Patent Application
20240084687
The present disclosure relates to producing reservoir fluids while mitigating the entrainment of solids within the produced reservoir fluid.
Reservoir fluids often contain entrained gases and solids. In producing reservoir fluids containing a relatively substantial fraction of gaseous material, the presence of such gaseous material hinders production by contributing to sluggish flow, and interfering with pump operation. As well, the presence of solids interferes with pump operation, including contributing to erosion of mechanical components. Accordingly, apparatuses and systems for producing reservoir fluids that serve to mitigate against the entrainment of solids within the produced fluids are desirable.
In one aspect, there is provided a fluid production system, for producing hydrocarbon material from an oil reservoir within a subterranean formation, comprising:
a downhole separator, emplaceable within a wellbore string passage of a wellbore string that is lining a wellbore, and including a separator flow receiving communicator and a filtering medium;
a pump; and
a solid and gas-depleted reservoir fluid conductor;
wherein:
the separator and the pump are co-operable with the wellbore string, wherein the co-operation is with effect that:
the pump is configured for effectuating uphole displacement of the solids and gas-depleted reservoir fluid via the solid and gas-depleted reservoir fluid conductor;
the pump includes:
while the system is disposed within the wellbore string passage in a pump cavity filling-ready configuration, wherein, in the pump cavity filling-ready configuration, the travelling valve is closed and the standing valve is closed, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone of the separator and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solid and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that, in response to displacement of the plunger away from the standing valve during an uphole stroke of the plunger, the volume, of the space defined by the pump cavity, increases, with effect that pressure within the pump cavity decreases, such that an unseating pressure differential is established between the subterranean formation and the pump cavity, with effect that the standing valve closure member becomes spaced apart relative to the standing valve seat, such that the standing valve closure member becomes unseated and such that the standing valve becomes open, with effect that flow communication is established, via the standing valve flow communicator, between the pump cavity and the solids and gas-depleted reservoir fluid within the separator output zone, and such that the system transitions from the pump cavity filling-ready configuration to a pump cavity-filling configuration;
while the system is disposed in the pump cavity-filling configuration and the plunger is being displaced away from the standing valve during an uphole stroke of the plunger with effect that the volume, of the space defined by the pump cavity, increases, and with effect that pressure within the pump cavity decreases, such that a flow-inducing pressure differential is established between the pump cavity and the output zone, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone of the separator and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
while the system is disposed in the backflushing-ready configuration, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone of the separator and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that, in response to displacement of the plunger towards the standing valve during a downhole stroke of the plunger, the standing valve closure member becomes displaced towards the standing valve seat, with effect that at least a portion of the solids and gas-depleted reservoir fluid, which has become emplaced within the pump cavity, is displaced by the standing valve closure member and discharged from the pump cavity, with effect that a backwashing flow of the discharged solids and gas-depleted reservoir fluid, through the filtering medium, is effected, for effectuating backwashing of the coupled solid residue material, such that the system is disposed in a backflushing configuration;
and
while the system is disposed in the backflushing configuration and the plunger is being displaced towards the standing valve during a downhole stroke of the plunger, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone of the separator and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation such that, in response to seating of the standing valve closure member on the standing valve seat, the flow communication, via the standing valve flow communicator, between the pump and the subterranean formation becomes occluded, such that the standing valve becomes closed.
In another aspect, there is provided a fluid production system for producing hydrocarbon material from an oil reservoir within a subterranean formation, comprising:
a downhole separator, emplaceable within a wellbore string passage of a wellbore string that is lining a wellbore, wherein the separator includes a separator flow receiving communicator and a filtering medium; and
a pump; and
a solid and gas-depleted reservoir fluid conductor;
wherein:
the separator and the pump are co-operable with the wellbore string, wherein the co-operation is with effect that:
the pump is configured for effectuating uphole displacement of the solids and gas-depleted reservoir fluid via the solid and gas-depleted reservoir fluid conductor;
the pump includes:
while the system is disposed within the wellbore string passage, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone of the separator and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
In another aspect, there is provided a fluid production system for producing hydrocarbon material from an oil reservoir within a subterranean formation, comprising:
a filtering medium, emplaceable within a wellbore;
a pump; and
a solid and gas-depleted reservoir fluid conductor;
wherein:
the filtering medium and the pump are co-operable with the wellbore, wherein the co-operation is with effect that:
the pump includes:
while the system is disposed within the wellbore string passage in a pump cavity filling-ready configuration, wherein, in the pump cavity filling-ready configuration, the travelling valve is closed and the standing valve is closed, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that, in response to displacement of the plunger away from the standing valve during an uphole stroke of the plunger, the volume, of the space defined by the pump cavity, increases, with effect that pressure within the pump cavity decreases, such that an unseating pressure differential is established between the subterranean formation and the pump cavity, with effect that the standing valve closure member becomes unseated from the standing valve seat such that the standing valve closure member becomes spaced apart relative to the standing valve seat and such that the standing valve becomes open, with effect that flow communication is established, via the standing valve flow communicator, between the pump cavity and the solids-depleted reservoir fluid within the output zone, and such that the system transitions from the pump cavity filling-ready configuration to a pump cavity-filling configuration;
while the system is disposed within the wellbore string passage in the pump cavity-filling configuration and the plunger is being displaced away from the standing valve during an uphole stroke of the plunger with effect that the volume, of the space defined by the pump cavity, increases, and with effect that pressure within the pump cavity decreases, such that a flow-inducing pressure differential is established between the pump cavity and the subterranean formation, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
while the system is disposed within the wellbore string passage in the backflushing-ready configuration, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that, in response to displacement of the plunger towards the standing valve during a downhole stroke of the plunger, the standing valve closure member becomes displaced towards the standing valve seat, with effect that at least a portion of the solids-depleted reservoir fluid, which has become emplaced within the pump cavity, is discharged from the pump cavity, with effect that a backwashing flow of the discharged solids and gas-depleted reservoir fluid, through the filtering medium, is effected, for effectuating backwashing of the coupled solid residue material, such that the system is disposed in a backflushing configuration;
and
while the system is disposed within the wellbore string passage in the backflushing configuration and the plunger is being displaced towards the standing valve during a downhole stroke of the plunger, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that, in response to seating of the standing valve closure member on the standing valve seat, the flow communication, via the standing valve flow communicator, between the pump and the subterranean formation becomes occluded, such that the standing valve becomes closed.
