Note: Descriptions are shown in the official language in which they were submitted.
SYSTEMS FOR DOVVNHOLE SEPARATION OF GASES FROM LIQUIDS
HAVING INTERCHANGEABLE FLUID CONDUCTORS
FIELD
[0001] The present disclosure relates to mitigating downhole pump gas
interference during
hydrocarbon production.
BACKGROUND
[0002] Downhole pump gas interference is a problem encountered while
producing wells,
especially wells with horizontal sections. In producing reservoir fluids
containing a significant
fraction of gaseous material, the presence of such gaseous material hinders
production by
contributing to sluggish flow.
SUMMARY
[0003] In one aspect, there is provided a reservoir fluid production
assembly for producing
reservoir fluid from a subterranean formation via a wellbore that is lined
with a wellbore string,
wherein the wellbore includes a wellbore space, the wellbore space includes a
downhole
wellbore space and an uphole wellbore space, and the uphole wellbore space is
disposed uphole
relative to the downhole wellbore space, wherein the assembly includes:
a reservoir fluid-supplying conductor;
an assembly-defining flow diverter counterpart configured for co-operating
with a
wellbore string-defining flow diverter counterpart of the wellbore string to
define a flow diverter
including: (i) a reservoir fluid-diverting conductor, (ii) a gas-depleted
reservoir fluid-diverting
conductor, and (iii) a sealed interface effector for engaging the wellbore
string such that a sealed
interface is defined for preventing, or substantially preventing, flow
communication, between the
downhole wellbore space and the uphole wellbore space; and
a pump;
wherein:
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the assembly is configured for co-operation with the wellbore string such
that,
while the assembly is disposed within the wellbore such that an intermediate
wellbore
space is disposed between the assembly and the wellbore string and such that
the sealed
interface is defined, and the downhole wellbore space is receiving reservoir
fluid from the
subterranean formation:
the reservoir fluid is conducted by the reservoir fluid supplying-conductor
to the reservoir fluid-diverting conductor;
the reservoir fluid that is being received by the reservoir fluid-diverting
conductor is conducted by the reservoir fluid-diverting conductor to a
reservoir
fluid separation space of the uphole wellbore space;
within the reservoir fluid separation space, a gas-depleted reservoir fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy
forces, such that a gas-depleted reservoir fluid is obtained;
the separated gas-depleted reservoir fluid is conducted, via the
intermediate wellbore passage, to the gas-depleted reservoir fluid-diverting
conductor; and
the separated gas-depleted reservoir fluid that is being received by the gas-
depleted reservoir fluid-diverting conductor is conducted by the gas-depleted
reservoir fluid-diverting conductor to the pump for pressurizing by the pump;
the reservoir fluid-supplying conductor is releasably retained relative to the
assembly-defined flow diverter counterpart;
and
while the assembly is disposed within a wellbore, the reservoir fluid-
supplying
conductor is releasable from the retention relative to the assembly-defined
flow diverter
counterpart by a downhole tool.
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[0004] In
another aspect, there is provided parts for assembly of a reservoir fluid
production
assembly for producing reservoir fluid from a subterranean formation via a
wellbore that is lined
with a wellbore string, wherein the wellbore includes a wellbore space, the
wellbore space
includes a downhole wellbore space and an uphole wellbore space, and the
uphole wellbore
space is disposed uphole relative to the downhole wellbore space, wherein the
assembly
includes:
a reservoir fluid-supplying conductor;
an assembly-defining flow diverter counterpart configured for co-operating
with a
wellbore string-defining flow diverter counterpart of the wellbore string to
define a flow diverter
including: (i) a reservoir fluid-diverting conductor, (ii) a gas-depleted
reservoir fluid-diverting
conductor, and (iii) a sealed interface effector for engaging the wellbore
string such that a sealed
interface is defined for preventing, or substantially preventing, flow
communication, between the
downhole wellbore space and the uphole wellbore space; and
a pump;
wherein:
the assembly is configured for co-operation with the wellbore string such
that,
while the assembly is disposed within the wellbore such that an intermediate
wellbore
space is disposed between the assembly and the wellbore string and such that
the sealed
interface is defined, and the downhole wellbore space is receiving reservoir
fluid from the
subterranean formation:
the reservoir fluid is conducted by the reservoir fluid supplying-conductor
to the reservoir fluid-diverting conductor;
the reservoir fluid that is being received by the reservoir fluid-diverting
conductor is conducted by the reservoir fluid-diverting conductor to a
reservoir
fluid separation space of the uphole wellbore space;
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within the reservoir fluid separation space, a gas-depleted reservoir fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy
forces, such that a gas-depleted reservoir fluid is obtained;
the separated gas-depleted reservoir fluid is conducted, via the
intermediate wellbore passage, to the gas-depleted reservoir fluid-diverting
conductor; and
the separated gas-depleted reservoir fluid that is being received by the gas-
depleted reservoir fluid-diverting conductor is conducted by the gas-depleted
reservoir fluid-diverting conductor to the pump for pressurizing by the pump;
wherein the parts comprise:
first, second, third, and fourth assembly counterparts;
the assembly-defined flow diverter counterpart includes first and second
assembly-defined flow diverter counterparts;
the first assembly counterpart includes the first assembly-defined flow
diverter
counterpart;
the second assembly counterpart includes the second assembly-defined flow
diverter counterpart;
the third assembly counterpart includes a reservoir fluid supplying conductor
that
is a first reservoir fluid-supplying conductor;
the fourth assembly counterpart includes a reservoir fluid supplying conductor
that is a second reservoir fluid-supplying conductor;
each one of the second, third, and fourth assembly counterparts is configured
for
releasable retention relative to the first assembly counterpart; and
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the first, second, third, and fourth assembly counterparts are co-operatively
configured such that:
while the assembly is disposed within the wellbore and includes the first,
second
and third assembly counterparts, and the second and third assembly
counterparts are
releasably retained relative to the first assembly counterpart,
interchangeability of the
third assembly counterpart with the fourth assembly counterpart, by the second
assembly
counterpart, is prevented; and
while the assembly is disposed within the wellbore and includes the first,
second
and third assembly counterparts, and the second and third assembly
counterparts are
releasably retained relative to the first assembly counterpart, in response to
release of the
second assembly counterpart from retention relative to the first assembly
counterpart, the
prevention of the interchangeability of the third assembly counterpart with
the fourth
assembly counterpart, by the second assembly counterpart, is defeated.
[0005] In
another aspect, there is provided a process for producing reservoir fluid from
a
subterranean formation comprising:
for a first time interval, while inducing displacement of reservoir fluid from
the subterranean
formation into a wellbore, within the wellbore:
via a first reservoir fluid-supplying conductor, conducting the reservoir
fluid to a gas
separator;
via the gas separator, separating gaseous material from the reservoir fluid
such that gas-
depleted reservoir fluid is obtained; and
conducting the gas-depleted reservoir fluid to the surface;
after completion of the first time interval, suspending the inducing of
displacement of the
reservoir fluid from the subterranean formation to the wellbore;
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while the inducing of displacement of reservoir fluid from the subterranean
formation to the
wellbore is suspended, replacing the first reservoir fluid-supplying conductor
with a second
reservoir fluid- supplying conductor; and
after the first reservoir fluid-supplying conductor has been replaced with a
second reservoir
fluid- supplying conductor, resuming inducement of displacement of reservoir
fluid from the
subterranean formation to the wellbore such that, within the wellbore, the
reservoir fluid is
conducted, via a first reservoir fluid-supplying conductor, a gas separator,
with effect that
gaseous material is separated from the reservoir fluid by the gas separator
such that gas-depleted
reservoir fluid is obtained and conducted to the surface.
[0006] In
another aspect, there is provided a reservoir fluid production assembly for
producing reservoir fluid from a subterranean formation via a wellbore that is
lined with a
wellbore string, wherein the wellbore includes a wellbore space, the wellbore
space includes a
downhole wellbore space and an uphole wellbore space, and the uphole wellbore
space is
disposed uphole relative to the downhole wellbore space, wherein the assembly
includes:
a reservoir fluid-supplying conductor;
an assembly-defined flow diverter counterpart which is configured to co-
operate with a
wellbore string-defined flow diverter counterpart, of the wellbore string, to
define a flow diverter
within the wellbore, wherein the flow diverter includes: (i) a reservoir fluid-
conducting passage
that is fluidly coupled to the reservoir fluid-supplying conductor, and (ii) a
gas-depleted reservoir
fluid-conducting passage; and
a pump disposed in fluid communication with the gas-depleted reservoir fluid-
conducting
passage;
wherein:
the assembly is configured for co-operation with the wellbore string such
that,
while the assembly is disposed within the wellbore such that the flow diverter
is defined,
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and the downhole wellbore space is receiving reservoir fluid from the
subterranean
formation:
the reservoir fluid is conducted by the reservoir fluid supplying-conductor
to the reservoir fluid-conducting passage of the flow diverter;
the reservoir fluid, that is being received by the reservoir fluid-conducting
passage, is conducted by the reservoir fluid-conducting passage to a reservoir
fluid separation space of the uphole wellbore space;
within the reservoir fluid separation space, a gas-depleted reservoir fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy
forces, such that a gas-depleted reservoir fluid is obtained; and
the gas-depleted reservoir fluid-conducting passage receives the separated
gas-depleted reservoir fluid, that is flowing in a downhole direction, and
diverts
the flow of the received gas-depleted reservoir fluid such that the received
gas-
depleted reservoir fluid is conducted by the gas-depleted reservoir fluid-
conducting passage in the uphole direction to the pump for pressurizing by the
pump;
the reservoir fluid-supplying conductor is releasably retained relative to the
assembly-defined flow diverter counterpart;
and
while the assembly is disposed within a wellbore, the reservoir fluid-
supplying
conductor is releasable from the retention relative to the assembly-defined
flow diverter
counterpart by a downhole tool.
