Note : Les descriptions sont présentées dans la langue officielle dans laquelle elles ont été soumises.
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DOWNHOLE FLOW DIVERTER WITH ARCUATE-SHAPED FLOW CONDUCTOR
FIELD
[0001] The present disclosure relates to mitigating downhole pump
gas
interference during hydrocarbon production.
BACKGROUND
[0002] 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.
[0003] Separators are provided help remedy or mitigate downhole
pump gas interference during hydrocarbon production. However, separators
often occupy relatively significant amounts of space within a wellbore,
rendering efficient separation of gaseous material that is entrained within
the
reservoir fluid difficult. Some separators are complex structures and are
associated with increased material and manufacturing costs. Accordingly,
efficient and cost effective separation of gaseous material that is entrained
within the reservoir fluid is desirable.
SUMMARY
[0004] In one aspect, there is provided a flow diverter for coupling
to a
reservoir fluid conductor, a gas-depleted reservoir fluid conductor, and a
sealed interface effector for establishing a production assembly configured
for disposition in a production effective orientation within a wellbore string
of
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a wellbore, extending into a subterranean formation, for effecting production
from the subterranean formation, wherein the flow diverter defines:
a reservoir fluid receiver;
a reservoir fluid discharging communicator;
a reservoir fluid conducting passage effecting flow
communication between the reservoir fluid receiver and the fluid
discharging communicator;
a gas-depleted reservoir fluid receiver;
a gas-depleted reservoir fluid discharging communicator; and
a gas-depleted reservoir fluid conducting passage effecting flow
communication between the gas-depleted reservoir fluid receiver and
the gas-depleted reservoir fluid discharging communicator;
wherein:
the reservoir fluid conductor defines a reservoir fluid conductor
receiver and a reservoir fluid conductor fluid passage for conducting
reservoir fluid received by the reservoir fluid conductor fluid receiver,
and the coupling of the reservoir fluid conductor to the flow diverter is
with effect that reservoir fluid, receivable by the reservoir fluid
conductor receiver is conductible to the reservoir fluid receiver of the
flow diverter;
the gas-depleted reservoir fluid conductor defines a fluid
passage, and the coupling of the gas-delpleted reservoir fluid
conductor to the flow diverter is with effect that gas-depleted reservoir
fluid, dischargable from the gas-depleting reservoir fluid discharging
communicator of the flow diverter, is conductible to the surface by the
fluid passage of the gas-depleted reservoir fluid conductor;
the production assembly is configured such that, while disposed
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within the wellbore string in a production effective orientation:
the reservoir fluid receiver of the flow diverter is disposed
downhole relative to the reservoir fluid discharging
communicator of the flow diverter;
the gas-depleted reservoir fluid receiver of the flow
diverter is disposed downhole relative to the gas-depleted
reservoir fluid discharging communicator of the flow diverter;
the reservoir fluid discharging communicator of the flow
diverter is disposed uphole relative to the gas-depleted reservoir
fluid receiver of the flow diverter; and
an intermediate fluid passage-defining outermost surface
of the flow diverter co-operates with the wellbore string for
establishing an intermediate fluid passage between the
intermediate fluid passage-defining outermost surface of the
flow diverter and the wellbore string;
the intermediate fluid passage is disposed for effecting flow
communication between the reservoir fluid discharging communicator
and the gas-depleted reservoir fluid receiver;
the reservoir fluid conductor receiver, the reservoir fluid
conductor fluid passage, the reservoir fluid receiver of the flow
diverter, the reservoir fluid conducting passage of the flow diverter,
and the reservoir fluid discharging communicator of the flow diverter
are co-operatively configured such that, while the production assembly
is disposed within the wellbore string in the separation-effective
orientation, the sealed interface effector is disposed in sealing
disposition with the wellbore string such that a sealed interface is
defined, and reservoir fluid flow is being received by the reservoir fluid
conductor receiver, the received reservoir fluid flow is conducted to the
reservoir fluid discharging communicator, via the reservoir fluid
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conductor fluid passage, the reservoir fluid receiver of the flow
conductor, and the reservoir fluid conducting passage of the flow
diverter, for discharging from the flow diverter via the reservoir fluid
discharging communicator;
the gas-depleted reservoir fluid conducting passage of the flow
