U.S. patent application number 12/635058 was filed with the patent office on 2011-06-16 for packing tube isolation device.
This patent application is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. Invention is credited to Harold Steven Bissonnette, Raymond J. Tibbles.
Application Number | 20110139465 12/635058 |
Document ID | / |
Family ID | 44141645 |
Filed Date | 2011-06-16 |
United States Patent
Application |
20110139465 |
Kind Code |
A1 |
Tibbles; Raymond J. ; et
al. |
June 16, 2011 |
PACKING TUBE ISOLATION DEVICE
Abstract
A packing tube isolation assembly, which includes a first
conduit, a second conduit, and a sealing member. The first conduit
extends substantially parallel to a longitudinal axis of a tube
disposable in a wellbore and has an opening defined in the first
conduit. The second conduit fluidly connects to an annulus of the
wellbore and to the opening of the first conduit, and is disposed
at an angle with respect to the first conduit. The sealing member
is disposed adjacent the second conduit and is configured to move
into and substantially obstruct the second conduit when the second
conduit is at least partially packed with a gravel slurry.
Inventors: |
Tibbles; Raymond J.; (Kuala
Lumpur, MY) ; Bissonnette; Harold Steven; (Sugar
Land, TX) |
Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION
SUGAR LAND
TX
|
Family ID: |
44141645 |
Appl. No.: |
12/635058 |
Filed: |
December 10, 2009 |
Current U.S.
Class: |
166/387 ;
166/51 |
Current CPC
Class: |
E21B 34/063 20130101;
E21B 43/04 20130101; E21B 33/124 20130101 |
Class at
Publication: |
166/387 ;
166/51 |
International
Class: |
E21B 33/12 20060101
E21B033/12; E21B 43/04 20060101 E21B043/04 |
Claims
1. A packing tube isolation assembly, comprising: a first conduit
extending substantially parallel to a longitudinal axis of a tube
disposed in a wellbore and having an opening defined in the first
conduit; a second conduit fluidly connected to an annulus of the
wellbore and to the opening of the first conduit; and a sealing
member disposed adjacent the second conduit and configured to
substantially obstruct the second conduit when the second conduit
is at least partially packed with a gravel slurry.
2. The packing tube isolation assembly of claim 1, wherein the
sealing member is movable from a first position where sealing
member allows fluid communication through the second conduit, to a
second position where the sealing member blocks fluid communication
through the second conduit.
3. The packing tube isolation assembly of claim 2, wherein the
sealing member comprises a slidable member configured to
increasingly extend out of the housing and into the second conduit
as the sealing member moves toward the second position.
4. The packing tube isolation assembly of claim 2, further
comprising a restraining element, wherein the restraining element
locks the sealing member in at least one of the first and second
positions.
5. The packing tube isolation assembly of claim 2, further
comprising a flapper having a first flapper position in which at
least a portion of the flapper is substantially parallel to the
second conduit and opposes the sealing member from moving to the
second position, and a second position in which the flapper extends
at least partially through the second conduit.
6. The packing tube isolation assembly of claim 2, further
comprising a housing at least partially containing the sealing
member in the first position and including: an inlet in fluid
communication with the first conduit and an interior of the
housing; and an outlet in fluid communication with the interior of
the housing and the annulus of the wellbore, and disposed on an
opposite side of the sealing member from the inlet.
7. The packing tube isolation assembly of claim 6, further
comprising a flow control device disposed in the inlet and
configured to block fluid communication through the inlet until a
pressure differential between the first conduit and the annulus of
the wellbore reaches an activation level.
8. The packing tube isolation assembly of claim 7, wherein the flow
control device comprises at least one of a rupture disk and a
pressure relief valve.
9. A system for gravel packing a well, comprising: a tube at least
partially disposed in the well; and first and second packing tube
isolation assemblies disposed around the tube, each comprising: a
first conduit having an opening formed through a wall thereof; a
second conduit connected to the first conduit at the opening, in
fluid communication therewith and with the well; and a sealing
member disposed adjacent the second conduit and configured to block
the second conduit when a pressure differential between the well
and the first conduit reaches an activation level.
10. The system of claim 9, wherein the sealing member comprises a
sliding sleeve, a flapper valve, a check valve, or a combination
thereof.
11. The system of claim 9, further comprising a housing connected
with the second conduit and at least partially containing the
sealing member.