[0007] In
another aspect, there is provided parts for assembly of a reservoir fluid
production
assembly for producing reservoir fluid from a subterranean formation via a
wellbore that is lined
with a wellbore string, wherein the wellbore includes a wellbore space, the
wellbore space
includes a downhole wellbore space and an uphole wellbore space, and the
uphole wellbore
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space is disposed uphole relative to the downhole wellbore space, wherein the
assembly
includes:
a reservoir fluid-supplying conductor;
an assembly-defined flow diverter counterpart which is configured to co-
operate with a wellbore
string-defined flow diverter counterpart, of the wellbore string, to define a
flow diverter within
the wellbore, wherein the flow diverter includes: (i) a reservoir fluid-
conducting passage that is
fluidly coupled to the reservoir fluid-supplying conductor, and (ii) a gas-
depleted reservoir fluid-
conducting passage; and
a pump disposed in fluid communication with the gas-depleted reservoir fluid-
conducting
passage;
wherein:
the assembly is configured for co-operation with the wellbore string such
that, while the
assembly is disposed within the wellbore such that the flow diverter is
defined, and the downhole
wellbore space is receiving reservoir fluid from the subterranean formation:
the reservoir fluid is conducted by the reservoir fluid supplying-conductor to
the reservoir
fluid-conducting passage of the flow diverter;
the reservoir fluid, that is being received by the reservoir fluid-conducting
passage, is
conducted by the reservoir fluid-conducting passage to a reservoir fluid
separation space of the
uphole wellbore space;
within the reservoir fluid separation space, a gas-depleted reservoir fluid is
separated
from the discharged reservoir fluid, in response to at least buoyancy forces,
such that a gas-
depleted reservoir fluid is obtained; and
the gas-depleted reservoir fluid-conducting passage receives the separated gas-
depleted
reservoir fluid, that is flowing in a downhole direction, and diverts the flow
of the received gas-
depleted reservoir fluid such that the received gas-depleted reservoir fluid
is conducted by the
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gas-depleted reservoir fluid-conducting passage in the uphole direction to the
pump for
pressurizing by the pump;
wherein:
the parts comprise first, second, third, and fourth assembly counterparts;
the assembly-defined flow diverter counterpart includes first and second
assembly-
defined flow diverter counterparts;
the first assembly counterpart includes the first assembly-defined flow
diverter
counterpart;
the second assembly counterpart includes the second assembly-defined flow
diverter
counterpart;
the third assembly counterpart includes a reservoir fluid supplying conductor
that is a
first reservoir fluid-supplying conductor;
the fourth assembly counterpart includes a reservoir fluid supplying conductor
that is a
second reservoir fluid-supplying conductor;
each one of the second, third, and fourth assembly counterparts is configured
for
releasable retention relative to the first assembly counterpart; and
the first, second, third, and fourth assembly counterparts are co-operatively
configured
such that:
while the assembly is disposed within the wellbore and includes the first,
second
and third assembly counterparts, and the second and third assembly
counterparts are
releasably retained relative to the first assembly counterpart,
interchangeability of the
third assembly counterpart with the fourth assembly counterpart, by the second
assembly
counterpart, is prevented; and
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while the assembly is disposed within the wellbore and includes the first,
second
and third assembly counterparts, and the second and third assembly
counterparts are
releasably retained relative to the first assembly counterpart, in response to
release of the
second assembly counterpart from retention relative to the first assembly
counterpart, the
prevention of the interchangeability of the third assembly counterpart with
the fourth
assembly counterpart, by the second assembly counterpart, is defeated.
[0008] In
another aspect, there is provided a method of deploying a reservoir fluid
production assembly downhole within a wellbore;
wherein the reservoir fluid production assembly is for producing reservoir
fluid from a
subterranean formation via a wellbore that is lined with a wellbore string,
wherein the wellbore
includes a wellbore space, the wellbore space includes a downhole wellbore
space and an uphole
wellbore space, and the uphole wellbore space is disposed uphole relative to
the downhole
wellbore space, wherein the assembly includes:
a reservoir fluid-supplying conductor;
an assembly-defined flow diverter counterpart which is configured to co-
operate with a
wellbore string-defined flow diverter counterpart, of the wellbore string, to
define a flow diverter
within the wellbore, wherein the flow diverter includes: (i) a reservoir fluid-
conducting passage
that is fluidly coupled to the reservoir fluid-supplying conductor, (ii) a gas-
depleted reservoir
fluid-conducting passage, and (iii) an actuatable sealed interface effector
for engaging the
wellbore string for establishing a sealed interface within the wellbore for
preventing, or
substantially preventing, flow communication between the uphole wellbore space
and the
downhole wellbore space; and
a pump disposed in fluid communication with the gas-depleted reservoir fluid-
conducting
passage;
wherein:
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the assembly is configured for co-operation with the wellbore string such
that,
while the assembly is disposed within the wellbore such that the flow diverter
is defined,
and the downhole wellbore space is receiving reservoir fluid from the
subterranean
formation:
the reservoir fluid is conducted by the reservoir fluid supplying-conductor
to the reservoir fluid-conducting passage of the flow diverter;
the reservoir fluid, that is being received by the reservoir fluid-conducting
passage, is conducted by the reservoir fluid-conducting passage to a reservoir
fluid separation space of the uphole wellbore space;
within the reservoir fluid separation space, a gas-depleted reservoir fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy
forces, such that a gas-depleted reservoir fluid is obtained; and
the gas-depleted reservoir fluid-conducting passage receives the separated
gas-depleted reservoir fluid, that is flowing in a downhole direction, and
diverts
the flow of the received gas-depleted reservoir fluid such that the received
gas-
depleted reservoir fluid is conducted by the gas-depleted reservoir fluid-
conducting passage in the uphole direction to the pump for pressurizing by the
pump;
wherein the method includes:
emplacing the assembly within the wellbore, with effect that the assembly
becomes
disposed within the wellbore; and
after the assembly has become disposed within the wellbore, actuating the
sealed
interface effector, with effect that the sealed interface is obtained.
BRIEF DESCRIPTION OF DRAWINGS
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[0009] The preferred embodiments will now be described with reference to
the following
accompanying drawings:
[0010] Figure IA is a schematic illustration of an embodiment of a
reservoir fluid production
assembly disposed within a wellbore;
[0011] Figure 1B is a schematic illustration of an embodiment of a flow
diverter of
embodiments of the system of the present disclosure;
[0012] Figure 2A is a schematic illustration of the flow diverter of the
present disclosure;
[0013] Figure 2B is a schematic illustration of the flow diverter of the
present disclosure;
[0014] Figure 3 is a side elevation view of the exterior of flow diverter;
[0015] Figure 4 is a sectional elevation view of the flow diverter in
Figure 3 taken along
lines G-G, showing the flow diverter established by the disposition of a flow
diverter-effecting
insert within the passageway of the insert-receiving part, and with the flow
diverter-effecting
insert releasably coupled by a lock mandrel to the insert-receiving part;
[0016] Figure 5 is an enlarged view of Detail "A" in Figure 4;
[0017] Figure 6A is a side elevation view of the insert-receiving part of a
flow diverter;
[0018] Figure 6B is a sectional elevation view of the insert-receiving part
illustrated in
Figure 6A, taken along lines A-A;
[0019] Figure 6C is an axial view taken along lines B-B in Figure 6A;
[0020] Figure 6D is an axial view taken along lines C-C in Figure 6A;
[0021] Figure 6E is an axial view taken along lines D-D in Figure 6A;
[0022] Figure 7 is an elevation view of one side of the flow diverter-
effecting insert;
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[0023] Figure 8 is a sectional elevation view of the flow diverter-
effecting insert, taken along
lines F-F in Figure 7; and
[0024] Figure 9 is a schematic illustration of the flowpaths within the
flow diverter
illustrated in Figures 4 and 5.
[0025] Figure 10 is a schematic illustration of an embodiment of a system
of the present
disclosure, showing a flow diverter body that is comprised of an insert-
receiving part and a flow
diverter-effecting insert part; and
[0026] Figure 11 is a schematic illustration of the system in Figure 10,
after the pump and
the flow diverter-effecting insert having been removed from the wellbore.
DETAILED DESCRIPTION
[0027] As used herein, the terms "up", "upward", "upper", or "uphole",
mean,
relativistically, in closer proximity to the surface 106 and further away from
the bottom of the
wellbore, when measured along the longitudinal axis of the wellbore 102. The
terms "down",
"downward", "lower", or "downhole" mean, relativistically, further away from
the surface 106
and in closer proximity to the bottom of the wellbore 102, when measured along
the longitudinal
axis of the wellbore 102.
[0028] Referring to Figures 1 A and 1B, there are provided systems 8, with
associated
apparatuses, for producing hydrocarbons from a reservoir, such as an oil
reservoir, within a
subterranean formation 100, when reservoir pressure within the oil reservoir
is insufficient to
conduct hydrocarbons to the surface 106 through a wellbore 102.
[0029] 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
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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.
[0030] "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.
[0031] Fluids may be injected into the oil reservoir through the wellbore
to effect stimulation
of the reservoir fluid. For example, such fluid injection is effected during
hydraulic fracturing,
water flooding, water disposal, gas floods, gas disposal (including carbon
dioxide sequestration),
steam-assisted gravity drainage ("SAGD") or cyclic steam stimulation ("CSS").
In some
embodiments, for example, the same wellbore is utilized for both stimulation
and production
operations, such as for hydraulically fractured formations or for formations
subjected to CSS. In
some embodiments, for example, different wellbores are used, such as for
formations subjected
to SAGD, or formations subjected to waterflooding.
