Patent Application
20200240254
The present disclosure relates to mitigating downhole pump gas interference and the stresses applied to downhole wellbore equipment during coupling and de-coupling operations, as well as the adverse effects of solid particulate matter entrainment, during hydrocarbon production.
Downhole pump gas interference is a problem encountered while producing wells, especially wells with horizontal sections. In producing reservoir fluids containing a significant fraction of gaseous material, the presence of such gaseous material hinders production by contributing to sluggish flow. Additionally, solid particulate material is entrained in reservoir fluids, and such solid particulate matter can adversely affect production operations.
The installation or incorporation of gas separators into wellbore string components or equipment that include pump assemblies often requires fixed connections between sections of tubing or various fluid conductors. The connection and disconnection of these various tubing sections or fluid conductors with other wellbore tools or equipment, for example pump assemblies, for various wellbore operations and/or wellbore maintenance applies can, in some instance, apply stresses to the tubing and/or downhole wellbore equipment. Accordingly, wellbore equipment that minimizes the number of fixed connections between tubing strings and/or fluid conductors, etc. is desirable.
In one aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the system comprises:
In another aspect, there is provided a reservoir fluid conducting system disposed within a wellbore that extends into a subterranean formation and is lined with a wellbore string that includes a wellbore string-defined flow diverter counterpart, wherein the system comprises:
In another aspect, there is provided a reservoir fluid production assembly for disposition within a wellbore that extends into a subterranean formation and is lined with a wellbore string, wherein the reservoir fluid production assembly comprises:
Reference will now be made, by way of example, to the accompanying drawings which show example embodiments of the present application, and in which:
Similar reference numerals may have been used in different figures to denote similar components.
As used herein, 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.
Referring to
The wellbore 102 can be straight, curved, or branched. The wellbore 102 can have various wellbore sections. A wellbore section is an axial length of a wellbore 102. A wellbore section can be characterized as “vertical” or “horizontal” even though the actual axial orientation can vary from true vertical or true horizontal, and even though the axial path can tend to “corkscrew” or otherwise vary. In some embodiments, for example, the central longitudinal axis of the passage 102CC defined by a 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 a vertical section 102A is disposed along an axis that is less than about 20 degrees from the vertical “V”, and a transition section 102B is disposed between the sections 102A and 102C. In some embodiments, for example, the transition section 102B joins the sections 102A and 102C. In some embodiments, for example, the vertical section 102A extends from the transition section 102B to the surface 106.
“Reservoir fluid” is fluid that is contained within an oil reservoir. Reservoir fluid may be liquid material, gaseous material, or a mixture of liquid material and gaseous material. In some embodiments, for example, the reservoir fluid includes water and hydrocarbons, such as oil, natural gas condensates, or any combination thereof.
Fluids may be injected into the oil reservoir through the wellbore to effect stimulation of the reservoir fluid. For example, such fluid injection is effected during hydraulic fracturing, water flooding, water disposal, gas floods, gas disposal (including carbon dioxide sequestration), steam-assisted gravity drainage (“SAGD”) or cyclic steam stimulation (“CSS”).
In some embodiments, for example, the same wellbore is utilized for both stimulation and production operations, such as for hydraulically fractured formations or for formations subjected to CSS. In some embodiments, for example, different wellbores are used, such as for formations subjected to SAGD, or formations subjected to waterflooding.
A wellbore string 113 is employed within the wellbore 102 for stabilizing the subterranean formation 100. In some embodiments, for example, 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 113A down into the wellbore through the production zone. In this respect, in the cased-hole completion, the wellbore string 113 includes wellbore casing 113A.
The annular region between the deployed wellbore casing and the oil reservoir may be filled with cement for effecting zonal isolation (see below). The cement is disposed between the wellbore casing and the oil reservoir for the purpose of effecting isolation, or substantial isolation, of one or more zones of the oil reservoir from fluids disposed in another zone of the oil reservoir. Such fluids include reservoir fluid being produced from another zone of the oil reservoir (in some embodiments, for example, such reservoir fluid being flowed through a production tubing string disposed within and extending through the wellbore casing to the surface), or injected fluids such as water, gas (including carbon dioxide), or stimulations fluids such as fracturing fluid or acid. In this respect, in some embodiments, for example, the cement is provided for effecting sealing, or substantial sealing, of flow communication between one or more zones of the oil reservoir and one or more others zones of the oil reservoir (for example, such as a zone that is being produced). By effecting the sealing, or substantial sealing, of such flow communication, isolation, or substantial isolation, of one or more zones of the oil reservoir, from another subterranean zone (such as a producing formation), is achieved. Such isolation or substantial isolation is desirable, for example, for mitigating contamination of a water table within the oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or combinations thereof) being produced, or the above-described injected fluids.