12. The system of claim 11, wherein the housing comprises an inlet
in fluid communication with the first conduit and a first space
defined between the sealing member and the housing, and an outlet
in fluid communication with the well and a second space formed
between the sealing member and the housing.
13. The system of claim 12, wherein a flow control device is
disposed at least partially in the inlet.
14. The system of claim 13, wherein the flow control device
comprises a rupture disk configured to rupture when the pressure
differential reaches the activation level, such that fluid
communication through the inlet moves the sealing member.
15. The system of claim 13, wherein the flow control device
comprises a pressure relief valve configured to open when the
pressure differential reaches the activation level, such that fluid
communication through the inlet moves the sealing member.
16. A method of isolating a packing tube, comprising: supplying a
gravel slurry through a first conduit; channeling at least a
portion of the gravel slurry from the first conduit to a second
conduit; distributing the gravel slurry to a portion of an annulus
of a wellbore through one or more outlets defined in the second
conduit; actuating a sealing member connected to the second conduit
when the second conduit is at least partially packed with gravel
slurry; and isolating at least a portion of the second conduit from
the first conduit with the sealing member.
17. The method of claim 16, wherein actuating the sealing member
comprises actuating a flow control device positioned between the
first conduit and the sealing device with a pressure differential
between the portion of the annulus of the wellbore and the first
conduit to place the first conduit in fluid communication with the
sealing member.
18. The method of claim 17, wherein actuating the sealing member
further comprises: sliding the sealing member from inside a housing
into the second conduit; and blocking the second conduit with the
sealing member.
19. The method of claim 18, wherein actuating the flow control
device comprises opening a pressure relief valve or rupturing a
disk in the flow control device.
20. The method of claim 17, wherein actuating the sealing member
comprises sliding the sealing member into the second conduit to
block the second conduit by applying the pressure differential
across the sealing member.
Description
BACKGROUND
[0001] When a hydrocarbon or other fluid is produced from a
subterranean formation, the fluid typically contains particulates
or sand. The production of sand from the well is typically
controlled in order to extend the life of the well. Gravel packs or
screens can be used to filter the particulates of the produced
fluids so the fluids without the particulates can be communicated
to the surface.
[0002] A challenge to using conventional gravel packing operations
arises when the fluid of the gravel slurry prematurely separates
from the gravel slurry, leaving the gravel behind. This is known as
dehydration. When this occurs, a bridge can form in the slurry flow
path, forming a bather that prevents slurry upstream of the bridge
from being communicated downhole. Bridges can also disrupt and
possibly prevent the packing of gravel around some parts of the
sand screen, for example, leaving areas in the well devoid of
gravel packing.
[0003] Another challenge associated with gravel packing operations
arises when wellbore equipment, such as a packer, or another
obstruction is located within the wellbore. In such cases, the
gravel pack conventionally has to be diverted around these
obstructions.
[0004] One way of overcoming the challenges presented during gravel
packing operations is to provide alternative flow paths around
obstructions, such as shunt tubes. A shunt tube can have one or
more tubes called transport tubes that can deliver slurry to a
number of packing tubes located along the wellbore. When a wellbore
section is gravel packed, the packing tubes associated with the
wellbore section can also be packed off, allowing gravel slurry
flow to be diverted further down the wellbore through the transport
tubes. Although the packed packing tube diverts most of the flow
down the transport tube, a small amount of the gravel slurry fluid
can leak through the transport tube into the packed packing tube.
This leakage can cause the gravel slurry remaining in the transport
tube to dehydrate and can limit the maximum length of the wellbore
that can be packed.
[0005] Additionally, after one or more sections of the wellbore are
gravel packed, hydrocarbons can be produced to the surface through
the tubing attached to the sand screen. During production, however,
the open packing tubes can allow produced fluids to enter the shunt
tube system, which can have an adverse affect on the production of
hydrocarbons from the wellbore.
[0006] There is a need, therefore, for new apparatus or assemblies
that can selectively isolate a transport tube from a packing
tube.
SUMMARY
[0007] Embodiments of the disclosure provide an exemplary packing
tube isolation assembly, which includes a first conduit, a second
conduit, and a sealing member. The first conduit extends
substantially parallel to a longitudinal axis of a tube disposable
in a wellbore and has an opening defined in the first conduit. The
second conduit fluidly connects to an annulus of the wellbore and
to the opening of the first conduit, and is disposed at an angle
with respect to the first conduit. The sealing member is disposed
adjacent the second conduit and is configured to move into and
substantially obstruct the second conduit when the second conduit
is at least partially packed with a gravel slurry.