[0032] A wellbore string 113 is employed within the wellbore 102 for
stabilizing the
subterranean formation 100. In some embodiments, for example, the wellbore
string 113 also
contributes to effecting fluidic isolation of one zone within the subterranean
formation 100 from
another zone within the subterranean formation 100.
[0033] The fluid productive portion of the wellbore 102 may be completed
either as a cased-
hole completion or an open-hole completion.
[0034] A cased-hole completion involves running wellbore casing down into
the wellbore
through the production zone. In this respect, in the cased-hole completion,
the wellbore string
113 includes wellbore casing.
[0035] The annular region between the deployed wellbore casing and the oil
reservoir may
be filled with cement for effecting zonal isolation (see below). The cement is
disposed between
the wellbore casing and the oil reservoir for the purpose of effecting
isolation, or substantial
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isolation, of one or more zones of the oil reservoir from fluids disposed in
another zone of the oil
reservoir. Such fluids include reservoir fluid being produced from another
zone of the oil
reservoir (in some embodiments, for example, such reservoir fluid being flowed
through a
production tubing string disposed within and extending through the wellbore
casing to the
surface), or injected fluids such as water, gas (including carbon dioxide), or
stimulations fluids
such as fracturing fluid or acid. In this respect, in some embodiments, for
example, the cement is
provided for effecting sealing, or substantial sealing, of flow communication
between one or
more zones of the oil reservoir and one or more others zones of the oil
reservoir (for example,
such as a zone that is being produced). By effecting the sealing, or
substantial sealing, of such
flow communication, isolation, or substantial isolation, of one or more zones
of the oil reservoir,
from another subterranean zone (such as a producing formation), is achieved.
Such isolation or
substantial isolation is desirable, for example, for mitigating contamination
of a water table
within the oil reservoir by the reservoir fluid (e.g. oil, gas, salt water, or
combinations thereof)
being produced, or the above-described injected fluids.
[0036] In some embodiments, for example, the cement is disposed as a sheath
within an
annular region between the wellbore casing and the oil reservoir. In some
embodiments, for
example, the cement is bonded to both of the production casing and the oil
reservoir.
[0037] In some embodiments, for example, the cement also provides one or
more of the
following functions: (a) strengthens and reinforces the structural integrity
of the wellbore, (b)
prevents, or substantially prevents, produced reservoir fluid of one zone from
being diluted by
water from other zones. (c) mitigates corrosion of the wellbore casing, (d) at
least contributes to
the support of the wellbore casing, and e) allows for segmentation for
stimulation and fluid
inflow control purposes.
[0038] The cement is introduced to an annular region between the wellbore
casing and the oil
reservoir after the subject wellbore casing has been run into the wellbore.
This operation is
known as "cementing".
[0039] In some embodiments, for example, the wellbore casing includes one
or more casing
strings, each of which is positioned within the well bore, having one end
extending from the well
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head. In some embodiments, for example, each casing string is defined by
jointed segments of
pipe. The jointed segments of pipe typically have threaded connections.
[0040] Typically, a wellbore contains multiple intervals of concentric
casing strings,
successively deployed within the previously run casing. With the exception of
a liner string,
casing strings typically run back up to the surface 106. Typically, casing
string sizes are
intentionally minimized to minimize costs during well construction. Generally,
smaller casing
sizes make production and artificial lofting more challenging.
[0041] For wells that are used for producing reservoir fluid, few of these
actually produce
through wellbore casing. This is because producing fluids can corrode steel or
form undesirable
deposits (for example, scales, asphaltenes or paraffin waxes) and the larger
diameter can make
flow unstable. In this respect, a production string is usually installed
inside the last casing string.
The production string is provided to conduct reservoir fluid, received within
the wellbore, to the
wellhead 116. In some embodiments, for example. the annular region between the
last casing
string and the production tubing string may be sealed at the bottom by a
packer.
[0042] To facilitate flow communication between the reservoir and the
wellbore, the
wellbore casing may be perforated, or otherwise include per-existing ports
(which may be
selectively openable, such as, for example, by shifting a sleeve), to provide
a fluid passage for
enabling flow of reservoir fluid from the reservoir to the wellbore.
[0043] In some embodiments, for example, the wellbore casing is set short
of total depth.
Hanging off from the bottom of the wellbore casing, with a liner hanger or
packer, is a liner
string. The liner string can be made from the same material as the casing
string, but, unlike the
casing string, the liner string does not extend back to the wellhead 116.
Cement may be
provided within the annular region between the liner string and the oil
reservoir for effecting
zonal isolation (see below), but is not in all cases. In some embodiments, for
example, this liner
is perforated to effect flow communication between the reservoir and the
wellbore. In this
respect, in some embodiments, for example, the liner string can also be a
screen or is slotted. In
some embodiments, for example, the production tubing string may be engaged or
stung into the
liner string, thereby providing a fluid passage for conducting the produced
reservoir fluid to the
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wellhead 116. In some embodiments, for example, no cemented liner is
installed, and this is
called an open hole completion or uncemented casing completion.
[0044] An open-hole completion is effected by drilling down to the top of
the producing
formation, and then lining the wellbore (such as, for example, with a wellbore
string 113). The
wellbore is then drilled through the producing formation, and the bottom of
the wellbore is left
open (i.e. uncased), to effect flow communication between the reservoir and
the wellbore. Open-
hole completion techniques include bare foot completions, pre-drilled and pre-
slotted liners, and
open-hole sand control techniques such as stand-alone screens, open hole
gravel packs and open
hole expandable screens. Packers and casing can segment the open hole into
separate intervals
and ported subs can be used to effect flow communication between the reservoir
and the
wellbore.
[0045] Referring to Figures 1A, a production assembly 10 is provided for
effecting
production of reservoir fluid from the reservoir 104 of the subterranean
formation 100.
[0046] In some embodiments, for example, a wellbore fluid conductor 113,
such as, for
example, the wellbore string 113 (such as, for example, the casing 113), is
disposed within the
wellbore 102. The assembly 10 is configured for disposition within the
wellbore fluid conductor
113, such that an intermediate wellbore passage 112 is defined within the
wellbore fluid
conductor 113, between the assembly 10 and the wellbore fluid conductor 113.
In some
embodiments, for example, the intermediate wellbore passage 112 is an annular
space disposed
between the assembly 10 and the wellbore string 113. In some embodiments, for
example, the
intermediate wellbore passage 112 is defined by the space that extends
outwardly, relative to the
central longitudinal axis of the assembly 10, from the assembly 10 to the
wellbore fluid
conductor 113. In some embodiments, for example, the intermediate wellbore
passage 112
extends longitudinally to the wellhead 116, between the assembly 10 and the
wellbore string 113.
[0047] The production assembly 10 includes a reservoir fluid-supplying
conductor 12 and an
uphole-disposed reservoir fluid-conducting assembly 14. In some embodiments,
for example,
the reservoir fluid-supplying conductor 12 is in the form of tubing, such as
coiled tubing, or a
substantial portion of the reservoir fluid-supplying conductor 12 is in the
form of tubing, such as
17
CA 3032720 2019-02-05
coiled tubing. In some embodiments, for example, the reservoir fluid-supplying
conductor 12 is
in the form of a hose, such as, for example, a braided hose, or a substantial
portion of the
reservoir fluid-supplying conductor 12 is in the form of a hose, such as, for
example, a braided
hose. In some embodiments, for example, the reservoir fluid-supplying
conductor 12 is
releasably retained relative to the reservoir fluid-supplying conductor 12.
The uphole-disposed
reservoir fluid-conducting assembly 14 defines a passage 14A.
[0048] The reservoir fluid-supplying conductor 12 is configured for
receiving and
conducting reservoir fluid, received within the wellbore 102 from the
subterranean formation, to
the uphole-disposed reservoir fluid-conducting assembly 14.
[0049] The uphole-disposed reservoir fluid-conducting assembly 14 includes
a pump 300 for
receiving reservoir fluid and, through mechanical action, pressurizing
reservoir fluid such that
the pressurized reservoir fluid is conducted uphole, via a reservoir fluid-
producing conductor
210, to an outlet 208 disposed at the surface 106, and thereby effect
production of the reservoir
fluid. It is understood that the reservoir fluid being conducted uphole
through the wellbore 102,
via the assembly 10, may be additionally energized by supplemental means,
including by gas-lift.
In some embodiments, for example, the pump 300 is a sucker rod pump. Other
suitable pumps
300 include screw pumps, electrical submersible pumps, and jet pumps.
[0050] 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
reservoir 104. When disposed in flow communication with the reservoir 104, the
wellbore 102 is
disposed for receiving reservoir fluid flow from the reservoir 104.
[0051] It is preferable to remove at least a fraction of the gaseous
material from the reservoir
fluid received by the reservoir fluid-supplying conductor 12, prior to the
pump suction 302, in
order to mitigate gas interference or gas lock conditions during pump
operation. In this respect,
the uphole-disposed reservoir fluid-conducting assembly 14 includes a flow
diverter 600 for
receiving reservoir fluid flow from the reservoir fluid-supplying conductor
12, effecting removal
18
CA 3032720 2019-02-05
of at least a fraction of the gaseous material from the received reservoir
fluid such that a gas-
depleted reservoir fluid is obtained, and conducting the gas-depleted
reservoir fluid to the pump.
[0052] In this respect, the flow diverter 600 is disposed uphole relative
to the reservoir fluid-
supplying conductor 12 and is fluid coupled to the reservoir fluid-supplying
conductor 12 for
receiving reservoir fluid being conducted by the reservoir fluid-supplying
conductor 12. The
flow diverter is also disposed downhole relative to the pump 300 and is
fluidly coupled to the
pump suction 302 for supplying the pump 300 with the gas-depleted reservoir
fluid. In some
embodiments, for example, the flow diverter 600 is disposed within a vertical
portion of the
wellbore 102 that extends to the surface 106.