In some embodiments, for example, the cement is disposed as a sheath within an annular region between the wellbore casing and the oil reservoir. In some embodiments, for example, the cement is bonded to both of the production casing and the subterranean formation 100.
In some embodiments, for example, the cement also provides one or more of the following functions: (a) strengthens and reinforces the structural integrity of the wellbore, (b) prevents, or substantially prevents, produced reservoir fluid of one zone from being diluted by water from other zones. (c) mitigates corrosion of the wellbore casing, (d) at least contributes to the support of the wellbore casing, and e) allows for segmentation for stimulation and fluid inflow control purposes.
The cement is introduced to an annular region between the wellbore casing and the subterranean formation 100 after the subject wellbore casing has been run into the wellbore 102. This operation is known as “cementing”.
In some embodiments, for example, the wellbore casing includes one or more casing strings, each of which is positioned within the well bore, having one end extending from the well head. In some embodiments, for example, each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.
Typically, a wellbore contains multiple intervals of concentric casing strings, successively deployed within the previously run casing. With the exception of a liner string, casing strings typically run back up to the surface 106. Typically, casing string sizes are intentionally minimized to minimize costs during well construction. Generally, smaller casing sizes make production and artificial lifting more challenging.
For wells that are used for producing reservoir fluid, few of these actually produce through wellbore casing. This is because producing fluids can corrode steel or form undesirable deposits (for example, scales, asphaltenes or paraffin waxes) and the larger diameter can make flow unstable. In this respect, a production string is usually installed inside the last casing string. The production string is provided to conduct reservoir fluid, received within the wellbore, to the 116. In some embodiments, for example, the annular region between the last casing string and the production tubing string may be sealed at the bottom by a packer 500.
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 subterranean formation 100. When disposed in flow communication with the subterranean formation 100, the wellbore 102 is disposed for receiving reservoir fluid flow from the subterranean formation 100, with effect that the system 8 receives the reservoir fluid.
In some embodiments, for example, the wellbore casing is set short of total depth. Hanging off from the bottom of the wellbore casing, with a liner hanger or packer, is a liner string. The liner string can be made from the same material as the casing string, but, unlike the casing string, the liner string does not extend back to the wellhead 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. In some embodiments, for example, this liner is perforated to effect flow communication between the reservoir and the wellbore. In this respect, in some embodiments, for example, the liner string can also be a screen or is slotted. In some embodiments, for example, the production tubing string may be engaged or stung into the liner string, thereby providing a fluid passage for conducting the produced reservoir fluid to the wellhead 116. In some embodiments, for example, no cemented liner is installed, and this is called an open hole completion or un-cemented casing completion.
An open-hole completion is effected by drilling down to the top of the producing formation, and then lining the wellbore (such as, for example, with a wellbore 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.
Referring now to
In some embodiments, for example, the system 8, includes a downhole disposed conductor 202 for receiving reservoir fluid from a downhole wellbore space 110. A flow diverter 600 is fluidly coupled to the downhole disposed conductor 202 and a pump 302 is fluidly coupled to flow diverter 600. In some embodiments, for example, the pump is releasably coupled to the flow diverter 600. A gas-depleted reservoir fluid producing conductor 204 is fluidly coupled to the pump 302 for conducting gas-depleted reservoir fluid, that has been pressurized by the pump 302, to the surface 106. The downhole-disposed conductor 202, the flow diverter 600, the pump 302, and the gas-depleted reservoir fluid-producing conductor 204 are co-operatively configured such that, while the downhole-disposed conductor 202 is receiving reservoir fluid from the downhole wellbore space 110, which reservoir fluid has been received within the downhole wellbore space 110 from the subterranean formation 100, the reservoir fluid is conducted uphole to a reservoir fluid separation space 112X via the flow diverter 600 where, within the reservoir fluid separation space 112X, a gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained.