diverter, the gas-depleted reservoir fluid receiver of the flow diverter,
the gas-depleted reservoir fluid discharging communicator of the flow
diverter, and the fluid passage of the gas-depleted reservoir fluid
conductor are co-operatively configured such that, while the
production assembly is disposed within the wellbore string in the
production-effective orientation, the sealed interface effector is
disposed in sealing disposition with the wellbore string such that a
sealed interface is defined, and gas-depleted reservoir fluid flow is
being received by the gas-depleted reservoir fluid communicator of the
flow diverter, the received gas-depleted reservoir fluid flow is
conducted, via the gas-depleted reservoir fluid conducting passage of
the flow diverter, the gas-depleted reservoir fluid discharging
communicator of the flow diverter, and the fluid passage of the gas-
depleted reservoir fluid conductor, such that the gas-depleted
reservoir fluid becomes disposed uphole relative to the gas-depleted
reservoir fluid receiver;
the reservoir fluid discharging communicator of the flow
diverter, the sealed interface effector, and the gas-depleted reservoir
fluid receiver of the flow diverter are co-operatively configured such
that, while the production assembly is disposed within the wellbore
string in the production-effective orientation, the sealed interface
effector is disposed in sealing disposition with the wellbore string such
that a sealed interface is defined, and reservoir fluid flow is being
discharged from the reservoir fluid discharging communicator:
the reservoir fluid becomes disposed externally of the
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separator within a wellbore space within the wellbore string;
a gas-depleted reservoir fluid is separated from the
discharged reservoir fluid, within the wellbore space, in response to
at least buoyancy forces; and
bypassing of the gas-depleted reservoir fluid receiver, by the
gas-depleted reservoir fluid, that is being conducted downhole via
the intermediate wellbore passage, is prevented by the sealed
interface effector, such that the gas-depleted reservoir fluid is
received by the gas-depleted reservoir fluid receiver;
the flow diverter includes a body and a body co-operator;
the body defines:
the reservoir fluid receiving communicator;
the gas-depleted reservoir fluid receiving communicator;
the gas-depleted reservoir fluid-conducting passage; and
the gas-depleted reservoir fluid discharging communicator;
the body co-operator includes an outermost surface;
the body co-operator is joined to the body at a joint with effect that at
least a portion of the intermediate passage-defining outermost surface of the
flow diverter is defined by the outermost surface of the body co-operator;
the body and the body co-operator co-operate to define an externally-
disposed reservoir fluid conducting passage;
at least a portion of the reservoir fluid conducting fluid passage is defined
by
the externally-disposed reservoir fluid conducting passage.
BRIEF DESCRIPTION OF THE DRAWINGS
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[0005] Reference will now be made, by way of example, to the
accompanying drawings which show example embodiments of the present
application, and in which:
[0006] Figure 1 is a schematic illustration of an embodiment of a
system of the present disclosure;
[0007] Figure 2 is a perspective view of a flow diverter according
to an
example embodiment of the present disclosure;
[0008] Figure 3 top view of the flow diverter of Figure 2;
[0009] Figure 4 is a side cross-sectional view of the flow diverter
of
Figure 3, taken along section line A-A of Figure 3;
[0010] Figure 5 is a perspective view of a section of the body of
the
flow diverter of Figure 3;
[0011] Figure 6 is a view of one side of the section illustrated in
Figure
6;
[0012] Figure 7 is a cross-sectional view of another side of the section
of Figure 6 taken along section line A-A of Figure 6;
[0013] Figure 8 is a view of another side of the section
illustrated in
Figure 6, with the view having being rotated 180 degrees relative to the view
illustrated in Figure 6;
[0014] Figure 9 is a perspective view of an arcuate shell section of the
body co-operator of the flow diverter of Figure 2;
[0015] Figure 10 is a side view of the body co-operator of Figure
9;
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[0016] Figure 11 is an end view of the body co-operator of Figure
9;
[0017] Figure 12 is a cross-sectional view of the body co-operator
of
Figure 10, taken along section line A-A of Figure 11; and
[0018] Figures 13, 14, and 15 are identical to Figures 2, 3, and 4,
respectively, and schematically illustrate the flows through the flow diverter
during production.
[0019] Similar reference numerals may have been used in different
figures to denote similar components.
DESCRIPTION OF EXAMPLE EMBODIMENTS
[0020] Referring to Figures 1-15 there is provided a system for
producing hydrocarbons from an oil reservoir within a subterranean
formation 100.