[0008] Embodiments of the disclosure also provide a system for
gravel packing a well, which includes a tube, first and second
packing tube isolation assemblies, and a packer. The tube is at
least partially disposed in the well. The first and second packing
tube isolation assemblies are disposed around the tube, and each
includes a first conduit, a second conduit and a sealing member.
The first conduit has an opening formed through a wall thereof. The
second conduit is connected to the first conduit around the
opening, and is in fluid communication therewith and with the well.
The sealing member is disposed adjacent the second conduit and is
configured to block the second conduit when a pressure differential
between the well and the first conduit reaches an activation level.
Further, the packer is disposed around the tube, between the first
and second packing tube isolation assemblies.
[0009] Embodiments of the disclosure further provide an exemplary
method of isolating a packing tube. The exemplary method may
include supplying a gravel slurry through a first conduit, and
channeling at least a portion of the gravel slurry from the first
conduit to a second conduit. The exemplary method may also include
distributing the gravel slurry to a portion of an annulus of a
wellbore through one or more outlets defined in the second conduit,
and actuating a sealing member connected to the second conduit when
the second conduit is at least partially packed with gravel slurry.
The exemplary method may further include isolating at least a
portion of the second conduit from the first conduit with the
sealing member.
BRIEF DESCRIPTION OF THE DRAWINGS
[0010] So that the recited features can be understood in detail, a
more particular description, briefly summarized above, may be had
by reference to one or more embodiments, some of which are
illustrated in the appended drawings. It is to be noted, however,
that the appended drawings illustrate only typical embodiments and
are therefore not to be considered limiting of its scope, for the
invention may admit to other equally effective embodiments.
[0011] FIG. 1 depicts a cross-sectional view of an illustrative
packing tube isolation assembly in a first position, according to
one or more embodiments described.
[0012] FIG. 2 depicts a cross-sectional view of the illustrative
packing tube isolation assembly of FIG. 1 in a second position,
according to one or more embodiments described.
[0013] FIG. 3 depicts a schematic view of an illustrative sand
completion system disposed within a wellbore and having two packing
tube isolation assemblies, according to one or more embodiments
described.
[0014] FIG. 4 depicts a schematic view of the illustrative sand
completion system of FIG. 3 with one of the packing tube isolation
assemblies in a second position, according to one or more
embodiments described.
[0015] FIG. 5 depicts a cross-sectional view of another
illustrative packing tube isolation assembly in a first position,
according to one or more embodiments described.
[0016] FIG. 6 depicts a cross-sectional view of the illustrative
packing tube isolation assembly of FIG. 5 in a second position,
according to one or more embodiments described.
[0017] FIG. 7 depicts a cross-sectional view of yet another
illustrative packing tube isolation assembly, according to one or
more embodiments described.
DETAILED DESCRIPTION
[0018] FIGS. 1 and 2 depict an illustrative packing tube isolation
assembly 100, according to one or more embodiments. FIG. 1 shows
the packing tube isolation assembly 100 in first or "open"
position, and FIG. 2 shows the packing tube isolation assembly 100
in a second or "closed" position. In one or more embodiments, the
packing tube isolation assembly 100 can include a first conduit or
supply tube 110 in fluid communication with one or more second
conduits or slave tubes 120. The first conduit 110 can be or
include one or more tubular members or channels. For example, the
first conduit 110 can be a transport tube that can be disposed
within a wellbore as part of a shunt tube system, which is shown in
FIGS. 3 and 4 and described below with reference thereto. The first
conduit 110 can have one or more first flow paths 115 (one shown)
to transport or channel a gravel slurry therethrough.
[0019] The second conduit 120 can also be or include one or more
tubular members or channels defining a second flow path 125
therein. For example, the second conduit 120 can be a packing tube
connected to the first conduit 110. The second conduit 120 can also
fluidly communicate with an annulus formed between the packing tube
isolation assembly 100 and a wall of a wellbore, as shown in, and
described below with reference to, FIGS. 3 and 4.
[0020] The first flow path 115 can be in selective fluid
communication with the second conduit 120. For example, the first
conduit 110 can have one or more openings 112 formed therethrough,
allowing the first and second conduits 110 and 120 to fluidly
communicate. As used herein, the term "selective fluid
communication" is generally defined to mean that a flow can be
allowed or partially or completely blocked, obstructed, or
otherwise attenuated as desired.