The flow diverter 600 is provided for, amongst other things, mitigating gas lock within the pump 302. In this respect, the flow diverter 600 is configured for receiving reservoir fluid that has been received by the wellbore 102 within the downhole wellbore space 110 from the subterranean formation 100, and separating gaseous material from the received reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. In some embodiments, for example, the flow diverter 600 is disposed within a vertical portion 102A of the wellbore 102 that extends to the surface 106. The flow diverter 600 is fluidly coupled to the pump 302 for effecting supply of the gas-depleted reservoir fluid received within the flow diverter 600 to the pump 302.
The pump 302 is provided to, through mechanical action, pressurize and effect conduction of the gas-depleted reservoir fluid to the surface 106, and thereby effect production of the gas-depleted reservoir fluid via the gas-depleted reservoir fluid producing conductor 204. In some embodiments, for example, the pump 302 is a sucker rod pump. Other suitable pumps 302 include screw pumps, electrical submersible pumps, jet pumps, and plunger lift, for example.
In some embodiments, for example, the system 8 includes a production assembly 10. The production assembly 10 is suspended within the wellbore 102 from the wellhead 116.
In some embodiments, for example, the assembly 10 includes the pump 302 and the gas-depleted reservoir fluid-producing conductor 204, and the flow diverter 600. The gas-depleted reservoir fluid-producing conductor 204 is fluidly coupled to the pump 302 for conducting the pressurized gas-depleted reservoir fluid that is received by the pump 302, to the surface 106.
The assembly 10 is disposed within the wellbore string 113, such that an intermediate wellbore passage 112 is defined within the wellbore string 113, between the assembly 10 and the wellbore string 113. In some embodiments, for example, the intermediate wellbore passage 112 is an annular space disposed between the assembly 10 and the wellbore string 113. In some embodiments, for example, 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.
In some embodiments, 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, and the assembly 10 defines the assembly counterpart 600C. The flow diverter defines: (i) a reservoir fluid-conducting passage 6002 for conducting reservoir fluid that is received within a downhole wellbore space from the subterranean formation 100, to the reservoir fluid separation space 112X of the wellbore 102, with effect that 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 302.
In some embodiments, for example, the assembly counterpart 600C includes a flow diverter body 602 and, in some embodiments, the flow diverter body 602 includes a shroud 603. In this respect, the shroud 603 is cooperatively disposed relative to the wellbore string counterpart 600B such that an intermediate reservoir fluid-conducting passage 1112 (such as, for example, an annular fluid passage) is disposed between the shroud 603 and the wellbore string counterpart 600B. The intermediate reservoir fluid conducting passage 1112 forms part of the reservoir fluid conducting passage 6002. In some embodiments, for example, the intermediate reservoir fluid-conducting passage 1112 includes the reservoir fluid-conducting passage 6002 and is disposed for conducting the received reservoir fluid to the reservoir fluid separation space 112X. In some embodiments, for example, the intermediate wellbore passage 112 includes the intermediate reservoir fluid-conducting passage 1112 and the reservoir fluid-conducting passage 6002.
In some embodiments, for example, the flow diverter body 602 or shroud 603 includes a tubular member that extends between an open upper end 604 and an open lower end 606 and defines an open interior space therebetween.
In some embodiments, for example, the wellbore string 113 or the wellbore string counterpart 600B is defined by a 5½″ casing.
In some embodiments, the flow diverter body 602 or shroud 603 includes an opening 605 for receiving the separated gas-depleted reservoir fluid such that the separated gas-depleted reservoir fluid is conducted via the gas-depleted reservoir fluid conducting passage 6004 to the pump 302. In this respect, the opening 605 defines a gas-depleted reservoir fluid receiver. In some embodiments, for example, the opening 605 is disposed at an uphole end of the shroud 603 or flow diverter body 602, and the gas-depleted reservoir fluid-conducting passage 6004 extends downhole from the uphole end for conducting the received gas-depleted reservoir fluid in a downhole direction. In some embodiments, for example, the opening 605 includes the open upper end 604 of the flow diverter body 602 or shroud 603, the flow diverter body 602 or shroud 603 being disposed within the wellbore 102 such that the opening upper end 604 is disposed for receiving the separated gas-depleted reservoir fluid, the open upper end 604 therefore serving as the gas-depleted reservoir fluid receiver. The reservoir fluid separation space 112X is disposed uphole, such as vertically above, the opening 605 or open upper end 604 of the flow diverter body 602 or shroud 603.