[0021] A wellbore 102 of a subterranean formation can be straight,
curved or branched. The wellbore can have various wellbore sections. A
wellbore section is an axial length of a wellbore 102. A wellbore section can
be characterized as "vertical" or "horizontal" even though the actual axial
orientation can vary from true vertical or true horizontal, and even though
the axial path can tend to "corkscrew" or otherwise vary. In some
embodiments, for example, the central longitudinal axis of the passage of a
horizontal section is disposed along an axis that is between about 70 and
about 110 degrees relative to the vertical, while the central longitudinal
axis
of the passage of a vertical section is disposed along an axis that is less
than
about 20 degrees from the vertical "V", and a transition section is disposed
between the horizontal and vertical sections.
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[0022] "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. Reservoir fluid may also include
fluids injected into the reservoir for effecting stimulation of resident
fluids
within the reservoir.
[0023] A wellbore string 200 is emplaced within the wellbore 102 for
stabilizing the subterranean formation 100. In some embodiments, for
example, the wellbore string 200 also contributes to effecting fluidic
isolation
of one zone within the subterranean formation 100 from another zone within
the subterranean formation 100.
[0024] The fluid productive portion of the wellbore 102 may be
completed either as a cased-hole completion or an open-hole completion.
[0025] With respect to a cased-hole completion, in some embodiments,
for example, a wellbore string 200, 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.
[0026] Typically, a wellbore 102 contains multiple intervals of
concentric casing strings, successively deployed within the previously run
casing. With the exception of a liner string, casing strings typically run
back
up to the surface 104. Typically, casing string sizes are intentionally
minimized to minimize costs during well construction. Generally, smaller
casing sizes make production and artificial lifting more challenging.
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[0027] 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 tubing string may be sealed at the bottom by a packer.
[0028] 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.
[0029] 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
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stung into the liner string, thereby providing a fluid passage for conducting
the produced reservoir fluid to the wellhead 106.
[0030] An open-hole completion is effected by drilling down to the
producing formation, and then lining the wellbore (such as, for example, with
a wellbore string 200). 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.
[0031] The system 10 receives, via the wellbore 102, the reservoir
fluid
flow from the reservoir 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 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.
[0032] In some embodiments, for example, the system 10 includes a
production assembly 300 disposed within the wellbore 102. The production
assembly 300 is suspended within the wellbore 102 from the wellhead 106.
[0033] The production assembly 300 includes a reservoir fluid
conductor 400, a flow diverter 500, a sealed interface effector 600, and a
gas-depleted reservoir fluid conductor 700. The gas-depleted reservoir fluid
conductor 700 includes a pump 800 for pressurizing the gas-depleted
reservoir fluid being conducted through the gas-depleted reservoir fluid
conductor 700.
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[0034] The production assembly 300 is configured for producing
reservoir fluid while, amongst other things, mitigating gas lock within the
pump 800.
[0035] In this respect, the reservoir fluid conductor 400 includes a
reservoir fluid receiver 402 for receiving reservoir fluid which has become
emplaced within a downhole-disposed space 110 of the wellbore 102 after
having been conducted from the subterranean formation 100. The reservoir
fluid conductor 400 defines a reservoir fluid-conducting passage 404 for
conducting the received reservoir fluid to the flow diverter 500. In this
respect, the reservoir fluid conductor 400 is coupled to the flow diverter
500.
The flow diverter 500 includes a reservoir fluid receiver 502, and the
coupling
of the reservoir fluid conductor 400 is with effect that the reservoir fluid-
conducting passage 404 is disposed in flow communication with the reservoir
fluid receiver 502 for supplying the reservoir fluid as flow 902.
[0036] The flow diverter 500 further includes a reservoir fluid discharge
communicator 504 for discharging reservoir fluid into an uphole wellbore
space 108 of the wellbore 102. While the assembly 300 is disposed in the
production effective orientation, the reservoir fluid discharge communicator
504 is disposed vertically above the reservoir fluid receiver 502. In some
embodiments, for example, the central axis of the reservoir fluid discharge
communicator 504 is disposed at an angle of less than 20 degrees relative to
the central longitudinal axis of the wellbore 102.
[0037] The uphole wellbore space 108 is disposed vertically above
the
downhole wellbore space 110. In some embodiments, for example, the
uphole wellbore space 108 is disposed within a vertical portion of the
wellbore 102. In some embodiments, for example, the uphole-disposed
space 108 spans a continuous space extending from the assembly 300 to the
wellbore string 200, and the continuous space extends outwardly relative to
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the central longitudinal axis of the assembly 300. In some embodiments, for
example, the uphole-disposed space 108 spans a continuous space extending
from the assembly 300 to the wellbore string 200, and the continuous space
extends outwardly relative to the central longitudinal axis of the wellbore
102. In some embodiments, for example, the reservoir fluid discharging
communicator 504 is disposed immediately below the uphole-disposed space
108.