[0021] In one or more embodiments, the second conduit 120 can have
a first portion 122 and a second portion 124 that can be welded,
riveted, or otherwise fastened or affixed to the first conduit 110
around the opening 112. The first portion 122 can be disposed at an
angle relative to a longitudinal axis of the first conduit 110,
such that the first portion 122 of the second conduit 120 is not
parallel to the first conduit 110, and at least a portion of the
second portion 124 can be substantially parallel to the
longitudinal axis of the first conduit 110. The angle of the first
portion 122 can be, for example, any angle greater than 0 degrees,
and can range from about 0.5 degrees to about 90 degrees, from
about 20 degrees to about 70 degrees, or from about 30 degrees to
about 60 degrees. The first and second portions 122 and 124 can be
provided by a single tubular member that is, for example, bent, or
can be two discrete tubular members fixed together at the desired
angle, by welding or fastening, for example, using flanges, or the
like.
[0022] One or more ports or outlets (three are shown 128A, 128B,
and 128C) can be formed through the second portion 124 of the
second conduit 120. The outlets 128A, 128B, 128C allow fluid
communication between the first flow path 115 of the first conduit
110 through the second conduit 120 to an area external to the
packing tube isolation assembly 100, as described below with
reference to FIGS. 3 and 4. Although not shown, the outlets 128A,
128B, 128C can include one or more nozzles connected to or disposed
within the second conduit 120.
[0023] The second conduit 120 can further include one or more
chambers 140 disposed therein. The chamber 140 can be disposed
within the second conduit 120, adjacent the first portion 122. The
chamber 140 can be in fluid communication with the first flow path
115 and the first conduit 110 via a flow path or inlet 160. The
chamber 140 can also be in fluid communication with the exterior of
the packing tube isolation assembly 100, such as the annulus 148 of
a wellbore, via a flow path or outlet 170, as shown in and
described below with reference to FIGS. 3 and 4. The flow paths
160, 170 can be an aperture, channel, conduit, control line, or the
like.
[0024] In one or more embodiments, a flow control device 165 can be
located in the inlet 160 to allow selective communication between
the chamber 140 and the first conduit 110. Illustrative flow
control devices 165 can include rupture disks, pressure relief
valves, or any other pressure sensitive devices. In another
exemplary embodiment, the flow control device 165 can be a
dissolvable plug or a solenoid. In another example, the flow
control device 165 can be a pressure-sensitive device that is
selectively actuatable or opened by exposure to an activation level
of pressure differential or another trigger, as described
below.
[0025] A sealing member 150 can be at least partially disposed
within the chamber 140. The sealing member 150 can be any slidable
body or member that can move from a first or "open" position within
the chamber 140, as depicted in FIG. 1, to a second or "closed"
position within the chamber 140, as depicted in FIG. 2. When the
sealing member 150 is in the first or "open" position (FIG. 1), the
first flow path 115 can be in fluid communication with the second
flow path 125. When the sealing member 150 is in the second or
"closed" position (FIG. 2), the first flow path 115 can be
prevented from communicating with the second flow path 125.
[0026] In at least one specific embodiment, the sealing member 150
can act as a piston that is moveable by applying a force against an
upper surface thereof. As depicted in FIG. 1, the sealing member
150 can be substantially flat at an upper surface or first end
thereof, and can be tapered or frustoconical at a second end
thereof to correspond to the angled first portion 122 of the second
conduit 120, among many other equally effective configurations are
envisaged. As such, the sealing member 150 acts as a gate or switch
to allow or block fluid flow through the opening 112, between the
first flow path 115 and the second flow path 125.
[0027] In at least one specific embodiment, the sealing member 150
can be actuated by pressure within the first conduit 110. For
example, when the second conduit 120 is packed or blocked, a
pressure differential can form within the first conduit 110. The
pressure within the first conduit 110 can rupture or otherwise
cause the flow control device 165 to open, thereby placing the flow
control device 165 in an open configuration. When the flow control
device 165 is in an open configuration, pressure within the first
conduit 110 can be communicated to the chamber 140, via the first
inlet 160. When the sealing member 150 is axially moved, at least a
portion of the sealing member 150 can extend past the chamber 140
and block the opening 112 to the second conduit 120. Accordingly,
communication between flow paths 115, 125 can be blocked or
prevented.