In some embodiments, the flow diverter body 602, or shroud 603, is disposed within the wellbore 113 such that it cooperates with a wellbore string counterpart 602B defined by a corresponding portion of the wellbore string 113. The flow diverter body 602 is disposed within the wellbore 113 and is cooperatively configured with the wellbore string counterpart 602B to define the intermediate reservoir fluid-conducting passage 6002 for conducting reservoir fluid that is received within a downhole wellbore space 110 from the subterranean formation 100 and conducted to an uphole wellbore space 108 via the downhole disposed conductor 202, to the reservoir fluid separation space 112X of the wellbore 102 where, within the reservoir fluid separation space 112X, the gas-depleted reservoir fluid is separated from the reservoir fluid in response to at least buoyancy forces. In some embodiments, for example, the reservoir fluid separation space 112X is configured such that, in operation, while reservoir fluid is being supplied to the reservoir fluid separation space 112X, the velocity of the gaseous portion of the reservoir fluid being conducted via the intermediate reservoir fluid conducting passage 6002 is greater than the critical liquid lifting velocity, and while the reservoir fluid is disposed within the reservoir fluid separation space 112X, the velocity of the gaseous portion of the reservoir fluid is sufficiently low such that the above-described separation is effected.
In some embodiments, there is provided a pump assembly and the pump assembly includes the pump 302 and a pump-seating body 700. The pump-seating body defines a pump-seating receptacle for receiving and releasably connecting with the pump 302. The pump-seating body 700 also defines a pump-intake conducting passage 704 for conducting the gas-depleted reservoir fluid obtained within the reservoir fluid separation space 112X to the pump 302. In some embodiments, the pump-seating receptacle 702 includes a pump-seating nipple 705 for effecting the releasable coupling or releasable connection between the pump 302 and the pump-seating body 700 such that the pump 302 is disposed for receiving the gas-depleted reservoir fluid.
In some embodiments, the flow diverter body 602 or shroud 603 and the pump-seating body 700 are cooperatively configured such that the gas-depleted reservoir fluid conducting passage 6004 is disposed between the shroud 603 and the pump-seating body 700 for delivering the gas-depleted reservoir fluid obtained within the reservoir fluid separation space 112X to the pump 302 via the pump-intake conducting passage 704.
In some embodiments, for example, the flow diverter body 602 or shroud 603 and the pump-seating body 700 are cooperatively configured such that bypassing of the pump-intake conducting passage 704 by the gas-depleted reservoir fluid that is received and conducted by the gas-depleted reservoir fluid conducting passage 6004 is prevented or substantially prevented. In this respect, in some embodiments, for example, the flow diverter body 602 includes a flow-blocking member or sealed interface 800 disposed intermediate the open upper end 604 and the open lower end 606 for preventing or substantially preventing such bypassing. In some embodiments, the sealed interface 800 is disposed within the flow diverter body 602 or shroud 603 such that the sealed interface 800 divides the opening interior space into an upper open interior space 608 and a lower open interior space 610, the upper open interior 608 being fluidly isolated from the lower open interior space 610.
In some embodiments, the pump-seating receptacle 702 has a diameter that is greater than a diameter of the pump-intake conducting passage 704.
In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the pump-seating receptacle 702 is disposed uphole of the open upper end 604 of the flow diverter body 602 with the pump-intake conducting passage 704 extending into the upper open interior space 608 of the flow diverter body 602 through the open upper end 604 such that the gas-depleted reservoir fluid-conducting passage 6004 is defined between the pump-intake conducting passage 704 of the pump-seating body 700 and the flow diverter body 602 or shroud 603 for conducting the separated gas-depleted reservoir fluid that is obtained within the reservoir fluid separation space 112X to a gas-depleted reservoir fluid receiving space 6006 defined within the flow diverter body 602 uphole of the sealed interface 800 from where it is conducted to the pump 302 via the pump-intake conducting passage 704 where the fluid is pressurized by the pump 302 and conducted uphole to the surface 106 via the gas-depleted reservoir fluid producing conductor 204. In this respect, the pump-seating body 700 is cooperatively configured with the flow diverter body 602 such that the pump-intake conducting passage 704 is fluidly coupled or disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006.