[0053] In some embodiments, the flow diverter 600 includes a wellbore
string counterpart
600B and an assembly counterpart 600C. The wellbore string 113 defines the
wellbore string
counterpart 600B, and the assembly 10 defines the assembly counterpart 600C.
The flow
diverter 600 defines: (i) a reservoir fluid-conducting passage 6002 for
diverted reservoir fluid,
received within the downhole wellbore space from the reservoir 104, to a
reservoir fluid
separation space 112X of the wellbore 102, with effect that a gas-depleted
reservoir fluid is
separated from the reservoir fluid within the reservoir fluid separation space
112X in response to
at least buoyancy forces; and (ii) a gas-depleted reservoir fluid-conducting
passage 6004 for
receiving the separated gas-depleted reservoir fluid while the separated gas-
depleted reservoir
fluid is flowing in a downhole direction, and diverting the flow of the
received gas-depleted
reservoir fluid such that the received gas-depleted reservoir fluid is
conducted by the flow
diverter 600 in the uphole direction to the pump 300.
[0054] In some embodiments, for example, the assembly counterpart 600C
includes a fluid
diverter body 600A.
[0055] In some embodiments, for example, the flow diverter body 600A is
configured such
that the depletion of gaseous material from the reservoir fluid material, that
is effected while the
assembly 10 is disposed within the wellbore 102, is effected externally of the
flow diverter body
600A within the wellbore 102, such as, for example, within an uphole wellbore
space 108 of the
wellbore 102.
19
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[0056] The flow diverter body 600A includes a reservoir fluid receiver 602
for receiving the
reservoir fluid (such as, for example, in the form of a reservoir fluid flow)
that is being
conducted (e.g. flowed), via the reservoir fluid-supplying conductor 12 from
its inlet 204. In
some embodiments, for example, the reservoir fluid-supplying conductor 12
extends to the
receiver 602. In this respect, the reservoir fluid-supplying conductor 12 is
fluidly coupled to the
inlet 204. In some embodiments, for example, the reservoir fluid receiver 602
includes one or
more ports 602A for receiving reservoir fluid being conducted by the fluid-
supplying conductor
12.
[0057] The flow diverter body 600A also includes a reservoir fluid
discharge communicator
604 that is fluidly coupled to the reservoir fluid receiver 602 via a
reservoir fluid-conductor 603.
In this respect, the reservoir fluid conductor 603 defines at least a portion
of the reservoir fluid-
conducting passage 6002.
[0058] The reservoir fluid conductor 603 defines one or more reservoir
fluid conductor
passages 603A. In some of the embodiments described below, for example, the
one or more
reservoir fluid-conducting passages 603A.
[0059] The reservoir fluid discharge communicator 604 is configured for
discharging
reservoir fluid (such as, for example, in the form of a flow) that is received
by the reservoir fluid
receiver 602 and conducted to the reservoir fluid discharge communicator 604
via the reservoir
fluid conductor 603. In some embodiments, for example, the reservoir fluid
discharge
communicator 604 is disposed at an opposite end of the flow diverter body 600A
relative to the
reservoir fluid receiver 602. In some embodiments, for example, the reservoir
fluid discharge
communicator 604 includes one or more ports 604A.
[0060] The flow diverter body 600A also includes a gas-depleted reservoir
fluid receiver 608
for receiving a gas-depleted reservoir fluid (such as, for example, in the
form of a flow), after
gaseous material has been separated from the reservoir fluid (for example, a
reservoir fluid flow),
that has been discharged from the reservoir fluid discharge communicator 604,
in response to at
least buoyancy forces. In this respect, the gas-depleted reservoir fluid
receiver 608 and the
reservoir fluid discharge communicator 604 are co-operatively configured such
that the gas-
CA 3032720 2019-02-05
depleted reservoir fluid receiver 608 is disposed for receiving a gas-depleted
reservoir fluid flow,
after gaseous material has been separated from the received reservoir fluid
flow that has been
discharged from the reservoir fluid discharge communicator 604, in response to
at least
buoyancy forces. In
some embodiments, for example, the reservoir fluid discharge
communicator 604 is disposed at an opposite end of the flow diverter body 600A
relative to the
gas-depleted reservoir fluid receiver 608. In some embodiments, for example,
the gas-depleted
reservoir fluid receiver 608 includes one or more ports 608A.
[0061] The
flow diverter body 600A also includes a gas-depleted reservoir fluid conductor
610 that defines a gas-depleted reservoir fluid-conducting passage 610A
configured for
conducting the gas-depleted reservoir fluid (for example, a gas-depleted
reservoir fluid flow),
received by the receiver 608, to the gas-depleted reservoir fluid discharge
communicator 611. In
some embodiments, for example, the gas-depleted reservoir fluid discharge
communicator 611 is
disposed at an opposite end of the flow diverter body 600A relative to the gas-
depleted reservoir
fluid receiver 608. The gas-depleted reservoir fluid discharge communicator
611 is configured
for fluid coupling to the pump 300, wherein the fluid coupling is for
supplying the pump 300
with the gas-depleted reservoir fluid received by the receiver 610 and
conducted through at least
the gas-depleted reservoir fluid conductor 610. In this respect, the gas-
depleted reservoir fluid-
conducting passage 610A defines at least a portion of the gas-depleted
reservoir fluid-conducting
passage 6004. In some embodiments, for example, the gas-depleted reservoir
fluid discharge
communicator includes one or more ports 611A.
[0062]
Referring to Figure 2A, in some embodiments, for example, the reservoir fluid
discharge communicator 604 is oriented such that, a ray (see, for example ray
604B), that is
disposed along the central longitudinal axis of the reservoir fluid discharge
communicator, is
disposed in an uphole direction at an acute angle of less than 30 degrees
relative to the central
longitudinal axis of the wellbore portion within which the flow diverter body
600A is disposed.
[0063] Again
referring to Figure 2A, in some embodiments, for example, the reservoir fluid
discharge communicator 604 is oriented such that, a ray (see, for example ray
604B), that is
disposed along the central longitudinal axis of the reservoir fluid discharge
communicator 604, is
21
CA 3032720 2019-02-05
disposed in an uphole direction at an acute angle of less than 30 degrees
relative to the vertical
(which includes disposition of the ray 604B along a vertical axis).
[0064] In some embodiments, for example, the flow diverter body 600A
includes the
reservoir fluid receiver 602, the reservoir fluid discharge communicator 604,
and the reservoir
fluid conductor 603 (such as, for example, in the form of a fluid passage or a
network of fluid
passages), for fluidly coupling the receiver 602 and the discharge
communicator 604. The flow
diverter body 600A also includes the gas-depleted reservoir fluid receiver
608, gas-depleted
reservoir fluid discharge communicator 611, and the gas-depleted reservoir
fluid conductor 610
(such as, for example, in the form of a fluid passage or a network of fluid
passages) for fluidly
coupling the receiver 608 to the discharge communicator 611.
[0065] The assembly counterpart 600C also includes a wellbore sealed
interface effector 400
configured for interacting with a wellbore feature for defining a wellbore
sealed interface 500
within the wellbore 102, between: (a) an uphole wellbore space 108 of the
wellbore 102, and (b)
a downhole wellbore space 110 of the wellbore 102, while the assembly 10 is
disposed within
the wellbore 102.
[0066] In some embodiments, for example, the disposition of the sealed
interface 500 is such
that flow communication, via the intermediate wellbore passage 112, between an
uphole
wellbore space 108 and a downhole wellbore space 110 (and across the sealed
interface 500), is
prevented, or substantially prevented. In some embodiments, for example, the
disposition of the
sealed interface 500 is such that fluid flow, across the sealed interface 500,
in a downhole
direction, from the uphole wellbore space 108 to the downhole wellbore space
110, is prevented,
or substantially prevented.
[0067] In such embodiments, for example, the disposition of the sealed
interface 500 is
effected by the combination of at least: (i) a sealed, or substantially
sealed, disposition of the
wellbore string 113 relative to a polished bore receptacle 114 (such as that
effected by a packer
240A disposed between the wellbore string 113 and the polished bore receptacle
114), and (ii) a
sealed, or substantially sealed, disposition of a flow diverter body portion
601 relative to the
polished bore receptacle 114. In this respect, the sealed interface 500
functions to prevent, or
22
CA 3032720 2019-02-05
substantially prevented, reservoir fluid flow, that is received within the
wellbore 102 (that is
lined with the wellbore string 113), from bypassing the reservoir fluid
receiver 602, and, as a
corollary, the reservoir fluid is directed to the reservoir fluid receiver 602
for receiving by the
reservoir fluid receiver 602. As well, the sealed interface 500 functions to
prevent, or
substantially prevented, gas-depleted reservoir fluid flow, that has been
separated from the
reservoir fluid discharged into the wellbore 102 from the discharge
communicator 604, from
bypassing the gas-depleted reservoir fluid receiver 608 and, as a corollary,
the gas-depleted
reservoir fluid is directed to the gas-depleted reservoir fluid receiver 608
for receiving by the
gas-depleted reservoir fluid receiver 608.
[0068] In some embodiments, for example, the sealed, or substantially
sealed, disposition of
the flow diverter body portion 601 relative to the polished bore receptacle
114 is effected by a
latch seal assembly. A suitable latch seal assembly is a WeatherfordTM Thread-
Latch Anchor
Seal AssemblyTM.
[0069] In some embodiments, for example, the sealed, or substantially
sealed, disposition of
the flow diverter body portion 601 relative to the polished bore receptacle
114 is effected by one
or more o-rings or seal-type Chevron rings. In this respect, the sealing
interface effector 400
includes the o-rings, or includes the seal-type Chevron rings.
[0070] In some embodiments, for example, the sealed, or substantially
sealed, disposition of
the flow diverter body portion 601 relative to the polished bore receptacle
114 is disposed in an
interference fit with the polished bore receptacle. In some of these
embodiments, for example,
the flow diverter body portion 601 is landed or engaged or "stung" within the
polished bore
receptacle 114.