[0038] In some embodiments, for example, the discharging is with
effect that the discharged reservoir fluid becomes disposed vertically above
the reservoir fluid discharge communicator 504. While the reservoir fluid is
disposed within the uphole-disposed space 108, a gas-depleted reservoir
fluid is separated from the reservoir fluid in response to at least buoyancy
forces.
[0039] The flow diverter 500 further defines a reservoir fluid-
conducting passage 506. The reservoir fluid-conducting passage 506 effects
flow communication between the reservoir fluid receiver 502 and the
reservoir fluid discharge communicator 504, for conducting the received
reservoir fluid from the reservoir fluid receiver 502 to the reservoir fluid
discharge communicator 504.
[0040] In some embodiments, for example, while the assembly 300 is
disposed within the wellbore 102 in the production effective orientation, the
reservoir fluid-conducting passage 404, the reservoir fluid-conducting
passage 506, and the uphole-disposed space 108 are co-operatively
configured such that, in operation, while the reservoir fluid is being
supplied
to the uphole-disposed space 108 via the reservoir fluid discharging
communicator 504, the velocity of the gaseous portion of the reservoir fluid,
being conducted via the reservoir fluid-conducting passage 404, and the
reservoir fluid-conducting passage 506, is greater than the critical liquid
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lifting velocity, such that separation of gases and liquids is mitigated, and
while the reservoir fluid is disposed within the uphole-disposed space 108,
the velocity of the gaseous portion of the reservoir fluid is sufficiently low
such that the above-described separation, within the uphole-disposed space
108, is effected.
[0041] In this respect, in some embodiments, for example, for each
one of the reservoir fluid-conducting passages 404, 506, the maximum
cross-sectional flow area is smaller than the minimum cross-sectional flow
area of the uphole-disposed space 108. In some of these embodiments, for
example, the ratio of the minimum cross-sectional flow area of the uphole-
disposed space 108 to the maximum cross-sectional flow area of the
reservoir fluid conducting passage 404 is at least 1.5, and the ratio of the
minimum cross-sectional flow area of the uphole-disposed space 108 to the
maximum cross-sectional flow area of the reservoir fluid conducting passage
506 is at least 1.5. In some embodiments, for example, the reservoir fluid
conductor 400 is a velocity string.
[0042] The flow diverter 500 further defines a gas-depleted
reservoir
fluid receiver 508 for receiving the gas-depleted reservoir fluid that has
been
separated from the reservoir fluid. While the assembly 300 is disposed
within the wellbore 102 in the production effective orientation, the gas-
depleted reservoir fluid receiver 508 is disposed vertically below the
reservoir
fluid discharging communicator 506.
[0043] In some embodiments, for example, flow of the separated gas-
depleted reservoir fluid is conductible to the gas-depleted reservoir fluid
communicator 508 via an established flow communication between the
uphole-disposed space 108 and the gas-depleted reservoir fluid receiving
communicator 508. In this respect, in some embodiments, for example, the
wellbore string 200 and the assembly 300 are co-operatively configured such
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that, while the assembly 300 is disposed within the wellbore string 200 in the
production effective orientation: (i) the gas-depleted reservoir fluid
receiving
communicator 508 is disposed below the reservoir fluid discharging
communicator 410, (ii) an intermediate fluid passage 112 is established
between the assembly 300 and the wellbore string 200 and effects flow
communication between the reservoir fluid discharging communicator 506
(and, therefore, the uphole wellbore space 108) and the gas-depleted
reservoir fluid receiving communicator 508. By virtue of the flow
communication that is effected between the reservoir fluid discharging
communicator 506 and the gas-depleted reservoir fluid receiving
communicator 508 by the intermediate fluid passage 112, a gas-depleted
reservoir fluid flow is conductible downhole for receiving by the gas-depleted
reservoir fluid receiving communicator 508. In some embodiments, for
example, the separating of gaseous material from the reservoir fluid includes
separating that is effected while the reservoir fluid is being conducted
downhole via the intermediate passage 112.