In some embodiments, for example, a supporting member 900 suspends the flow diverter body 602 from the pump-seating body 700 such that the gas-depleted reservoir fluid conducting passage 6004 is disposed between the pump seating body 700 and an inner surface 601 of the flow diverter body 602 or shroud 603. Therefore, in some embodiments, the pump-seating body 700, the supporting member 900 and the flow diverter body 602 are cooperatively configured such that the gas-depleted reservoir fluid-conducting passage 6004 is defined between the pump-seating body 700 and a corresponding inner surface 601 of the flow diverter body 602. In some embodiments, for example, the gas-depleted reservoir fluid-conducting passage 6004 is an annular space disposed between the pump-seating body 700 and the flow diverter body 602. In some embodiments, the gas-depleted reservoir fluid-conducting passage 6004 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from the pump-seating body 700 to the flow diverter body 602. In some embodiments, the gas-depleted reservoir fluid-conducting passage 6004 extends longitudinally from the open upper end 606 of the flow diverter body 602 to the closed end defined within the flow diverter body 602 by the sealed interface 800 in the space between the pump seating body 700 and the flow diverter body 602.
In some embodiments, for example, the sealed interface 800 is disposed within the flow diverter body 602 and divides the flow diverter body 602, or shroud 603, into the upper interior space 608 that extends between one side of the sealed interface 800 and the open upper end 604 of the flow diverter body 602, and a lower interior space 610 that extends between the opposite side of the sealed interface 800 and the open lower end 606 of the flow diverter body 602. Accordingly, in some embodiments the closed end of the gas-depleted reservoir fluid-conducting passage 6004 is defined by one side of the sealed interface 800.
In some embodiments, the gas-depleted reservoir fluid receiving space 6006 is disposed within the upper interior space 608 of the flow diverter body 602. In some embodiments, therefore, the gas-depleted reservoir fluid receiving space 6006 is defined at a bottom end of the upper interior space 608 of the flow diverter body 602. In some embodiments, disposition of the flow blocking member or sealed interface 800 within the flow diverter body 602, or shroud 603, is such that a sealed interface is effected between the inner surface 601 of the flow diverter body 602 and the corresponding surface of flow-blocking member or sealed interface 800 such that the upper interior space 608 is fluidly isolated from the lower open interior space 610.
In some embodiments, the supporting member 900 includes a hanger assembly. In some embodiments, the supporting member 900 is disposed uphole of the flow diverter flow blocking member 800 and is selected such that the supporting member 900, or hanger assembly, does not impede fluid flow within the gas-depleted reservoir fluid conducting passage 6004. Therefore, in some embodiments, the supporting member 900, or hanger assembly, is selected such that suspension of the flow diverter body 602 from the pump-seating body 700 is with effect that fluid flow of the gas-depleted reservoir fluid from the wellbore separation space 112X to the gas-depleted reservoir fluid receiving space 6006 across the supporting member 900, or hanger assembly, is permitted. In some embodiments, the supporting member 900, or hanger assembly, is selected such that suspension of the flow diverter body 602 from the pump-seating body 700 is with effect that interference to the flow of gas-depleted reservoir fluid within the gas-depleted reservoir fluid conducting passage 6004 to the gas-depleted reservoir fluid receiving space 6006 is prevented, or substantially prevented.
In some embodiments, a further supporting member 902 supports the assembly counterpart 600C within the wellbore string 113 or relative to the wellbore counterpart 600B. In some embodiments, for example, the supporting member 902 supports the flow diverter body 602 or shroud 603 within the wellbore 102 relative to a corresponding portion of the wellbore string 113. In this respect, the supporting member 902 supports the flow diverter body 602 or shroud 603 relative to the corresponding portion of the wellbore string 113 such that it does not impede, or substantially does not impede, flow through the intermediate reservoir fluid conducting passage 6002. In some embodiments, for example, the supporting member 902 includes a hanger assembly.
In some embodiments, for example as shown in
Referring again to
In some embodiments, the pump-intake conducting passage 704 extends between the distal end 706 of the pump-seating body 700 and the pump-seating receptacle 702, and disposition of the pump-seating body 700 within the flow diverter 602 is such that the pump-intake conducting passage 704 is disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006. Therefore, while gas-depleted reservoir fluid is being received within the gas-depleted reservoir fluid receiving space 6006 from the wellbore separation space 112X via the gas-depleted reservoir fluid conducting passage 6004, gas-depleted reservoir fluid is supplied to the pump 302 via the pump-intake conducting passage 704.