In another aspect, there is provided a fluid production system for producing hydrocarbon material from an oil reservoir within a subterranean formation, comprising:
a filtering medium, emplaceable within a wellbore;
a pump; and
a solid and gas-depleted reservoir fluid conductor;
wherein:
the filtering medium and the rod pump are co-operable with the wellbore, wherein the co-operation is with effect that:
the pump is configured for effectuating uphole displacement of the solids-depleted reservoir fluid;
the pump includes:
while the system is disposed within the wellbore string passage, the system is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the output zone and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
In another aspect, there is provided a rod pump comprising:
a suction;
a standing valve including a standing valve closure member, a standing valve seat, and a standing valve flow communicator;
a travelling valve;
a plunger configured for reciprocating movement relative to the standing valve in alternating uphole and downhole strokes, wherein the plunger is coupled to the travelling valve such that the travelling valve is movable with the plunger;
a discharge; and
a pump cavity, wherein the pump cavity defines a space extending from the standing valve flow communicator to the travelling valve flow communicator, and includes a closure member-conducting passage defined by a passage-defining conductor;
wherein:
while the pump is disposed within the wellbore string in a pump cavity filling-ready configuration, wherein, in the pump cavity filling-ready configuration, the travelling valve is closed and the standing valve is closed, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that, in response to displacement of the plunger away from the standing valve during an uphole stroke of the plunger, the volume, of the space defined by the pump cavity, increases, with effect that pressure within the pump cavity decreases, such that an unseating pressure differential is established between the subterranean formation and the pump cavity, with effect that the standing valve closure member becomes unseated from the standing valve seat such that the standing valve closure member becomes spaced apart relative to the standing valve seat and such that the standing valve becomes open, with effect that flow communication is established, via the standing valve flow communicator, between the pump cavity and the downhole-disposed reservoir fluid material, and such that the system transitions from the pump cavity filling-ready configuration to a pump cavity-filling configuration;
while the pump is disposed within the wellbore string passage in the pump cavity-filling configuration and the plunger is being displaced away from the standing valve during an uphole stroke of the plunger with effect that the volume, of the space defined by the pump cavity, increases, and with effect that pressure within the pump cavity decreases, such that a flow-inducing pressure differential is established between the pump cavity and a zone that is disposed downhole relative to the pump, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that:
while the pump is disposed within the wellbore string passage in the backflushing-ready configuration, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that, in response to displacement of the plunger towards the standing valve during a downhole stroke of the plunger, the standing valve closure member becomes displaced towards the standing valve seat, with effect that at least a portion of the pump cavity-disposed reservoir fluid, which has become emplaced within the pump cavity, is discharged from the pump cavity, with effect that a backwashing flow of the discharged pump cavity-disposed reservoir fluid is effected in the downhole direction, such that the pump is disposed in a backflushing configuration;
while the system is disposed in the backflushing-ready configuration, the system is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
In another aspect, there is provided a standing valve-comprising component co-operable with at least a travelling valve-comprising component for system of a rod pump which comprises:
a suction;
a standing valve including a standing valve closure member, a standing valve seat, and a standing valve flow communicator;
a travelling valve;
a plunger configured for reciprocating movement relative to the standing valve in alternating uphole and downhole strokes, wherein the plunger is coupled to the travelling valve such that the travelling valve is movable with the plunger;
a discharge; and
a pump cavity, wherein the pump cavity defines a space extending from the standing valve flow communicator to the travelling valve flow communicator, and includes a closure member-conducting passage defined by a passage-defining conductor;
wherein:
while the pump is disposed within the wellbore string in a pump cavity filling-ready configuration, wherein, in the pump cavity filling-ready configuration, the travelling valve is closed and the standing valve is closed, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that, in response to displacement of the plunger away from the standing valve during an uphole stroke of the plunger, the volume, of the space defined by the pump cavity, increases, with effect that pressure within the pump cavity decreases, such that an unseating pressure differential is established between the subterranean formation and the pump cavity, with effect that the standing valve closure member becomes unseated from the standing valve seat such that the standing valve closure member becomes spaced apart relative to the standing valve seat and such that the standing valve becomes open, with effect that flow communication is established, via the standing valve flow communicator, between the pump cavity and the downhole-disposed reservoir fluid material, and such that the system transitions from the pump cavity filling-ready configuration to a pump cavity-filling configuration;
while the pump is disposed within the wellbore string passage in the pump cavity-filling configuration and the plunger is being displaced away from the standing valve during an uphole stroke of the plunger with effect that the volume, of the space defined by the pump cavity, increases, and with effect that pressure within the pump cavity decreases, such that a flow-inducing pressure differential is established between the pump cavity and a zone that is disposed downhole relative to the pump, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that:
while the pump is disposed within the wellbore string passage in the backflushing-ready configuration, the pump is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the pump cavity-disposed reservoir fluid that has become emplaced within the pump cavity, and the uphole-disposed reservoir fluid that has become emplaced within the wellbore, uphole relative to the pump, and is disposed in fluid pressure communication with the surface, such that, in response to displacement of the plunger towards the standing valve during a downhole stroke of the plunger, the standing valve closure member becomes displaced towards the standing valve seat, with effect that at least a portion of the pump cavity-disposed reservoir fluid, which has become emplaced within the pump cavity, is discharged from the pump cavity, with effect that a backwashing flow of the discharged pump cavity-disposed reservoir fluid is effected in the downhole direction, such that the pump is disposed in a backflushing configuration;
while the system is disposed in the backflushing-ready configuration, the system is co-operable with at least downhole-disposed reservoir fluid, that has become emplaced within the wellbore, downhole relative to the pump, and is disposed in fluid pressure communication with the subterranean formation, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor and in flow communication with the subterranean formation, such that:
the standing valve component defines:
In another aspect, there is provided a fluid production system for producing hydrocarbon material from an oil reservoir within a subterranean formation, comprising:
a filtering apparatus, emplaceable within a wellbore, wherein the filtering apparatus includes:
a housing, wherein the housing defines:
and
a filtering medium;
wherein:
the apparatus is configured for co-operation with a wellbore such that, while the apparatus is disposed within the wellbore and downhole fluid has been received within the wellbore and is disposed within a downhole fluid-receiving zone within the wellbore:
In another aspect, there is provided a filtering apparatus integratable within a fluid production system for producing hydrocarbon material, via a wellbore extending into a subterranean formation, from a hydrocarbon-containing reservoir, wherein the filtering apparatus includes:
a housing, wherein the housing defines:
a check valve;
and
a filtering medium;
wherein:
the apparatus is configured for co-operation with a wellbore such that, while the apparatus is disposed within the wellbore and downhole fluid has been received within the wellbore and is disposed within a downhole fluid-receiving zone within the wellbore:
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 a wellbore 102, 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 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. The term “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 hydrocarbon material, such as oil, natural gas condensates, or any combination thereof. The reservoir fluid can also contain water. The reservoir fluid can also include fluids injected into the reservoir for effecting stimulation of resident fluids within the reservoir.
A wellbore string 108 is emplaced within the wellbore 102 for stabilizing the subterranean formation 100. In some embodiments, for example, the wellbore string 108 also contributes to effecting fluidic isolation of one zone within the subterranean formation 100 from another zone within the subterranean formation 100.
The fluid productive portion of the wellbore 102 may be completed either as a cased-hole completion or an open-hole completion.
With respect to a cased-hole completion, in some embodiments, for example, a wellbore string 108, in the form of a wellbore casing that includes one or more casing strings, each of which is positioned within the wellbore 102, having one end extending from the wellhead 106, is provided. In some embodiments, for example, each casing string is defined by jointed segments of pipe. The jointed segments of pipe typically have threaded connections.
Typically, a wellbore 102 contains multiple intervals of concentric casing strings, successively deployed within the previously run casing. With the exception of a liner string, casing strings typically run back up to the surface 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 the wellbore casing. This is because producing fluids can corrode steel or form undesirable deposits (for example, scales, asphaltenes or paraffin waxes) and the larger diameter can make flow unstable. In this respect, a production string is usually installed inside the last casing string. The production string is provided to conduct reservoir fluid, received within the wellbore, to the wellhead 106. In some embodiments, for example, the annular region between the last casing string and the production string may be sealed at the bottom by a packer.
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 10 receives the reservoir fluid.
In some embodiments, for example, the wellbore casing is set short of total depth. Hanging off from the bottom of the wellbore casing, with a liner hanger or packer, is a liner string. The liner string can be made from the same material as the casing string, but, unlike the casing string, the liner string does not extend back to the wellhead 106. Cement may be provided within the annular region between the liner string and the oil reservoir for effecting zonal isolation (see below), but is not in all cases. In some embodiments, for example, this liner is perforated to effect flow communication between the reservoir and the wellbore. In some embodiments, for example, the production tubing string may be engaged or stung into the liner string, thereby providing a fluid passage for conducting the produced reservoir fluid to the wellhead 106.
An open-hole completion is established by drilling down to the producing formation, and then lining the wellbore (such as, for example, with a wellbore string 108). The wellbore is then drilled through the producing formation, communication between the reservoir and the wellbore.
The system 10 receives, via the wellbore 102, the reservoir fluid flow from the subterranean formation 100. As discussed above, the wellbore 102 is disposed in flow communication (such as through perforations provided within the installed casing or liner, or by virtue of the open hole configuration of the completion), or is selectively manipulated into flow communication (such as by perforating the installed casing, or by actuating a valve to effect opening of a port), with the subterranean formation 100. When disposed in flow communication with the subterranean formation 100, the wellbore 102 is disposed for receiving reservoir fluid flow within the reservoir fluid-receiving zone 402 from the subterranean formation 100, with effect that the system 10 receives the reservoir fluid.
In some embodiments, for example, the system 10 includes a reservoir production system 200, disposed within a wellbore string passage 110 of the wellbore string 108. The reservoir production system 200 includes a separator 400, a pump 300, and a solid and gas-depleted reservoir flow conductor 500. The pump 300 includes a suction 300A and a discharge 300B. The separator 400 is fluidly coupled to the pump suction 300A. The solid and gas-depleted reservoir flow conductor 500 is fluidly coupled to the pump discharge 300B.