[0071] In some embodiments, for example, the flow diverter body portion 601
defines a
passage, and the reservoir fluid-supplying conductor 12 is disposed within the
passage.
[0072] The above-described disposition of the wellbore sealed interface 500
provide for
conditions which minimize solid debris accumulation in the joint between the
flow diverter body
portion 601 and the polished bore receptacle 114 or in the joint between the
polished bore
receptacle 114 and the wellbore string 113. By providing for conditions which
minimize solid
23
CA 3032720 2019-02-05
debris accumulation within the joint, interference to movement of the
separator relative to the
liner, or the casing, as the case may be, which could be effected by
accumulated solid debris, is
mitigated.
[0073] Referring to Figure 1A, in some embodiments, for example, the sealed
interface 500
is disposed within a section of the wellbore 102 whose axis 102A is disposed
at an angle "a" of
at least 60 degrees relative to the vertical "V". In some of these
embodiments, for example, the
sealed interface 500 is disposed within a section of the wellbore whose axis
is disposed at an
angle "a" of at least 85 degrees relative to the vertical "V". In this
respect, disposing the sealed
interface 500 within a wellbore section having such wellbore inclinations
minimizes solid debris
accumulation at the sealed interface 500.
[0074] Referring to Figure 1A, in some embodiments, for example, the flow
diverter body
600, the sealed interface effector 400, and the reservoir fluid-supplying
conductor 12, are co-
operatively configured such that, while the assembly 10 is disposed within the
wellbore string
113 such that the sealed interface 500 is defined, and the reservoir fluid-
supplying conductor 12
is receiving reservoir fluid from the downhole wellbore space 110 that has
been received within
the downhole wellbore space 110 from the subterranean formation 100:
the reservoir fluid is conducted to the reservoir fluid receiver 602 via the
reservoir fluid-
supplying conductor 12;
the reservoir fluid is conducted as a flow 802 to the reservoir fluid
discharge
communicator 604 by the reservoir fluid conductor 603 and discharged as a flow
804 to the
reservoir fluid separation space 112X of the uphole wellbore space 108;
within the reservoir fluid separation space 112X, a gas-depleted reservoir
fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy forces, such that
the gas-depleted reservoir fluid is obtained;
the separated gas-depleted reservoir fluid is conducted as a flow 806 to the
gas-depleted
reservoir fluid receiver 608 via the intermediate wellbore passage 112, and
the received gas-
depleted reservoir fluid is conducted as a flow 808 from the gas-depleted
reservoir fluid receiver
24
CA 3032720 2019-02-05
608 to the pump 300 via at least the conductor 610 and the gas-depleted
reservoir fluid discharge
communicator 611.
[0075] In this respect, in such embodiments, for example, at least a
portion of the space
within the intermediate wellbore space 112, between the reservoir fluid
discharge communicator
604 and the gas-depleted reservoir fluid receiver 608, defines at least a
portion of the gas-
depleted reservoir fluid-conducting passage 6004.
[0076] Once received by the pump 300, the gas-depleted reservoir fluid is
pressurized by the
pump 300 and conducted to the surface via the reservoir fluid-producing
conductor 210.
[0077] Also, the separation of gaseous material from the reservoir fluid is
with effect that a
liquid-depleted reservoir fluid is obtained and is conducted uphole (in the
gaseous phase, or at
least primarily in the gaseous phase with relatively small amounts of
entrained liquid) as a flow
810 via the intermediate wellbore passage 112 that is disposed between the
assembly 10 and the
wellbore string 113 (see above).
[0078] The reservoir fluid produced from the subterranean formation 100,
via the wellbore
102, including the gas-depleted reservoir fluid, the liquid-depleted reservoir
material, or both,
may be discharged through the wellhead 116 to a collection facility, such as a
storage tank within
a battery.
[0079] In some embodiments, for example, the flow diverter body 600A is
configured such
that the gas-depleted reservoir fluid receiver 608 is disposed downhole
relative to (such as, for
example, vertically below) the reservoir fluid discharge communicator 604,
with effect that the
separated gas-depleted reservoir fluid is conducted in a downhole direction to
the gas-depleted
reservoir fluid receiver 608.
[0080] In some embodiments, for example, separation of gaseous material,
from the reservoir
fluid that is being discharged from the reservoir fluid discharge communicator
604, is effected
within an uphole-disposed space 1121X of the intermediate wellbore passage
112, the uphole-
disposed space 1121X being disposed uphole relative to the reservoir fluid
discharge
CA 3032720 2019-02-05
communicator 604. In this respect, in some embodiments, for example, the
reservoir fluid
separation space 112X includes the uphole-disposed space 1121X.
[0081] In some embodiments, for example, a flow diverter body-defined
intermediate
wellbore passage portion 1121Y of the intermediate wellbore passage 112 is
disposed within a
space between the flow diverter body 600A and the wellbore string 113, and
effects flow
communication between the reservoir fluid discharge communicator 604 and the
gas-depleted
reservoir fluid receiver 608 for effecting conducting of the gas-depleted
reservoir fluid to the
gas-depleted reservoir fluid receiver 608. In this respect, in such
embodiments, for example, the
flow diverter body-defined intermediate wellbore passage portion 1121Y defines
at least a
portion of the gas-depleted reservoir fluid-conducting passage 6004.
[0082] In some embodiments, for example, the space between the flow
diverter body 600A
and the wellbore string 113, within which the flow diverter body-defined
intermediate wellbore
passage portion 1121Y is disposed, is an annular space. In some embodiments,
for example, the
flow diverter body-defined intermediate space 1121Y is defined by the
entirety, or the substantial
entirety, of the space between the flow diverter body 600A and the wellbore
string 113. In some
embodiments, for example, separation of gaseous material, from the reservoir
fluid that is
discharged from the reservoir fluid discharge communicator 604, is effected
within the flow
diverter body-defined intermediate wellbore passage portion 1121Y. In this
respect, in some
embodiments, for example, at least a portion of the reservoir fluid separation
space 112X is co-
located with at least a portion of the flow diverter body-defined intermediate
wellbore passage
portion 1121Y.
[0083] In some embodiments, for example, the separation of gaseous
material, from the
reservoir fluid that is being discharged from the reservoir fluid discharge
communicator 604, is
effected within both of the uphole-disposed space 1121X and the flow diverter
body-defined
intermediate wellbore passage portion 1121Y. In this respect, in some
embodiments, for
example, the reservoir fluid is discharged from the reservoir fluid discharge
communicator 604
into the uphole wellbore space 1121X, and, in response to at least buoyancy
forces, the gaseous
material is separated from the discharged reservoir fluid, while the reservoir
fluid is being
conducted downhole, from the uphole-disposed space 1121X, through the flow
diverter body-
26
CA 3032720 2019-02-05
defined intermediate wellbore passage portion 1121Y, and to the gas-depleted
reservoir fluid
receiver 608. In this respect, in some embodiments, for example, the uphole-
disposed space
1121X is merged with the flow diverter body-defined intermediate wellbore
passage portion
1121Y
[0084] In some embodiments, for example, the reservoir fluid separation
space 112X spans a
continuous space extending from the assembly to the wellbore string 113, and
the continuous
space extends outwardly relative to the central longitudinal axis of the
assembly 10.
[0085] In some embodiments, for example, the reservoir fluid separation
space 112X spans a
continuous space extending from the assembly to the wellbore string 113, and
the continuous
space extends outwardly relative to the central longitudinal axis of the
wellbore 102.
[0086] In some embodiments, for example, the reservoir fluid separation
space 112X is
disposed within a vertical portion of the wellbore 102 that extends to the
surface 106.
[0087] In some embodiments, for example, the ratio of the minimum cross-
sectional flow
area of the reservoir fluid separation space 112X to the maximum cross-
sectional flow area of
the fluid passage 12A defined by the reservoir fluid-supplying conductor 12 is
at least about 1.5.
[0088] In some embodiments, for example, the flow diverter body 600A
further includes a
shroud 620 co-operatively disposed relative to the gas-depleted reservoir
fluid receiver 608 such
that the shroud 620 projects below the gas-depleted reservoir fluid receiver
608 and interferes
with conduction of the gas-depleted reservoir fluid to the gas-depleted
reservoir fluid receiver
608 The shroud 620 provides increased residence time for separation of gaseous
material within
the intermediate fluid passage 112.
[0089] In those embodiments where the gas-depleted reservoir fluid receiver
608 is disposed
below the reservoir fluid discharge communicator 604, in some of these
embodiments, for
example, the shroud 620 projects below the gas-depleted reservoir fluid
receiver 608, such that
gas-depleted reservoir fluid being conducted downhole to the gas-depleted
reservoir fluid
receiver 608 is directed below the gas-depleted reservoir fluid receiver 608
by the shroud 620.
27
CA 3032720 2019-02-05
[0090] In some embodiments, for example, the space, between: (a) the gas-
depleted reservoir
fluid receiver 608 of the flow diverter body 600A, and (b) the sealed
interface 500, defines a
sump 700 for collection of solid particulate that is entrained within fluid
being discharged from
the reservoir fluid discharge communicator 604 of the flow diverter body 600A,
and the sump
700 has a volume of at least 0.1 m3. In some embodiments, for example, the
volume is at least
0.5 m3. In some embodiments, for example, the volume is at least 1.0 m3. In
some
embodiments, for example, the volume is at least 3.0 m3.
[0091] By providing for the sump 700 having the above-described volumetric
space
characteristic, and/or the above-described minimum separation distance
characteristic, a suitable
space is provided for collecting relative large volumes of solid debris, from
the gas-depleted
reservoir fluid being flowed downwardly to the gas-depleted reservoir fluid
receiver 608, such
that interference by the accumulated solid debris with the production of oil
through the system is
mitigated. This increases the run-time of the system before any maintenance is
required. As
well, because the solid debris is deposited over a larger area, the propensity
for the collected
solid debris to interfere with movement of the flow diverter body 600A within
the wellbore 102,
such as during maintenance (for example, a workover) is reduced.