[0044] In some embodiments, for example, the intermediate fluid
passage 112 is an annular space disposed between the assembly 300 and the
wellbore string 200. In some embodiments, for example, the intermediate
fluid passage 112 is defined by the space that extends outwardly, relative to
the central longitudinal axis of the assembly 300, from an outermost surface
of the assembly 300 to the wellbore string 200. In some embodiments, for
example, the intermediate wellbore passage 112 extends longitudinally to
the wellhead 106, between the assembly 300 and the wellbore string 200.
[0045] In some embodiments, for example, the flow diverter 500
defines an intermediate fluid passage-defining outermost surface 501 which
co-operates with the wellbore string 200 for establishing the intermediate
fluid passage 112. In this respect, the intermediate fluid passage 112 is
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disposed between the intermediate fluid passage-defining outermost surface
501 of the flow diverter 500 and the wellbore string 200.
[0046] In some embodiments, for example, the wellbore string 200
and
the assembly 300 are further co-operatively configured such that, while the
assembly 300 is disposed within the wellbore string 200 in a production
effective orientation, in response to sealing disposition of the sealed
interface effector 600 relative to the wellbore string 200, a sealed interface
602 is defined, and bypassing of the gas-depleted reservoir fluid receiving
communicator 508, by the separated gas-depleted reservoir fluid, is
prevented by the sealed interface 602. In this respect, in some
embodiments, for example, the sealed interface 602 is established within the
wellbore 102 above the downhole wellbore space 110 and below the gas-
depleted reservoir fluid receiver 508. In some embodiments, for example,
the disposition of the sealed interface 602 is such that flow communication,
via the intermediate wellbore passage 112, between the uphole wellbore
space 108 and the downhole wellbore space 110, is prevented. In this
respect, the sealed interface functions to prevent, the gas-depleted reservoir
fluid from bypassing the gas-depleted reservoir fluid receiving communicator
508, and, accordingly, diverts the flow of the gas-depleted reservoir fluid to
the gas-depleted reservoir fluid receiver 508.
[0047] In some embodiments, for example, the sealed interface 602
is
disposed within a vertical section of the wellbore 102. In some
embodiments, for example, the sealed interface effector 600 includes a
packer.
[0048] The flow diverter 500 further defines a gas-depleted reservoir
fluid discharge communicator 510. While the assembly 300 is disposed in
the production effective orientation, the gas-depleted reservoir fluid
discharge communicator 510 is disposed above the gas-depleted reservoir
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fluid receiver 508. The gas-depleted reservoir fluid receiver 508 is disposed
in flow communication with the gas-depleted reservoir fluid discharge
communicator 510 via a gas-depleted reservoir fluid-conducting passage
512. In this respect, the flow diverter 500 defines the gas-depleted reservoir
fluid-conducting passage 512, and isolates flow of the gas-depleted reservoir
fluid, through the flow diverter 500, from contemporaneous flow of reservoir
fluid through the flow diverter 500 via the reservoir fluid-conducting passage
506.
[0049] The gas-depleted reservoir fluid is discharged, via the gas-
depleted reservoir fluid discharge communicator 510, from the flow diverter
500 and to the gas-depleted reservoir fluid conductor 700 for conducting to
the surface 104 as flow 904. In this respect, the gas-depleted reservoir fluid
conductor 700 is fluidly coupled to the reservoir fluid discharge
communicator 510.
[0050] The pump 800 forms part of the gas-depleted reservoir fluid
conductor 700. In this respect, the gas-depleted reservoir fluid conductor
700 includes an upstream conductor portion 702 and a downstream
conductor portion 704. The upstream conductor portion 702 extends from
the gas-depleted reservoir fluid discharge communicator 510 to the suction
802 of the pump 800. The downstream conductor portion 704 extends from
the discharge 804 of the pump 800 to the surface 104.
[0051] The separation of the gaseous material from the reservoir
fluid
is also with effect that a liquid-depleted reservoir fluid is obtained. The
liquid-
depleted reservoir fluid is conducted uphole, in the gaseous phase, or at
least
primarily in the gaseous phase, with relatively small amounts of entrained
liquid, as gaseous flow 906 via the intermediate fluid passage 112 that is
disposed between the assembly 300 and the wellbore string 200.
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[0052] 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 at the surface 104
from the wellbore 102 through the wellhead 106 to a collection facility, such
as a storage tank within a battery.