The separator 400 includes a filtering apparatus 600. The filtering apparatus 600 includes a housing 612 and a filtering medium 602. The housing 612 defines a flow passage 604, a filtering flow receiving communicator 608, and a flow discharging communicator 414. The filtering flow receiving communicator 608, the filtering medium 602, the flow passage 604, and the flow discharging communicator 414 are co-operatively configured such that, only if flow communication is effective between the reservoir fluid-receiving zone 402 and the flow discharging communicator 414 via the filtering flow receiving communicator 608, at least a portion of solid material that is entrained within reservoir fluid, that is flowing through the filtering flow receiving communicator 608, is separated from the reservoir fluid by the filtering medium 602, with effect that a flow of solids-depleted reservoir fluid 411 is established within the flow passage 604 for discharging through the flow discharging communicator 414. In some embodiments, for example, the filtering medium 602 is mounted to the housing 612.
The separator 400 and the pump 300 are co-operable with the wellbore string 108. The co-operation is with effect that: flow communication is established, within the wellbore 102, between a reservoir fluid-receiving zone 402 and a gas separation zone 404, and in response to motivation by the pump 300:
flow of the reservoir fluid is received within the reservoir fluid-receiving zone 402;
the reservoir fluid flow 401, received within the reservoir fluid-receiving zone 402, is conductible upwardly to the gas separation zone 404, with effect that the reservoir fluid flow is separated into at least a downwardly-flowing gas-depleted reservoir fluid flow 408 and an upwardly flowing gas-enriched reservoir fluid flow 410, wherein the separation includes separation in response to buoyancy forces within the gas separation zone 404;
the separated gas-depleted reservoir fluid flow 408 is received by a separator flow receiving communicator 412, below the gas separation zone 404; and
at least a portion of solid material, entrained within the received gas-depleted reservoir fluid, becomes separated, by the filtering medium, from the received gas-depleted reservoir fluid as a solid material residue that is coupled to the filtering medium 602, such that a solids and gas-depleted reservoir fluid 411 is obtained and becomes emplaced within the flow discharging communicator 414 of the separator 400 for supply to the pump 300, such that the separator flow receiving communicator 402 is disposed in flow communication with the separator flow discharging communicator 414 via the filtering medium 602.
The pump 300 is configured for effectuating uphole displacement of the solids and gas-depleted reservoir fluid 411 via the solid and gas-depleted reservoir fluid conductor 500.
In some embodiments, for example, the pump 300 is a rod pump 300. In this respect, the reservoir production system 200 includes a production string 202, and the production string 202 defines the separator 400 and the solid and gas-depleted reservoir fluid conductor 500. The rod pump 300 is emplaced within the production string 202. Referring to
In some embodiments, for example, the traveling valve 306 includes a closure member 3064, a flow communicator 3062, and a seat 3064. In some embodiments, for example, the closure member 3066, the flow communicator 3062, and the seat 3064 are co-operatively configured such that, while the closure member 3066 is seated on the seat 3064, the flow communicator 3062 is occluded by the closure member 3066. In some embodiments, for example, the occlusion is with effect that the flow communicator 3062 is closed.
In some embodiments, for example, the closure member 3066, the flow communicator 3062, and the seat 3064 are further co-operatively configured such that, while the closure member 3066 is unseated (i.e. spaced apart) relative to the seat 3064, fluid flow is conductible through the flow communicator 3062, and while fluid flow is being conducted through the flow communicator 3062, the closure member 3066 is obstructive to the conducted fluid flow, with effect that at least a portion of the conducted fluid flow is diverted past the closure member 3066.
In some embodiments, for example, the closure member 3066, the flow communicator 3062, and the seat 3064 are further co-operatively configured such that, while the closure member 3066 is seated on the seat 3064 such that the flow communicator 3062 is being occluded by the closure member 3066, unseating of the closure member 3066 is effectible in response to displacement of the closure member 3066, relative to the seat 3064, along an axis that is parallel to a central axis of the flow communicator 3062.
In some embodiments, for example, the closure member 3066, the flow communicator 3062, and the seat 3064 are further co-operatively configured such that, while the closure member 3066 is seated on the seat 3064 such that the flow communicator 3062 is being occluded by the closure member 3066, unseating of the closure member 3066 is effectible in response to displacement of the closure member 3066, relative to the seat 3064, along an axis that is perpendicular to the plane within which the flow communicator 3062 is disposed.
In some of these embodiments, for example, the closure member 3066 is a plug, such as, for example, a ball or a dart. In some embodiments, for example, the closure member 3066 is a plug that is contained within a cage, attached to the plunger 308, and the seat 3064 is also attached to the plunger 308, such that the movement of the travelling valve 306 with the plunger 308 is established by at least the attachment of the cage to the plunger 308 and the attachment of the seat 3064 to the plunger 308. In some embodiments, for example, the closure member 3066 is a poppet (such that the traveling valve 306 is a poppet valve).
In some embodiments, for example, the standing valve 310 includes a flow communicator 3102, a closure member 3106, and a seat 3104. In some embodiments, for example, the closure member 3106, the flow communicator 3102, and the seat 3104 are co-operatively configured such that, while the closure member 3106 is seated on the seat 3104, the flow communicator 3102 is occluded by the closure member 3106. In some embodiments, for example, the occlusion is with effect that the flow communicator 3102 is closed.
In some embodiments, for example, the closure member 3106, the flow communicator 3102, and the seat 3104 are further co-operatively configured such that, while the closure member 3106 is unseated (e.g. spaced apart) relative to the seat 3104, fluid flow is conductible through the flow communicator 3102, and while fluid flow is being conducted through the flow communicator 3102, the closure member 3106 is obstructive to the conducted fluid flow, with effect that at least a portion of the conducted fluid flow is diverted past the closure member 3106.