[0092] As above-described, the reservoir fluid-producing conductor 210
extends from the
gas-depleted reservoir fluid discharge communicator 611 to the wellhead 116
for effecting flow
communication between the discharge communicator 611 and the earth's surface
106, such as,
for example, a collection facility located at the earth's surface 106, and
defines a fluid passage
210A.
[0093] In some embodiments, for example, the length of the fluid-supplying
conductor 12, as
measured along the central longitudinal axis of the fluid-supplying conductor
12, is at least 500
feet, such as, for example, at least 750 feet, such as, for example at least
1000 feet.
[0094] In some embodiments, for example, the flow diverter 600 is disposed
uphole of a
horizontal section 102C of the wellbore 102, such as, in some embodiments, for
example, within
a vertical section 102A, or, in some embodiments, for example, within a
transition section 102B.
28
CA 3032720 2019-02-05
[0095] . In some embodiments, for example, the central longitudinal axis of
the passage
102CC of the horizontal section 102C is disposed along an axis that is between
about 70 and
about 110 degrees relative to the vertical "V", the central longitudinal axis
of the passage 102AA
of the vertical section 102A is disposed along an axis that is less than about
20 degrees from the
vertical "V", and the transition section 102B is disposed between the sections
102A and 102C.
In some embodiments, for example, the transition section 102B joins the
sections 102A and
102C. In some embodiments, for example, the vertical section 102A extends from
the transition
section 102B to the surface 106.
[0096] In some of these embodiments, for example, the reservoir fluid-
supplying conductor
12 extends from the flow diverter 600, in a downhole direction, into the
horizontal section 102C,
such that the inlet 204 is disposed within the horizontal section 102C.
[0097] Referring to Figures 10 and 11, in some embodiments, for example,
the assembly 10
is configured such that, while the assembly 10 is disposed within the wellbore
10, the reservoir
fluid-supplying conductor 12 is releasable from the retention relative to the
uphole-disposed
reservoir fluid-conducting assembly 14 and replaceable with another reservoir
fluid-supplying
conductor 12 having a smaller minimum cross-sectional flow area.
[0098] In this respect, in some embodiments, for example, parts for
assembly to obtain the
production assembly 10 are provided, and the parts include first, second,
third, and fourth
assembly counterparts 10A, 10B, 10C, and 10D. The assembly-defined flow
diverter counterpart
600C includes first and second assembly-defined flow diverter counterparts
6002, 6004. The
first assembly counterpart 10A includes the first assembly-defined flow
diverter counterpart
6002, and the second assembly counterpart 10B includes the second assembly-
defined flow
diverter counterpart 6004. The third assembly counterpart 10C includes a
reservoir fluid-
supplying conductor 12 that is a first reservoir fluid-supplying conductor 12,
and the first
reservoir fluid-supplying conductor 12 defines a fluid passage having a
minimum cross-sectional
flow area. The fourth assembly counterpart 10D includes a reservoir fluid-
supplying conductor
12 that is a second reservoir fluid-supplying conductor 12, and the second
reservoir fluid-
supplying conductor 12 defines a fluid passage having a minimum cross-
sectional flow area that
29
CA 3032720 2019-02-05
is less than the minimum cross-sectional flow area of the fluid passage
defined by the first
reservoir fluid-supplying conductor 12.
[0099] Each
one of the second, third, and fourth assembly counterparts 10B, 10C, and 10D
is
configured for releasable retention relative to the first assembly counterpart
10A
[00100] The first, second, third, and fourth assembly counterparts 10A, 10B,
10C, 10D are co-
operatively configured such that:
while the assembly 10 is disposed within the wellbore 10 and includes the
first, second
and third assembly counterparts 10A, 10B, 10C, and the second and third
assembly counterparts
10B, 10C are releasably retained relative to the first assembly counterpart
10A,
interchangeability of the third assembly counterpart 10C with the fourth
assembly counterpart
10D is prevented; and
while the assembly 10 is disposed within the wellbore 10 and includes the
first, second
and third assembly counterparts 10A, 10B, 10C, and the second and third
assembly counterparts
10B, 10C are releasably retained relative to the first assembly counterpart
10A, in response to
release of the second assembly counterpart 10B from retention relative to the
first assembly
counterpart 10A, the prevention of the interchangeability of the third
assembly counterpart 10C
with the fourth assembly counterpart 10D is defeated.
[00101] In some embodiments, for example, the third assembly counterpart 10C
is connected
to the second assembly counterpart 10B, such that release of the third
assembly counterpart 10C
from retention relative to the first assembly counterpart 10A is effected by
the release of the
second assembly counterpart 10B relative to the first assembly counterpart
10A. In some of
these embodiments, for example, in response to release of the second assembly
counterpart 10B
from retention relative to the first assembly counterpart 10A, both of the
second and third
assembly counterparts 10B, 10C become displaceable relative to the first
assembly counterpart
for defeating occlusion of a workstring-conducting passageway 626 such that
the fourth
assembly counterpart 10D is conductible through the workstring-conducting
passageway 626 for
releasable coupling to the first assembly counterpart 10A.
CA 3032720 2019-02-05
[00102] In some embodiments, for example, the releasable retention of the
second assembly
counterpart 10B relative to the first assembly counterpart 10A is independent
of the releasable
retention of the third assembly counterpart 10C relative to the first assembly
counterpart 10A. In
other words, each one of the first and second assembly counterparts 10B, 10C,
independently, is
configured for releasable retention relative to the first assembly counterpart
10A.
[00103] In this respect, the first, second, third, and fourth assembly
counterparts 10A, 10B,
10C, I OD are co-operatively configured such that:
while the assembly 10 is disposed within the wellbore 10 and includes the
first, second
and third assembly counterparts 10A, 10B, 10C, and each one of the second and
third assembly
counterparts 10B, 10C, independently, is releasably retained relative to the
first assembly
counterpart 10A, interchanging of the third assembly counterpart 10C with the
fourth assembly
counterpart, is prevented by occlusion of a workstring-conducting passageway
626 by the second
assembly counterpart 10B; and
while the assembly 10 is disposed within the wellbore 10 and includes the
first, second
and third assembly counterparts 10A, 10B, 10C, and each one of the second and
third assembly
counterparts 10B, 10C, independently, is releasably retained relative to the
first assembly
counterpart 10A, in response to the release of the second assembly counterpart
10B from the
retention relative to the first assembly counterpart 10A, the second assembly
counterpart 10B
becomes displaceable relative to the first assembly counterpart 10A for
defeating the occlusion
of the workstring-conducting passageway 626 by the second assembly counterpart
10B such that
the prevention of the interchangeability of the third assembly counterpart 10C
with the fourth
assembly counterpart 10D is defeated.
[00104] In some embodiments, for example, the preventing of the
interchangeability of the
third assembly counterpart 10C with the fourth assembly counterpart 10D
includes preventing of
release of the retention of the third assembly counterpart 10C relative to the
first assembly
counterpart 10A, and the defeating of the preventing of the interchangeability
of the third
assembly counterpart 10C with the fourth assembly counterpart 10D includes
defeating of the
preventing of release of the retention of the third assembly counterpart 10C
relative to the first
31
CA 3032720 2019-02-05
assembly counterpart 10A such that the third assembly counterpart 10C becomes
releasable from
the retention relative to the first assembly counterpart 10A for effecting
displacement of the third
assembly counterpart 10C relative to the first assembly counterpart such that
occlusion to the
workstring-conducting passageway 626 by the third assembly counterpart 10C is
defeated with
effect that the fourth assembly counterpart 10D is conductible through the
workstring-conducting
passageway 626 for effecting releasable coupling of the fourth assembly
counterpart 10D to the
first assembly counterpart 10A such that an assembly 10 is obtained that
includes the second
reservoir fluid-supplying conductor 12.
[00105] In some embodiments, for example, the minimum cross-sectional flow
area of the
fluid passage defined by second reservoir fluid-supplying conductor 12 is less
than the minimum
cross-sectional flow area of the fluid passage defined by the first reservoir
fluid-supplying
conductor 12. In some embodiments, for example, the ratio of the minimum cross-
sectional flow
area of the fluid passage defined by the second reservoir fluid-supplying
conductor 12 to the
minimum cross-sectional flow area of the fluid passage defined by the second
reservoir fluid-
supplying conductor 12 is less than about 0.9, such as, for example, less than
about 0.8, such as,
for example, less than 0.7.
[00106] Referring to Figures 2A, 2B, 3-5, 6A, 6B, 6C, 6D, 6E, and 7-9, in some
embodiments, for example, the first assembly-defined flow diverter counterpart
6002 includes an
insert-receiving part 622 (see Figures 6, 6A, 6B, and 6C). The insert-
receiving part 622 defines a
reservoir fluid receiver 602, a gas-depleted reservoir fluid discharge
communicator 612, and a
passageway 626 extending from the reservoir fluid receiver 602 to the gas-
depleted reservoir
fluid receiver 612. The insert-receiving part 622 is configured for
integration into the reservoir
fluid conducting assembly 14, such as, for example, by threaded coupling, such
that the assembly
14 includes the insert-receiving part 622.
[00107] In some embodiments, for example, the second assembly-defined flow
diverter
counterpart 6004 includes a flow diverter-effecting insert 624 (see Figures 7
and 8) configured
for insertion within the passageway 626. The flow diverter-effecting insert
624 is co-operatively
configured with the insert-receiving part 622 such that the flow diverter body
600A is defined
while the flow diverter-effecting insert 624 is disposed within the passageway
626. The flow
32
CA 3032720 2019-02-05
diverter-effecting insert 624 is disposed in a flow diverter-defining position
when the flow
diverter-effecting insert 624, while disposed within the passageway 626 of the
insert-receiving
part 622, is disposed such that the flow diverter body 600A is defined and
functions as above-
described.