[0053] With reference now to Figures 2 - 15, there is shown an
example embodiment of the flow diverter 500. The flow diverter 500
includes a body 500A and a body co-operator 500B. The body co-operator
500B is joined to the body 500A at a joint 514. In some embodiments, for
example, the joining of the body co-operator 500B to the body 500 is to an
outermost surface 524 of the body.
[0054] In some embodiments, for example, the body co-operator 500B
is defined by a plurality of sections. In this respect, in some embodiments,
for example, the body co-operator 500B includes an arcuate shell section 550
and an end cap 552. The end cap 552 is joined to one end 551 of the
arcuate shell section 550 for sealing the end 551.
[0055] The body 500A defines the reservoir fluid receiving
communicator 502, the gas-depleted reservoir fluid receiving communicator
508, the gas-depleted reservoir fluid-conducting passage 512, and the gas-
depleted reservoir fluid discharging communicator 510.
[0056] The body 500A and the body co-operator 500B co-operate to
define an externally-disposed reservoir fluid conducting passage 520. The
externally-disposed reservoir fluid conducting passage 520 is disposed
externally of the body 500A. The externally-disposed reservoir fluid
conducting passage 520 is defined, in part, by the outermost surface 524 of
the body 500A. In some embodiments, for example, the externally-disposed
reservoir fluid conducting passage 520 has a length of at least 12 inches,
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measured along the central longitudinal axis 522 of the externally-disposed
reservoir fluid conducting passage 520. In some embodiments, for example,
the externally-disposed reservoir fluid conducting passage 520 is defined
between the body co-operator 500B and the body 500A.
[0057] At least a portion of the reservoir fluid conducting fluid passage
506 is defined by the externally-disposed reservoir fluid conducting passage
520. In some embodiments, for example, the body 500A further defines a
body-defined reservoir fluid conducting passage 526, and the reservoir fluid-
conducting passage 506 further includes the body-defined flow reservoir fluid
conducting passage 526, such that the body-defined reservoir fluid-
conducting passage 526 is disposed in flow communication with the
externally-disposed reservoir fluid conducting passage 520. In some
embodiments, for example, the flow communication is established via an
externally-disposed reservoir fluid conducting passage communicator 528,
which is defined by the body 500A. In some embodiments, for example, the
externally-disposed reservoir fluid conducting passage communicator 528 is
defined within the outermost surface 524 of the body 500A.
[0058] In some embodiments, for example, the co-operation of the
body 500A and the body co-operator 500B is with additional effect that the
reservoir fluid discharging communicator 504 is defined by the joining of the
body 500A and the body co-operator 500B.
[0059] The body co-operator 500B defines an outermost surface 516.
[0060] In some embodiments, for example, the outermost surface 516
of the body co-operator 500B defines a convex surface portion 532. The
convex surface portion 532, of the outermost surface 516 of the body co-
operator 500B, is a continuous surface portion, of the outermost surface 516
of the body co-operator 500B. The convex surface portion 532 is convex
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relative to the central longitudinal axis 522 of the externally-disposed
reservoir fluid conducting passage 520.
[0061] In some embodiments, for example, the outermost surface 516
has a dimension, measured along a plane to which the central longitudinal
axis 522 of the externally-disposed reservoir fluid conducting passage 520 is
perpendicular, of at least 1.5 inches. In some embodiments, for example,
the outermost surface 516 has a dimension, measured along a plane to
which the central longitudinal axis 522 of the externally-disposed reservoir
fluid conducting passage 520 is coincident, of at least 12 inches.
[0062] In some embodiments, for example, the outermost surface 516
has a surface area of at least 40 square inches. In some embodiments, for
example, the convex surface portion 532 defines at least 70% of the
outermost surface 516. In some embodiments, for example, the convex
surface portion 532 defines at least 80% of the outermost surface 516. In
some embodiments, for example, the convex surface portion 532 defines at
least 90% of the outermost surface 516. In some embodiments, for
example, the convex surface portion 532 defines the entirety of the
outermost surface 516.
[0063] The joining of the body co-operator 500B to the body 500 is
with effect that at least a portion of the intermediate passage-defining
outermost surface 501 of the flow diverter 500 is defined by the convex
surface portion 532 of the outermost surface 516 of the body co-operator
500B, such that the at least a portion of the intermediate passage-defining
outermost surface 501 of the flow diverter 500 defines the convex surface
portion 532.