In some embodiments, for example, the closure member 3106, the flow communicator 3102, and the seat 3104 are further co-operatively configured such that, while the closure member 3106 is seated on the seat 3104 such that the flow communicator 3102 is being occluded by the closure member 3106, unseating of the closure member 3106 is effectible in response to displacement of the closure member 3106, relative to the seat 3104, along an axis that is parallel to a central axis of the flow communicator 3102.
In some embodiments, for example, the closure member 3106, the flow communicator 3102, and the seat 3104 are further co-operatively configured such that, while the closure member 3106 is seated on the seat 3104 such that the flow communicator 3102 is being occluded by the closure member 3106, unseating of the closure member 3106 is effectible in response to displacement of the closure member 3106, relative to the seat 3104, along an axis that is perpendicular to the plane within which the flow communicator 3102 is disposed.
In some of these embodiments, for example, the closure member 3106 is a plug, such as, for example, a ball or a dart. In some embodiments, for example, the closure member 3106 is a plug that is contained within a cage 3112. In some embodiments, for example, the closure member 3106 is a poppet (such that the standing valve 310 is a poppet valve).
The pump 300 further includes a housing 304, which, in some embodiments, is defined by a barrel 304. The barrel 304 is configured to receive the movement of the plunger 308 and, in this respect, the plunger 308 is moveable relative to the barrel 304 such that the traveling valve 306 is displaceable, relative to the standing valve 310, for positioning relative to the standing valve 310 within a range of positions uphole of the standing valve 310. In some embodiments, for example, the seat 3104 is defined on the inner surface of the housing 304.
The pump includes a pump cavity 312 is defined by the inner surface of the housing 304. The pump cavity 312 defines a space extending from the standing valve flow communicator 3102 to the travelling valve flow communicator 3062. In some embodiments, for example, the volume of the pump cavity 312 is determinable based on the positioning of the traveling valve 306 relative to the standing valve 310.
In some embodiments, the pump 300 is a tubing pump with the housing 304 being formed as a part of the production string 202. When the pump 300 is a tubing pump, the pump 300 is coupled to the production string 202 such that a section of the production string 202 defines the housing 304.
In other embodiments, the pump 300 is an insert pump, with the housing 200 being landed on a landing site, or anchored to the tubing. When the pump 300 is an insert pump, the pump 300 is inserted into the tubing in the production string 202 and run as an assembled unit with the sucker rod 302. The insert pump 300 is anchored to the production string 202. The insert pump 300 can be anchored at the top of the pump 300, or at the bottom of the pump 300. An insert pump is typically smaller in diameter than a tubing pump, in order to be inserted into the production string 202, allowing the production string 202 to extend downhole past the pump 114.
As depicted in
In some embodiments, for example, the system is transitionable from the pump cavity filling-ready configuration (see
While the system 200 is disposed in the pump cavity filling-ready configuration, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that, in response to displacement of the plunger 308 away from the standing valve 310 during an uphole stroke of the plunger 308, the volume, of the space defined by the pump cavity 312, increases, with effect that pressure within the pump cavity 312 decreases. The decrease in pressure is with effect that an unseating pressure differential becomes established between the subterranean formation 100 and the pump cavity 312, with effect that the standing valve closure member 3106 becomes spaced apart relative to the standing valve seat 3104 (and, therefore, unseated), such that the standing valve 310 becomes open. In response to the opening of the standing valve 310, flow communication is established, via the flow communicator 3102, between the pump cavity 312 and the solids and gas-depleted reservoir fluid within the separator flow discharging communicator 414. As a result, the system 200 transitions from the pump cavity filling-ready configuration to a pump cavity-filling configuration.
While the system 200 is disposed in the pump cavity-filling configuration and the plunger 308 is being displaced away from the standing valve 310 during an uphole stroke of the plunger 308 with effect that the volume, of the space defined by the pump cavity 312, increases, and with effect that pressure within the pump cavity 312 decreases, such that a flow-inducing pressure differential is established between the pump cavity 312 and the flow discharging communicator 414, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100 such that, in response to the establishment of the flow-inducing pressure differential based on the displacement of the plunger 308 away from the standing valve 310 during an uphole stroke of the plunger 308, the solid and gas-depleted reservoir fluid, disposed within the flow discharging communicator 414, is displaced in response to the established flow-inducing pressure differential, via the standing valve flow communicator 302, into the pump cavity 312.
While the plunger 308 continues to be displaced in an uphole direction such that the travelling valve 306 is further displaced away from the standing valve 310, and such that the volume of the pump cavity 312 continues to increase, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that the unseating pressure differential is maintained, with effect that the closure member 3106 of the standing valve 310, which is unseated from the seat 3104, is urged to remain unseated from the valve seat 3104, such that the standing valve 310 remains open, and reservoir fluid continues to be displaced from the subterranean formation 100 into the wellbore 102 and is received within the pump cavity 312 via the standing valve flow communicator 3102.
In parallel, while the pump 300 is disposed in the pump cavity-filling configuration, and the plunger 308 is being displaced uphole, displacement of solid and gas-depleted reservoir fluid, disposed within the solid and gas-depleted reservoir fluid conductor 500 (e.g the space 316), is urged, by the plunger 308, in the uphole direction.