The flow diverter body 602, or shroud 603, further defines a reservoir fluid receiving space 6008 for receiving reservoir fluid that is conducted from the downhole wellbore space 110 to the uphole wellbore space 108. In some embodiments, the downhole disposed conductor 202 and the flow diverter 600 are cooperatively configured such that the downhole disposed conductor 202 is disposed in fluid communication with the reservoir fluid receiving space 6008 such that the reservoir fluid that is received within the downhole wellbore space 110 from the subterranean 100 and is conducted uphole to the uphole wellbore space 108 via the downhole disposed conductor 202 is discharged into the reservoir fluid receiving space 6008 from where it is conducted to the wellbore separation space 112X.
In some embodiments, for example, the downhole disposed conductor 202 includes a discharge end 203 from which reservoir fluid, that is received within the downhole wellbore space 110 from the subterranean formation 100, is discharged uphole into the reservoir fluid receiving space 6008 defined by the flow diverter body 602, or shroud 603.
In some embodiments, the flow diverter body 602 and the downhole disposed conductor 202 are cooperatively configured such that a reservoir fluid conducting passage 6010 fluidly interconnects the reservoir fluid receiving space 6008 and the intermediate reservoir fluid conducting passage 6002, the reservoir fluid receiving space 6008 being defined within the lower interior space 610 of the flow diverter body 602 downhole of the sealed interface 800. In this respect, the reservoir fluid conducting passage 6010 extends between the closed, upper end of the lower interior space 610, as defined by the sealed interface 800 to the open, lower end 606 of the flow diverter body 602 or shroud 603, the open lower end 606 therefore, in some embodiments, serving as a received reservoir fluid outlet 611.
As shown in
In some embodiments, the reservoir fluid receiving space 6008 is defined within the lower open space 610 of the flow diverter body 602 between the discharge end 203 of the downhole disposed conductor 202 and the sealed interface 800 while the reservoir fluid-conducting passage 6010 is defined between the downhole disposed conductor 202 and a corresponding inner surface of the flow diverter body 602. In some embodiments, for example, the reservoir fluid-conducting passage 6010 is an annular space disposed between the downhole disposed conductor 202 and the flow diverter body 602. In some embodiments, the reservoir fluid-conducting passage 6010 is defined by the space that extends outwardly, relative to the central longitudinal axis of the assembly 10, from at least a vertical, or substantially vertical, portion of the downhole disposed conductor 202 to the flow diverter body 602. In some embodiments, the reservoir fluid-conducting passage 6010 extends longitudinally from the sealed interface 800 to the open lower end 606 of the flow diverter body 602 between the downhole disposed conductor 202 and the flow diverter body 602.
In some embodiments, for example, the system 8 also includes a wellbore string sealed interface 500 for preventing, or substantially preventing, bypassing of the reservoir fluid separation space 112X by the reservoir fluid that is supplied to the uphole wellbore space 108 by the downhole-disposed conductor 202. In some embodiments, for example, the sealed interface 500 is defined by a sealed interface effector 502, such as, for example, a packer.
In some embodiments, for example, the sealed interface 500 is defined within the wellbore 102, between: (a) the uphole wellbore space 108 of the wellbore 102, and (b) the downhole wellbore space 110 of the wellbore 102. In some embodiments, for example, the disposition of the sealed interface 500 is such that flow communication, via the intermediate wellbore passage 112, between the uphole wellbore space 108 and the downhole wellbore space 110 (and across the sealed interface 500), is prevented, or substantially prevented. In some embodiments, for example, 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. In this respect, the sealed interface 500 functions to prevent, or substantially prevent, reservoir fluid flow, that is received within the uphole wellbore space 108 via the downhole disposed conductor 202, from bypassing the reservoir fluid separation space 112X, and, as a corollary, the reservoir fluid is directed to the reservoir fluid separation space 112X, via the intermediate reservoir fluid conductor 112, for facilitating separation of gaseous material from the reservoir fluid in response to at least buoyancy forces.
