assembly 14 so as to enable production using the modified assembly 10 (now with a reservoir fluid-supplying conductor 12 having a narrower cross-sectional flow area).
  • the assembly 10 is emplaced within the wellbore, with effect that the assembly 10 is disposed within the wellbore.
  • the sealed interface effector 400 e.g. packer
  • the sealed interface 500 is actuated, thereby establishing the sealed interface 500 .

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  • Geochemistry & Mineralogy (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
US16/268,113 2018-02-05 2019-02-05 Systems for downhole separation of gases from liquids having interchangeable fluid conductors Abandoned US20190301272A1 (en)

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CN115680577A (zh) * 2022-11-07 2023-02-03 西南石油大学 一种井下同心管水力举升泵

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CA3174317A1 (fr) * 2020-06-24 2021-12-30 Jeffrey Charles Saponja Separateur de fond de trou
US11970925B2 (en) 2020-09-30 2024-04-30 Tier 1 Energy Solutions, Inc. Device and method for gas lift of a reservoir fluid

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US20160265332A1 (en) * 2013-09-13 2016-09-15 Production Plus Energy Services Inc. Systems and apparatuses for separating wellbore fluids and solids during production

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
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
CN115680577A (zh) * 2022-11-07 2023-02-03 西南石油大学 一种井下同心管水力举升泵

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