While the system 200 is disposed in the pump cavity-filling configuration and the plunger 308 is being displaced uphole, the plunger 308 continues to be displaced uphole until the plunger 308 has reached an uphole displacement limit as defined by the surface equipment, such that further uphole displacement of the traveling valve 306 relative to the standing valve 310 is prevented. As a result, the urging of emplacement of the standing valve closure member 3106 in the unseated condition is defeated. This is because the unseating pressure differential is defeated once the pump cavity 312 is no longer expanding in volume, such that there is an insufficient pressure differential for inducing displacement of the solid and gas-depleted reservoir fluid from the flow discharging communicator 414 to the pump cavity 312. In this respect, the system 200 is also co-operable with at least the solid and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 and is disposed in fluid pressure communication with the subterranean formation 100, such that, in response to completion of the uphole stroke of the plunger 308, the urging of emplacement of the standing valve closure member 3106 in the unseated condition is defeated.
The establishment of these conditions (in response to completion of the uphole stroke of the plunger 308 is with effect that the system 200 transitions from the pump cavity-filling configuration to a backflushing-ready configuration (see
While the system 200 is disposed in the backflushing-ready configuration, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that, in response to displacement of the plunger 308 towards the standing valve 310 during a downhole stroke of the plunger 208, the standing valve closure member 3106 becomes displaced towards the standing valve seat 3104, with effect that at least a portion of the solid and gas-depleted reservoir fluid, which has become emplaced within the pump cavity 312, is displaced by the standing valve closure member 3106 and discharged from the pump cavity 312, and, as a corollary, the volume of the space defined by the pump cavity 312 decreases. The discharging is with effect that a backwashing flow 610 of the discharged solid and gas-depleted reservoir fluid, through the filtering medium 602, is effected, for effectuating backwashing of the solid residue that is coupled to the filtering medium. Such backwashing flow 610 is useful for cleaning of the filtering medium 602, by separation (e.g. removal) of at least a portion of the solid residue material from the filtering medium 602. In this respect, while the system 200 is disposed in the backwashing-ready configuration, in response to displacement of the plunger 308 towards the standing valve 310 during a downhole stroke of the plunger 208, the system 200 transitions to a backflushing configuration (see
In some embodiments, for example, the pump cavity 312 includes a closure member-conducting passage 3122, and the closure member-conducting passage is defined by a passage-defining conductor 3124, and while the system 200 is disposed in the backflushing configuration, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator 400 and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that:
while the standing valve closure member 3106 is being displaced towards the standing valve closure seat 3104, the standing valve closure member 3106 is displaced through at least the passage-defining conductor 3124;
while the standing valve closure member 3106 is being displaced through the passage-defining conductor 3124, the solid and gas-depleted reservoir fluid, displaced by the standing valve closure member 3106, is displaced through only either one of: (i) a gap 3126 defined between the standing valve closure member 3106 and the passage-defining conductor 3124, or (ii) the standing valve flow communicator 3102, such that the solid and gas-depleted reservoir fluid that is discharged from the pump cavity 312 is defined by the solid and gas-depleted reservoir fluid displaced through the standing valve communicator 3102 by the standing valve closure member 3106 being displaced through the passage-defining conductor 3124;
the displacement of the standing valve closure member 3106 through the passage-defining conductor 3124 is a tight clearance displacement “D” of at least 0.75 inches, such as, for example, at least 1.0 inch, such as, for example, at least 1.25 inches, such as, for example, at least 1.5 inches, such as, for example, at least 1.75 inches, such as, for example, at least two (2) inches; and
for the entirety of the tight clearance displacement, the standing valve closure member 3106 is spaced-apart from the passage-defining conductor 3124 by the gap 3126, wherein the gap 3126 is defined by a minimum distance “MD” from the standing valve closure member 3106 to the passage-defining conductor 3124 and is less than 70/1000 of an inch. In some embodiments, for example, the gap 3126 is at least 20/1000 of an inch, such as, for example, at least 25/1000 of an inch, such as, for example, at least 30/1000 of an inch, such as, for example, at least 35/1000 of an inch, such as, for example, at least 40/1000 of an inch, such as, for example, at least 45/1000 of an inch.
In some embodiments, for example, that portion of the downhole stroke, during which the system 200 is disposed in the backwashing configuration, is a backwashing configuration-defining downhole stroke portion, and over the entirety of the backwashing configuration-defining downhole stroke portion, the solid and gas-depleted reservoir that is discharged from the pump cavity 312 has a total volume of at least 1.5 cubic inches, such as, for example, at least 1.75 cubic inches.
In some embodiments, for example, while the system 200 is disposed in the backflushing configuration, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator 400 and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that the backwashing flow 610 of the discharged solids and gas-depleted reservoir fluid, through the filtering medium 602, is effected at a rate of at least 50 millilitres per second, such as, for example, at least 60 millilitres per second, such as, for example, 70 millilitres per second.
In some embodiments, for example, the separator 400 further includes a receptacle 420 for receiving the solid residue material 422, which has been separated (e.g removed) from the filtering medium 602 by the backwashing. In some embodiments, for example the receptacle 420 is disposed below the filtering medium 602. In this respect, the transport of the solid residue material 422 to the receptacle 420 is effected by gravity settling. In some embodiments, for example, the receptacle 420 includes a mud joint.
While the system 200 is disposed in the backflushing configuration and the plunger 308 continues to be displaced in the downhole direction during a downhole stroke of the plunger 308, such that the travelling valve 306 is further displaced towards the standing valve 310, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator 400 and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that at least a further portion of the solid and gas-depleted reservoir fluid, which has become emplaced within the pump cavity 312, is discharged from the pump cavity 312 as a backwashing flow 610, and, as a corollary, the volume of the space defined by the pump cavity 312 further decreases.
While the system 200 is disposed in the backflushing configuration and the plunger 308 is being displaced towards the standing valve 310 during a downhole stroke of the plunger 310, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that, in response to seating of the standing valve closure member 3106 on the standing valve seat 3104, the flow communication, via the standing valve flow communicator 3102, between the pump cavity 312 and the subterranean formation 100 becomes occluded, such that the standing valve 310 becomes closed.