In some embodiments, for example, the downhole disposed conductor 202, the flow diverter body 602, the flow diverter body sealed interface 800, the pump-seating body 700, the pump 302 and the gas-depleted reservoir fluid producing conductor 204 are cooperatively configured such that, in operation, while the downhole disposed conductor 202 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 supplied to the uphole wellbore space 108 by the downhole disposed conductor 202 such that reservoir fluid is discharged from the discharge end 203 of the downhole disposed conductor 202 into the reservoir fluid receiving space 6008. The reservoir fluid received within the reservoir fluid receiving space 6008 is then conducted downhole via the reservoir fluid conducting passage 6010 and delivered to the intermediate reservoir fluid conducting passage 6002 via the received reservoir fluid outlet 611, where it is directed uphole to the reservoir fluid separation space 112X. Bypassing of the reservoir fluid separation space 112X by the reservoir fluid is prevented, or substantially prevented by the sealed interface 500 or sealed interface effector 502, such that reservoir fluid is supplied to the reservoir fluid separation space 112X by the intermediate reservoir fluid conductor 6002. Within the reservoir fluid separation space 112X, gas-depleted reservoir fluid is separated from the reservoir fluid, in response to at least buoyancy forces, such that the gas-depleted reservoir fluid is obtained. The separated gas-depleted reservoir fluid is received by a gas depleted reservoir fluid receiver 605 of the flow diverter body 602 or shroud 603 (e.g. the open upper end 604 of the flow diverter body 602 or shroud 603) and is conducted to the gas-depleted reservoir fluid receiving space 6006 via the gas-depleted reservoir fluid conducting passage 6004. From the gas-depleted reservoir fluid receiving space 6006, the separated gas-depleted reservoir fluid is conducted to the pump 302 via the pump-intake conducting passage 704. Once received by the pump 302, the gas-depleted reservoir fluid is pressurized by the pump 302 and is conducted uphole to the surface 106 as production flow via the gas-depleted reservoir fluid producing conductor 204.
In parallel, the separation of gaseous material from the reservoir fluid within the reservoir fluid separation space 112X is with effect that a liquid-depleted reservoir fluid is obtained and is conducted uphole (in the gaseous phase, or at least primarily in the gaseous phase with relatively small amounts of entrained liquid), via a liquid-depleted reservoir fluid conducting passage 6012 that is disposed between the assembly 10 and a corresponding portion of the wellbore string 113 generally uphole of the reservoir fluid separation space 112X.
The reservoir fluid produced from the subterranean formation 100, via the wellbore 102, including the gas-depleted reservoir fluid, the liquid-depleted reservoir fluid, or both, may be discharged through the wellhead 116 to a collection facility, such as a storage tank.
In some embodiments, for example, the reservoir fluid separation space 112X spans a continuous space extending from the assembly 10 to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the assembly 10.
In some embodiments, for example, the reservoir fluid separation space 112X spans a continuous space extending from the assembly 10 to the wellbore string 113, and the continuous space extends outwardly relative to the central longitudinal axis of the wellbore 102.
In some embodiments, for example, the reservoir fluid separation space 112X is disposed within a vertical portion 102A of the wellbore 102 that extends to the surface 106.
In some embodiments, for example, 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 defined by the reservoir fluid-supplying conductor 202 is at least about 1.5.
In some embodiments, for example, the uphole wellbore space 108 includes a sump space 550, and the sump space 550 is disposed: (i) downhole relative to the reservoir fluid separation space 112X (such as, for example, downhole relative to the intermediate reservoir fluid conducting passage 6002), and (ii) uphole relative to the sealed interface 500. The sump space 550 is provided for collecting solid particulate material that gravity separates from the reservoir fluid that is supplied to the uphole wellbore space 108 by the downhole-disposed conductor 202. In some embodiments, for example, the discharge end 203 of the downhole-disposed conductor 202 is disposed uphole relative to the sump space 550 and is cooperatively configured with the flow diverter body 602 such that the discharge end 203 is oriented for discharging the conducted reservoir fluid in a downhole direction towards the sump space 550. In this respect, as reservoir fluid is discharged from the discharge end 203 into the reservoir fluid receiving space 6008 defined by the flow diverter body 602, the reservoir fluid flows in the downhole direction in the reservoir fluid conducting passage towards the sump space 550, and after having flowed in the downhole direction, the reservoir fluid reverses direction and flows in an uphole direction to the reservoir fluid separation space 112X via the intermediate reservoir fluid conducting passage 6002. During the flow reversal, as the reservoir fluid is discharged from the open lower end 606 of the flow diverter body (or reservoir fluid outlet), at least a fraction of solid particulate material, that is entrained within the reservoir fluid, that is discharged into the uphole wellbore space 108 from the downhole-disposed conductor 202, becomes separated from the reservoir fluid and gravity settles within the sump space 550.