[00108] The
insert-receiving part 622 further defines both of the reservoir fluid
discharge
communicator 604 and the gas-depleted reservoir receiver 608. The reservoir
fluid discharge
communicator 604 is disposed in fluid communication with the passageway 626,
and the gas-
depleted reservoir receiver 608 is also disposed in fluid communication with
the passageway
626.
[00109] In some embodiments, for example, the insert-receiving part 622 and
the flow
diverter-effecting insert 624 are co-operatively configured such that, while
the assembly 10,
having the flow diverter-effecting insert 624 disposed within the passageway
626 of the insert-
receiving part 622, is disposed within the wellbore 102 such that the sealed
interface 500 is
defined, and the reservoir fluid-supplying conductor 12 is receiving reservoir
fluid from the
downhole wellbore space 110 that has been received within the downhole
wellbore space 110
from the subterranean formation 100:
the reservoir fluid is conducted to the reservoir fluid receiver 602 via the
reservoir fluid-
supplying conductor 12;
the reservoir fluid is conducted to the reservoir fluid discharge communicator
604 by the
reservoir fluid conductor 603 and discharged to the reservoir fluid separation
space 112X of the
uphole wellbore space 108;
within the reservoir fluid separation space 112X, a gas-depleted reservoir
fluid is
separated from the discharged reservoir fluid, in response to at least
buoyancy forces, such that
the gas-depleted reservoir fluid is obtained;
the separated gas-depleted reservoir fluid is conducted to the gas-depleted
reservoir fluid
receiver 608, and the received gas-depleted reservoir fluid is conducted from
the gas-depleted
33
CA 3032720 2019-02-05
reservoir fluid receiver 608 to the pump 300 via at least the conductor 610
and the gas-depleted
reservoir fluid discharge communicator 611.
[00110] In some embodiments, for example, the gas-depleted reservoir fluid
receiver 608 is
disposed below the reservoir fluid discharge communicator 604, in which case,
the receiving of
the obtained gas-depleted reservoir fluid flow by the gas-depleted reservoir
fluid receiver 608 is
effected by conduction of the obtained gas-depleted reservoir fluid flow to
the gas-depleted
reservoir fluid receiver 608 in a downhole direction.
[00111] In some embodiments, for example, the insert-receiving part 622 and
the flow
diverter-effecting insert 624 are further co-operatively configured such that,
while the assembly
10, having the flow diverter-effecting insert 624 disposed within the
passageway 626 of the
insert-receiving part 622, is disposed within the wellbore 102 such that the
sealed interface 500 is
defined, and the reservoir fluid-supplying conductor 12 is receiving reservoir
fluid from the
downhole wellbore space 110 that has been received within the downhole
wellbore space 110
from the subterranean formation 100:
bypassing of the reservoir fluid discharge communicator 604, by the reservoir
fluid flow
being received by the reservoir fluid receiver 602, is at least interfered
with (such as, for
example, prevented or substantially prevented) by the flow diverter-effecting
insert 624 that is
disposed within the passageway 626, such that the received reservoir fluid
flow is conducted to
the reservoir fluid discharge communicator 604 and discharged into the
wellbore 102 such that
gaseous material is separated from the discharged reservoir fluid flow within
the wellbore 102 in
response to at least buoyancy forces, such that a gas-depleted reservoir fluid
flow is obtained and
conducted to the gas-depleted reservoir fluid receiver 608 such that a gas-
depleted reservoir fluid
flow is received by the gas-depleted reservoir fluid receiver 608; and
bypassing of the gas-depleted reservoir fluid discharge communicator 612, by
the gas-
depleted reservoir fluid flow being received by the gas-depleted reservoir
fluid receiver 608, is at
least interfered with (such as, for example, prevented or substantially
prevented) by the flow
diverter-effecting insert 624 that is disposed within the passageway 626, such
that gas-depleted
reservoir fluid flow is conducted to the gas-depleted reservoir fluid
discharge communicator 612
34
CA 3032720 2019-02-05
for discharging of the gas-depleted reservoir fluid flow via the gas-depleted
reservoir fluid
communicator 612;
[00112] In some of these embodiments, for example, the flow diverter-effecting
insert 624 is
further configured for disposition relative to the passageway 626 such that a
passageway sealed
interface 628 is established. In this respect, the insert-receiving part 622
and the flow diverter-
effecting insert 624 are further co-operatively configured such that a
passageway sealed interface
628 is established while the flow diverter-effecting insert 624 is disposed
within the passageway
626 of the insert-receiving part 622, with effect that:
the passageway 626 is disposed in fluid communication with the reservoir fluid
discharge
communicator 604 via a passageway portion 630 that is disposed downhole
relative to the
passageway sealed interface 628, such that fluid communication is effected
between the reservoir
fluid receiver 602 and the reservoir fluid discharge communicator 604; and
the passageway 626 is disposed in fluid communication with the gas-depleted
reservoir
fluid receiver 608 via a passageway portion 632 that is disposed uphole
relative to the
passageway sealed interface 628, such that fluid communication is effected
between the gas-
depleted reservoir fluid receiver 608 and the gas-depleted reservoir fluid
discharge
communicator 612;
and, while the assembly 10, having the flow diverter-effecting insert 624
disposed within the
passageway 626 of the insert-receiving part 622, is disposed within the
wellbore 102 such that
the sealed interface 500 is defined, and the reservoir fluid-supplying
conductor 12 is receiving
reservoir fluid from the downhole wellbore space 110 that has been received
within the
downhole wellbore space 110 from the subterranean formation 100:
bypassing of the reservoir fluid discharge communicator 604, by reservoir
fluid flow, that
is received by the reservoir fluid receiver 602, is prevented, or
substantially prevented, by the
passageway sealed interface 628, such that the received reservoir fluid flow
is conducted, via the
passageway portion 630 disposed downhole relative to the passageway sealed
interface 628, to
the reservoir fluid discharge communicator 604, such that the received
reservoir fluid flow is
discharged into the wellbore 102 and gaseous material is separated from the
discharged reservoir
CA 3032720 2019-02-05
fluid flow within the wellbore 102 in response to at least buoyancy forces,
such that a gas-
depleted reservoir fluid flow is obtained and conducted to the gas-depleted
reservoir fluid
receiver 608 such that the gas-depleted reservoir fluid flow is received by
the gas-depleted
reservoir fluid receiver 608;
and
bypassing of the gas-depleted reservoir fluid discharge communicator 612, by
the gas-
depleted reservoir fluid flow, that is received by the gas-depleted reservoir
fluid receiver 608, is
prevented, or substantially prevented, by the passageway sealed interface 628,
such that the
received gas-depleted reservoir fluid flow is conducted, via the passageway
portion 632 disposed
uphole relative to the passageway sealed interface 628, from the gas-depleted
reservoir fluid
receiver 608 to the gas-depleted reservoir fluid discharge communicator 612
such that the gas-
depleted reservoir fluid flow is discharged from the gas-depleted reservoir
fluid discharge
communicator 612.
[00113] In some embodiments, for example, the passageway sealed interface 628
is effected
by sealing engagement, or substantially sealing engagement, of the flow
diverter-effecting insert
624 with the insert-receiving part 622. In some embodiments, for example, the
sealing
engagement, or substantially sealing engagement, of the flow diverter-
effecting insert 624 with
the passageway 626 is effected by a sealing member 628A that is coupled to the
flow diverter-
effecting insert 624. In some embodiments, a sealing member 629 is also
coupled to the flow
diverter effecting insert 624 for protecting the sealing area (defined between
sealing members
628A and 629) from erosion and corrosion.
[00114] Referring to Figures 7, 8 and 9, in some embodiments, for example, the
flow diverter-
effecting insert 624 is elongated and includes a first end 624A and a second
end 624B. The
sealing member 628A extends about an external surface 624C of the flow
diverter-effecting
insert 624. The first end 624A is shaped (such as, for example, cone-shaped)
to urge the flow of
reservoir fluid, received by the reservoir fluid receiver 602, towards the
reservoir fluid conductor
branches 603. The ports 6245 (such as, for example, in the form of slots
formed through the
external surface 624C of the part 624) are relatively closer to the first end
624A, and the port
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CA 3032720 2019-02-05
6243 is disposed at the second end 624B. A fluid passage 6244 extends along,
or substantially
along, the central longitudinal axis of the part 624, from the ports 6245 to
the port 6243 for
conducting fluid received by the ports 6245 to the port 6243. The flow
diverter-effecting insert
624 and the insert-receiving part 622 are further co-operatively configured
such that:
the ports 6245 are disposed for receiving the gas-depleted reservoir fluid
flow from
corresponding gas-depleted reservoir fluid conductor branches 610(a)-(f) that
extend from the
gas-depleted reservoir fluid receiver 608;
the gas-depleted reservoir fluid flow, that is received by the ports 6245, is
conducted, via
the fluid passage 6244 to the port 6243, for discharging, via the port 6243,
into the passageway
portion 632 disposed uphole relative to the passageway sealed interface 628,
for discharging via
the gas-depleted reservoir fluid discharge communicator 612;
the sealing member 628A:
(i) prevents, or substantially prevents, bypassing of the ports 6245 by the
gas-
depleted reservoir fluid flow being conducted by the gas-depleted reservoir
fluid
conductor branches 610(a)-(f); and
(ii) prevents, or substantially prevents, bypassing of the reservoir fluid
conductor branches 603(a)-(f) by reservoir fluid flow that is received by the
reservoir
fluid receiver 602, such that the received reservoir fluid flow is conducted,
via: (a) the
passageway portion 630 disposed downhole relative to the passageway sealed
interface
628, and (b) the branches 603(a)-(0, to the reservoir fluid discharge
communicator 604,
while the flow diverter-effecting insert 624 is disposed within the passageway
626 of the insert-
receiving part 622, such as while the flow diverter-effecting insert 624 is
disposed in the flow
diverter-defining position.