In this respect, while the system 200 is disposed in the backflushing configuration and the plunger 308 is being displaced towards the standing valve 310 during a downhole stroke of the plunger 310, in response to the seating of the standing valve closure member 3106 on the standing valve seat 3104, pressure builds up within the pump cavity 312, the system 200 transitions from the backflushing configuration to a pump cavity evacuation configuration (see
While the system 200 is disposed in the pump cavity evacuation configuration, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that, in response to displacement of the plunger 308 towards the standing valve 310 during a downhole stroke of the plunger 208, at least a portion of the solid and gas-depleted reservoir fluid, that has become emplaced within the pump cavity 312, is displaced uphole from the pump cavity 312 to the sold and gas-depleted reservoir fluid conductor 500 via the travelling valve flow communicator 3062, as a pressurized solid and gas-depleted reservoir fluid 502, with effect that the volume, of the space defined by the pump cavity 312, decreases.
While the system 200 is disposed in the pump cavity evacuation configuration, and the plunger 308 continues to be displaced in the downwhole direction, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that the reservoir fluid continues to be displaced from the pump cavity 312 to the solid and gas-depleted reservoir fluid conductor 500 via the travelling valve flow communicator 3062, such that the travelling valve 306 approaches the standing valve 310, and such that the volume of the pump cavity 312 continues to decrease, while, in parallel, the closure member 3106 of the standing valve 310, which is seated on the seat 3104, is urged to remain seated on the valve seat 3104, such that the standing valve 310 remains closed. Such displacement of the plunger 308 continues until the plunger 308 has reached a downhole displacement limit as defined by the surface equipment, such that further downhole displacement of the traveling valve 306 relative to the standing valve 310 is prevented.
While the system 200 is disposed in the pump cavity evacuation configuration and the plunger 308 continues to be displaced in the downwhole direction, the system 200 is co-operable with at least the solids and gas-depleted reservoir fluid, that has become emplaced within the flow discharging communicator 414 of the separator and is disposed in fluid pressure communication with the subterranean formation 100, the solids and gas-depleted reservoir fluid that has become emplaced within the pump cavity 312, and the solids and gas-depleted reservoir fluid that has become emplaced within the solid and gas-depleted reservoir fluid conductor 500 and in flow communication with the subterranean formation 100, such that, in response to the plunger 308 reaching the downhole displacement limit, the travelling valve closure member 3066 becomes seated on the seat travelling valve seat 3064, such that the system 200 transitions from the pump cavity-evacuation configuration to the pump cavity filling-ready configuration. Meanwhile, the standing valve 310 remains closed during the transitioning.
The sequence described in
In some embodiments, for example, the filtering medium 602 is mechanical filter, such as, for example, a screen, such as, for example, a shaker screen.
In some embodiments, for example, the filtering medium 602 is metallic. In some embodiments, for example, the filtering medium 602 is non-metallic.
In some embodiments, for example, the filtering medium 602 has a coating that is characterized by low adhesion properties, such as, for example, a low static coefficient of friction and/or a low dynamic coefficient of friction.
In some embodiments, for example, the gas-depleted reservoir flow, received by the flow communicator, includes oversize solid material, and the oversize solid material is characterized by a size of greater than 60 mesh, and the filtering medium 602 is configured to prevent passage of at least 90% of the oversize solid material of the gas-depleted reservoir fluid flow.
In some embodiments, for example, the gas-depleted reservoir flow, received by the flow communicator, includes oversize solid material, and the oversize solid material is characterized by a size of from 100 mesh to 140 mesh, and the filtering medium 602 is configured to prevent passage of at least 90% of the oversize solid material of the gas-depleted reservoir fluid flow
Referring to
only if flow communication is effective between the reservoir fluid-receiving zone 402 and the flow discharging communicator 414 via the filtering flow receiving communicator 608, and the flowing of the gas-depleted reservoir fluid 408, via the filtering flow receiving communicator 608, from the reservoir fluid-receiving zone 402 to the flow discharging communicator 414 is being motivated by the pump 300, the separation, of the at least a portion of solid material, entrained within the gas-depleted reservoir fluid 408, is effected, such that a solids and gas depleted reservoir fluid 411 is obtained; and
only if a fluid pressure differential, greater than a minimum fluid pressure differential, is established across the filtering flow receiving communicator 608, flow communication, via the bypass flow receiving communicator 616, between the reservoir fluid-receiving zone 402 and the flow discharging communicator 414 is established, with effect that the received gas-depleted reservoir fluid 608 is conductible, via the bypass flow receiving communicator 616, through the flow passage 604, and to the flow discharging communicator 414 for supply to the pump 300, for effecting uphole displacement of the gas-depleted reservoir fluid 608.
In some embodiments, for example, the separation, of the at least a portion of solid material, entrained within the gas-depleted reservoir fluid 608, is with effect that the solid material accumulates within the filtering medium 603, such that accumulated solid material is obtained.