The pump-seating body 700 includes a gas-depleted reservoir fluid inlet 710 disposed uphole of the flow diverter sealed interface 800 that is disposed in fluid communication with the gas-depleted reservoir fluid receiving space 6006 such that the gas-depleted reservoir fluid is communicated to the pump-intake conducting passage 704 from the gas-depleted reservoir fluid receiving space 6006 through the gas-depleted reservoir fluid inlet 710.
In some embodiments, for example, in reference to the embodiment illustrated in
Referring now in particular to
Therefore, in the example embodiment illustrated in
A pump-seating body flow-blocking member or sealed interface 810 is disposed within the pump-seating body 700 such that a sealed interface is effected between the pump-seating body 700 and a corresponding portion of the pump-seating body flow-blocking member or sealed interface 810, the gas-depleted reservoir fluid inlet 710 disposed within the pump-seating body 700 uphole of the pump-seating body sealed interface 810.
A reservoir fluid outlet 720 is disposed within the pump-seating body 700 downhole relative to the placement of the pump-seating body flow-blocking member 810 such that the reservoir fluid outlet 720 is in fluid communication with the reservoir fluid receiving space 6008 such that reservoir fluid that is conducted uphole from the downhole wellbore space 110, via the downhole disposed conductor 202, is communicated to the reservoir fluid receiving space 6008 through the reservoir fluid outlet 720.
In some embodiments, the pump-seating body 700 and the pump-seating body sealed interface 810 are cooperatively configured such that the gas-depleted reservoir fluid inlet 710 is disposed uphole of the pump-seating body sealed interface 810 while the reservoir fluid outlet 720 is disposed downhole of the pump-seating body sealed interface 810, the reservoir fluid outlet 720 being fluidly isolated from the gas-depleted reservoir fluid inlet 710 by the pump-seating body sealed interface 810.
As shown in
The releasable coupling of the downhole disposed conductor 202 to the pump seating body 700 is such that a reservoir fluid discharge opening 612 (or received reservoir fluid outlet 611) is defined, for example, by the annular gap or space defined between the downhole disposed conductor 202 and/or the pump-seating body 700 and the open lower end 606 of the flow diverter body 602 or shroud 603, serves to fluidly interconnect the reservoir fluid conducting passage 6010 and the intermediate reservoir fluid conducting passage 6002, the reservoir fluid conducting passage 6010 extending between the reservoir fluid receiving space 6008 and the reservoir fluid discharge opening 612.
Therefore, in some embodiments, for example, in operation, while the downhole disposed conductor 202 is releasably coupled to the reservoir fluid receiver 706 of the pump-seating body 700 and is receiving reservoir fluid received within the downhole wellbore space 110 from the subterranean formation 100, as shown in
In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the reservoir fluid receiver disposed at the distal end 706 of the pump-seating body 700 is disposed uphole of the open lower end 606 of the flow diverter body 602 such that the downhole disposed conductor 202 is releasably coupled to the pump-seating body 700 at a location uphole of the open lower end 606 of the flow diverter body 602.
In some embodiments, the pump-seating body 700 and the flow diverter body 602 are cooperatively configured such that the reservoir fluid receiver disposed at the distal end 706 of the pump-seating body 700 is disposed downhole of the open lower end 606 of the flow diverter body 602 such that the downhole disposed conductor 202 is releasably coupled to the pump-seating body 700 at a location downhole of the open lower end 606 of the flow diverter body 602.
As described above, in some embodiments, for example, the pump-seating receptacle 702 includes an on/off tool or lugs 703, or any other suitable on/off mechanism known in the art, for releasably coupling the pump 302 or pump assembly to the pump-seating body 700. In the embodiment shown in
In the above description, for purposes of explanation, numerous details are set forth in order to provide a thorough understanding of the present disclosure. However, it will be apparent to one skilled in the art that these specific details are not required in order to practice the present disclosure. Although certain dimensions and materials are described for implementing the disclosed example embodiments, other suitable dimensions and/or materials may be used within the scope of this disclosure. All such modifications and variations, including all suitable current and future changes in technology, are believed to be within the sphere and scope of the present disclosure. All references mentioned are hereby incorporated by reference in their entirety. Therefore, as certain adaptations and modifications of the described embodiments can be made, the above discussed embodiments are considered to be illustrative and not restrictive.
This application claims priority under 35 U.S.C. § 120 from U.S. Provisional Patent Application No. 62/798,791 filed on Jan. 30, 2019, and the entire content is incorporated herein by reference.
| Number | Date | Country | |
|---|---|---|---|
| 62798791 | Jan 2019 | US |