[00115] In some embodiments, for example, and referring to Figure 9, the
reservoir fluid flow,
from the downhole wellbore space 610, is received by the reservoir fluid
receiver 602 (in this
embodiment, the inlet port 602A), and conducted through the downhole
passageway portion 630
37
CA 3032720 2019-02-05
to the reservoir fluid discharge communicator 604 (in the form of reservoir
fluid outlet ports
604(a)-(f), and the conduction from the downhole passageway portion 630 to the
ports 604(a)-(f)
is effected via a plurality of reservoir fluid conductor branches 603(a)-(f)
extending between the
downhole passageway portion 630 and the ports 604(a)-(f)), as is represented
by flowpath 10.
The passageway sealed interface 628 prevents, or substantially prevents, the
received reservoir
fluid flow within the passageway portion 630 from bypassing the reservoir
fluid discharge
communicator 604 such that a reservoir fluid flow is discharged through the
reservoir fluid
discharge communicator 604. Upon
discharging from the reservoir fluid discharge
communicator 604, the reservoir fluid flow becomes disposed within the uphole
wellbore space
108 and, while the discharged reservoir fluid is disposed within the uphole
wellbore space 108,
gaseous material is separated from the discharged reservoir fluid, in response
to at least
buoyancy forces, such that a gas-depleted reservoir fluid flow is obtained.
Because the wellbore
sealed interface 500 is preventing, or substantially preventing, the bypassing
of the gas-depleted
reservoir fluid receiver 608 by the obtained gas-depleted reservoir fluid
flow, the obtained gas-
depleted reservoir fluid flow is conducted to the gas-depleted reservoir fluid
receiver 608. The
gas-depleted reservoir fluid flow, received by the gas-depleted reservoir
fluid receiver 608 (in the
form of inlet ports 608(a)-(f)), is conducted to the uphole passageway portion
632, via: (i) a
plurality of gas-depleted reservoir fluid conductor branches 610(a)-(f)
extending between the
gas-depleted reservoir fluid receiver 608 and the uphole passageway portion
632), (ii) the ports
6245, (iii) the fluid passage 6244 of the flow diverter-effecting insert 624,
and (iv) the port 6243,
as is represented by flowpath 12. The passageway sealed interface 628
prevents, or substantially
prevents, the gas-depleted reservoir fluid flow from bypassing the ports 6245
such that the gas-
depleted reservoir fluid flow is discharged through the gas-depleted reservoir
fluid discharge
communicator 612.
[00116] In
some embodiments, for example, the flow diverter-effecting insert 624 is
disposed
for becoming releasably retained relative to the insert-receiving part 622 via
a coupler 804
incorporated in the reservoir fluid conducting assembly 14 such that the flow
diverter-effecting
insert is disposed within the passageway in the flow diverter-defining
position. In some
embodiments, for example, the releasable retention is effected with a lock
mandrel 802 that has
been integrated within the reservoir fluid conducting assembly 14. In this
respect, while
38
CA 3032720 2019-02-05
disposed in the flow diverter-defining position, the flow diverter-effecting
insert 624 is
releasably retained to the insert-receiving part 622 via a lock mandrel 802
that has been
integrated within the reservoir fluid conducting assembly 14 uphole of the
insert-receiving part
622, such that the flow diverter-effecting insert is disposed in the flow
diverter-defining position,
the flow diverter-effecting insert 624 while being releasably retained
relative to the insert-
receiving part 622. In some embodiments, for example, the flow diverter-
effecting insert 624 is
run downhole with the lock mandrel 802 with a running tool and set within the
reservoir fluid
conducting assembly 14 by coupling the lock mandrel 802 to a corresponding
nipple 804 within
the reservoir fluid conducting assembly 14. Exemplary lock mandrels 802
include the Otis
XNTM lock mandrel that is available from Halliburton Company. The
corresponding nipple for
the Otis XNTM lock mandrel is the Otis XNTM nipple.
[00117] Upon release from retention relative to the insert-receiving part
622 with a suitable
tool, the flow diverter-effecting insert 624 is displaceable, relative to the
insert-receiving part
622 (such as, for example, in an uphole direction through the passage 14A such
that the flow
diverter-effecting insert 624 is removed from the assembly 10) such that
occlusion of the
passageway of the insert-receiving part, by the flow diverter-effecting insert
624, is defeated, or
at least partially defeated (such as, for example, removed or at least
partially removed), and such
that the insert-receiving part 622 becomes disposed in a non-occluded
condition.
[00118] In this respect, while the flow diverter-effecting insert 624 is
releasably retained
relative to the insert-receiving part 622, interchangeability of the first
reservoir fluid-supplying
conductor 12 with the second reservoir fluid-supplying conductor 12 is
prevented. Upon release
of the flow diverter-effecting insert 624 from the retention relative to the
insert-receiving part
622, and displacement of the flow diverter-effecting insert 624, relative to
the insert-receiving
part 622 (such as, for example, in an uphole direction through the a reservoir
fluid-producing
conductor 210 such that the flow diverter-effecting insert 624 is removed from
the assembly 10)
such that occlusion of the passageway of the insert-receiving part, by the
flow diverter-effecting
insert 624, is defeated, or at least partially defeated (such as, for example,
removed or at least
partially removed), the insert-receiving part 622 becomes disposed in a non-
occluded condition,
and the preventing of the interchangeability of the first reservoir fluid-
supplying conductor 12
39
CA 3032720 2019-02-05
with the second reservoir fluid-supplying conductor 12 is defeated. In some
embodiments, for
example, the displacing of the flow diverter-effecting insert 624 is effected
via slickline.
[00119] In some embodiments, for example, the first reservoir fluid-supplying
conductor 12 is
releasably retained relative to the first assembly counterpart 10A, such as,
for example, the
diverter body portion 601, by coupling between a lock mandrel 806 and a
corresponding nipple
808. In some embodiments, for example, the first reservoir fluid-supplying
conductor 12 is run
downhole with the lock mandrel with a running tool, through the passageway of
the insert
receiving part 622, and set within a passage defined within the diverter body
portion 601 by
coupling the lock mandrel to a corresponding nipple within the diverter body
portion 601, such
that the reservoir fluid-supplying conductor 12 is hung from the nipple.
Exemplary lock
mandrels include the Otis XNTM lock mandrel that is available from Halliburton
Company. The
corresponding nipple for the Otis XNTM lock mandrel is the Otis XNTM nipple.
In this respect,
in some embodiments, for example, the first assembly counterpart 10A further
includes the
wellbore sealed interface effector 400, and the reservoir fluid-supplying
conductor 12 is
removable from the assembly 10, without having to remove other components,
such as the
wellbore sealed interface effector 400.
[00120] In
some embodiments, for example, to interchange the first reservoir fluid-
supplying
conductor 12 with the second reservoir fluid-supplying conductor 12, the first
reservoir fluid-
supplying conductor 12 is removed from the wellbore via the passageway of the
insert-receiving
part 622 and the reservoir fluid-producing conductor 210. In this respect,
prior to the removal of
the first reservoir fluid-supplying conductor 12 from the wellbore, the flow
diverter-effecting
insert 624 is removed from the wellbore, and prior to the removal of the
insert 624 from the
wellbore, the pump 300 is removed from the wellbore. In some embodiments, for
example, the
first reservoir fluid-supplying conductor 12 is removable via slickline. In
some embodiments,
for example, the first reservoir fluid-supplying conductor 12 is rod
retrievable. After the first
reservoir fluid-supplying conductor 12 has been removed from the wellbore 102,
the second
reservoir fluid-supplying conductor 12 is run-in-hole, via the passage 14A,
including the
passageway 626 of the insert-receiving part 622, and coupled to the same
nipple used at which
the first reservoir fluid-supplying conductor 12 had been releasably retained
(using a
CA 3032720 2019-02-05
corresponding lock mandrel) such that the second reservoir fluid-supplying
conductor 12 is
releasably retained relative to the insert-receiving part 622. Sequentially,
the flow diverter-
effecting insert 624, and then the pump 300, are conveyed downhole through the
passage 14A
and correspondingly re-deployed within the reservoir fluid conducting assembly
14 so as to
enable production using the modified assembly 10 (now with a reservoir fluid-
supplying
conductor 12 having a narrower cross-sectional flow area).
[00121] In some of these embodiments, for example, it is advantageous to
switch to a
narrower reservoir fluid-supplying conductor 12 as the reservoir pressure is
depleted and the
bottomhole pressure is reduced, so as to maintain flow the produced reservoir
fluid within the
reservoir fluid-supplying conductor 12 at a suitable velocity and mitigate
slugging.
[00122] In some embodiments, for example, the assembly 10 is emplaced within
the wellbore,
with effect that the assembly 10 is disposed within the wellbore. After the
assembly 10 has been
emplaced within the wellbore, the sealed interface effector 400 (e.g. packer)
is actuated, thereby
establishing the sealed interface 500.
[00123] In
the above description, for purposes of explanation, numerous details are set
forth in
order to provide a thorough understanding of the present disclosure. However,
it will be
apparent to one skilled in the art that these specific details are not
required in order to practice
the present disclosure.
Although certain dimensions and materials are described for
implementing the disclosed example embodiments, other suitable dimensions
and/or materials
may be used within the scope of this disclosure. All such modifications and
variations, including
all suitable current and future changes in technology, are believed to be
within the sphere and
scope of the present disclosure. All references mentioned are hereby
incorporated by reference
in their entirety.
41
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