In some embodiments, for example, the establishing of the fluid pressure differential, greater than a minimum fluid pressure differential, across the filtering flow receiving communicator 608 is established in response to the plugging of the filtering medium 602 by the accumulated solid material
In some embodiments, for example, the filtering apparatus 600 further includes a closure member 606, such as, for example, a check valve 606. Referring specifically to
The bypass flow receiving communicator 616, the closure member 606, the flow passage 604, and the flow discharging communicator 414 are co-operatively configured such that, the closure member 606 modulates flow communication, via the bypass flow receiving communicator 616, between the reservoir fluid-receiving zone 402 and the flow discharging communicator 414. The bypass flow receiving communicator 616 is configurable in a closed condition (
Referring to
The bypass flow receiving communicator 616, the closure member 606, the seat 618, and the flow discharging communicator 414 are co-operatively configured such that:
while the bypass flow receiving communicator 616 is disposed in the closed condition, the closure member 606 is seated on the seat 618 (see
while the bypass flow receiving communicator 616 is disposed in the open condition, the closure member 606 is unseated relative to the seat 618 (see
The closure member 606 and the housing 612 are co-operatively configured such that, while the closure member 606 is unseated relative to the seat, the closure member 606 is motivated by at least the gas-depleted reservoir fluid to impact the housing 612, with effect that the filtering medium 602 is vibrated for effecting release of the accumulated solid material.
In some embodiments, for example, the impacting of the housing 612 is in response to an impacting of the seat 618 by the closure member 606 derived from a recession of the closure member 606 relative to the seat 618.
In some embodiments, for example, the closure member 606 and the housing 612 are co-operatively configured such that, while the closure member 606 is unseated relative to the seat 618 and flowing of gas-depleted reservoir fluid 608, via the bypass flow receiving communicator 616, to the flow discharging communicator 414 is being motivated such that gas-depleted reservoir fluid is being conducted, via the bypass flow receiving communicator 616, to the flow discharging communicator 414, the impacting of the housing 612, by the closure member 606, is motivated by the flowing gas-depleted reservoir fluid. In some of these embodiments, for example, the flow communication between the filtering flow receiving communicator 608 and the flow discharging communicator 414 is effected via the flow passage 604, the flow communication between the bypass flow receiving communicator 616 and the flow discharging communicator 414 is effected via the flow passage 604, and the flowing of reservoir fluid between the filtering flow receiving communicator 608 and the flow discharging communicator 414 is effected via the flow passage 604, such that the impacting of the housing 612 by the closure member 606, that is motivated by the flowing reservoir fluid, is effected while the closure member 606 is displaced, by the flowing gas-depleted reservoir fluid, through at least a portion of the flow passage 604.
In some of these embodiments, for example, the housing 612 and the closure member 606 are co-operatively configured such that the displacement of the closure member 606, by the flowing gas-depleted reservoir fluid, is limited to a displacement of the closure member 606 through a traversed flow passage portion 604A. The traversed flow passage portion 604A defines at least a portion of the flow passage 604 In some of these embodiments, for example, the filtering apparatus 600 further includes a retainer 620, wherein the displacement is limited within the space of the flow passage 604 between the retainer 620 and the seat 618. The traversed flow passage portion 604A is defined by a traversed flow passage-defining housing portion 612A of the housing 612. Throughout the displacement, the clearance 622 between the traversed flow passage-defining housing portion 612A and the closure member 606 is at least 40/1000 of an inch, such as, for example, at least ⅛ of an inch, such as, for example, at least ¼ of an inch. In some embodiments, for example, the clearance is less than ⅜ of an inch. In some embodiments, for example, throughout the displacement, the clearance 622 (and, therefore, the cross-sectional flow area of the traversed flow passage portion 604A) is variable such that the ratio of the clearance 622 within a larger passage-defining cross-section 6121 of the traversed flow passage-defining housing section 612A (see
In some embodiments, for example, the traversed flow passage portion 604A has a length of at least four (4) feet (such as, for example, at least five (5) feet, such as, for example, at least 10 feet), measured along the central longitudinal axis of the traversed flow passage portion 604A.
In some embodiments, for example, a standing valve-comprising component is provided and the standing valve component is co-operable with at least a travelling valve-comprising component for system of the pump 300. In this respect, the standing valve component includes the standing valve 310 and the passage-defining conductor 3124 through which the standing valve closure member 3106 is displaced. The displacement of the standing valve closure member 3106 through the passage-defining conductor 3124 is a tight clearance displacement “D” of at least 0.75 inches, such as, for example, at least 1.0 inch, such as, for example, at least 1.25 inches, such as, for example, at least 1.5 inches, such as, for example, at least 1.75 inches, such as, for example, at least two (2) inches. For the entirety of the tight clearance displacement, the standing valve closure member 3106 is spaced-apart from the passage-defining conductor 3124 by the gap 3126, wherein the gap 3126 is defined by a minimum distance “MD” from the standing valve closure member 3106 to the passage-defining conductor 3124 and is less than 70/1000 of an inch. In some embodiments, for example, the gap 3126 is at least 10/1000 of an inch, such as, for example, at least 22/1000 of an inch, such as, for example, at least 30/1000 of an inch, such as, for example, at least 40/1000 of an inch.
The preceding discussion provides many example embodiments. Although each embodiment represents a single combination of inventive elements, other examples may include all suitable combinations of the disclosed elements. Thus if one embodiment comprises elements A, B, and C, and a second embodiment comprises elements B and D, other remaining combinations of A, B, C, or D, may also be used.
The term “connected” or “coupled to” may include both direct coupling (in which two elements that are coupled to each other contact each other) and indirect coupling (in which at least one additional element is located between the two elements).
Although the embodiments have been described in detail, it should be understood that various changes, substitutions and alterations can be made herein.
Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the disclosure of the present invention, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed, that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.
As can be understood, the examples described above and illustrated are intended to be examples only. The invention is defined by the appended claims.
This application claims the benefits of priority to U.S. Provisional Patent Application No. 63/400,227, filed Aug. 23, 2022, titled DOWNHOLE APPARATUS, the contents of which are hereby expressly incorporated into the present application by reference in their entirety.
| Number | Date | Country | |
|---|---|---|---|
| 63400227 | Aug 2022 | US |