Date Recue/Date Received 2021-04-19
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[0064] In some embodiments, for example, the convex surface portion
532 of the outermost surface 516 of the body co-operator 500B defines at
least one outermost surface-defined arc 518.
[0065] Each one of the at least one outermost surface-defined arc
518,
independently, extends outwardly relative to the central longitudinal axis 522
of the externally-disposed reservoir fluid conducting passage 520.
[0066] In some embodiments, for example, each one of the at least
one outermost surface-defined arc 518, independently, has a minimum arc
length of at least 1.5 inches.
[0067] Referring to Figures 11 and 12, in some embodiments, for
example, each one of the at least one outermost surface-defined arc 518,
independently, is disposed within a respective arc-defining plane 530 that
traverses the central longitudinal axis 522 of the externally-disposed
reservoir fluid conducting passage 520, such that at least one arc-defining
plane is defined. In some embodiments, for example, for each one of the at
least one arc-defining plane 530, independently, the central longitudinal axis
522 of the externally-disposed reservoir fluid conducting passage 520 is
disposed, relative to the arc-defining plane 530, at an angle selected from
the group consisting of: (i) 90 degrees, and (b) an acute angle of greater
than 45 degrees. In some embodiments, for example, for each one of the at
least one arc-defining plane 530, independently, the central longitudinal axis
522, of the externally-disposed reservoir fluid conducting passage 520, is
orthogonal to the arc-defining plane 530.
[0068] In some embodiments, for example, each one of the at least
one outermost surface-defined arc, independently, is a circular arc.
Date Recue/Date Received 2021-04-19
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[0069] In some embodiments, for example, the body co-operator 500B
defines an innermost surface 534, and the innermost surface 534 defines a
concave surface portion 536. The concave surface portion 536, of the
innermost surface 534 of the body co-operator 500B, is a continuous surface
portion, of the innermost surface 534 of the body co-operator 500B. The
concave surface portion 536 is concave relative to the central longitudinal
axis 522 of the externally-disposed reservoir fluid conducting passage 520.
[0070] In some embodiments, for example, the concave surface
portion
536 of the innermost surface 534 of the body co-operator 500B defines at
least one innermost surface-defined arc 540.
[0071] Each one of the at least one innermost surface-defined arc
540,
independently, extends outwardly relative to the central longitudinal axis 522
of the externally-disposed reservoir fluid conducting passage 520.
[0072] In some embodiments, for example, each one of the at least
one innermost surface-defined arc 540, independently, has a minimum arc
length of at least one (1) inch.
[0073] Referring to Figures 11 and 12, in some embodiments, for
example, each one of the at least one innermost surface-defined arc 540,
independently, is disposed within a respective arc-defining plane 530 that
traverses the central longitudinal axis 522 of the externally-disposed
reservoir fluid conducting passage 520, such that at least one arc-defining
plane is defined. In some embodiments, for example, for each one of the at
least one arc-defining plane 530, independently, the central longitudinal axis
522 of the externally-disposed reservoir fluid conducting passage 520 is
disposed, relative to the arc-defining plane 530, at an angle selected from
the group consisting of: (i) 90 degrees, and (b) an acute angle "X" of greater
than 45 degrees. In some embodiments, for example, for each one of the at
Date Recue/Date Received 2021-04-19
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least one arc-defining plane 530, independently, the central longitudinal axis
522, of the externally-disposed reservoir fluid conducting passage 520, is
orthogonal to the arc-defining plane 530.
[0074] In some embodiments, for example, each one of the at least
one innermost surface-defined arc 540, independently, is a circular arc.
[0075] In some embodiments, for example, the innermost surface 534
of the body co-operator 500B defines, in part, the external reservoir fluid
conducting fluid passage 520.
[0076] In some embodiments, for example, relative to the convex
surface portion 532, the concave surface portion 536 is disposed on an
opposite side of the body co-operator 500B. In some embodiments, for
example, a thickness of an arcuate wall portion 538 of the body co-operator
500B is defined by the minimum distance from the convex surface portion
532 to the concave surface portion 536, and the maximum thickness of the
arcuate wall portion of the body co-operator is less than 0.1 inches.
[0077] In the above description, for purposes of explanation,
numerous
details are set forth in order to provide a thorough understanding of 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. Therefore, it will be understood
that certain adaptations and modifications of the described embodiments can
be made and that the above discussed embodiments are considered to be
illustrative and not restrictive. All references mentioned are hereby
incorporated by reference in their entirety.
Date Recue/Date Received 2021-04-19