[0028] The outlet 170 can allow fluids such as air or liquids
entrained within the chamber 140 to escape, i.e. vent, into the
annulus 148 of the wellbore or the flow path 125 when the sealing
member 150 moves from the first position to the second position.
Such communication can avoid or minimize back pressure that might
otherwise impede the progression of the sealing member 150 from the
first position to the second position.
[0029] In one or more embodiments, the sealing member 150 can be
restrained in the first position by a restraining element 151.
Illustrative restraining elements 151 can include shear pins or
shear screws. Illustrative restraining elements 151 can also
include an electrically-actuating element, such as solenoid, or a
pneumatically- or hydraulically-actuating element, or the like. In
operation, the restraining element 151 can receive a signal to be
released, thereby releasing the sealing member 150 from its first
position to the second position (FIG. 2). One or more control lines
can be used to transmit a release signal to the restraining element
151. Illustrative control lines can include hydraulic control
lines, pneumatic control lines, electronic control lines, or
similar control lines. In one or more embodiments, wireless
telemetry can be employed instead of, or in addition to, control
lines.
[0030] FIG. 3 depicts an exemplary embodiment of a sand completion
system 300, which integrates a plurality of the packing tube
isolation assemblies 100, for example, a first packing tube
assembly 100A and a second packing tube assembly 100B. It will be
appreciated that various embodiments of the sand completion system
300 can include additional or fewer packing tube isolation
assemblies 100, and may also include other packing tube isolation
devices. The sand completion system 300 can be disposed in a
wellbore 340, and can include one or more particulate control
devices, for example, first and second particulate control devices
352, 354, and a tube 305. The first conduits 110 of the packing
tube isolation assemblies 100A, B can be disposed substantially
parallel to a longitudinal axis of the tube 305, such that, for
example, in a vertical portion of the wellbore 340, the first
conduits 110 are also vertically oriented. One or more packer
assemblies (three are shown: 370, 380, 385) can be located around
the completion system 300.
[0031] In one or more embodiments, the first and second particulate
control devices 352, 354 can be sand control screens. For example,
the first and second particulate control devices 352, 354 can be
commercially-available screens, slotted or perforated liners or
pipes, screened pipes, pre-packed or dual pre-packed screens and/or
liners, or combinations thereof. The packer assemblies 370, 380,
385 can include one or more sealing members. For example the packer
assemblies 370, 380, 385 can include one or more packers capable of
sealing off the annular region or annulus 364 between the
completion system 300 and the wellbore 340. Illustrative packer
assemblies 370, 380, 385 can include compression or cup packers,
inflatable packers, swellable packers, "control-line bypass"
packers, polished bore retrievable packers, other common downhole
packers, or combinations thereof.
[0032] In exemplary operation, the completion system 300 can be
conveyed into the wellbore 340, and can be used to perform downhole
operations such as gravel packing. The wellbore 340 can have an
open or cased borehole. When the wellbore 340 has a cased borehole,
the wellbore 340 can have a casing 343. The wellbore 340 can have
one or more hydrocarbon producing zones, for example, first and
second hydrocarbon producing zones 342, 348.
[0033] The completion system 300 can be located within the wellbore
340, such that, in an exemplary embodiment, at least one packing
tube isolation assembly 100 can be associated or placed adjacent
each of potentially many identified hydrocarbon producing zones.
For example, the first packing tube isolation assembly 100A can be
located adjacent the first hydrocarbon producing zone 342, and the
second packing tube isolation assembly 100B can be located adjacent
the second hydrocarbon producing zone 348.
[0034] After locating the completion 300 within the wellbore 340,
the packer assemblies 370, 380, 385 can be set. The packer
assemblies 370, 380, 385 can define first and second wellbore
regions 366, 368, by isolating the first and second hydrocarbon
producing zones 342, 348 from one another. The packer assemblies
370, 380, 385 can be set by application of pressure, by application
of axial force through the tube 305, by swelling, or in other ways
known in the art.
[0035] In an exemplary embodiment, the packer assemblies 370, 380
can isolate the first hydrocarbon producing zone 342 and define the
first wellbore region 366. The packer assemblies 380, 385 can
similarly isolate the second hydrocarbon producing zone 348 and
define the second wellbore region 368. Consequently, the first
wellbore region 366 can be associated with the first hydrocarbon
producing zone 342, and the second wellbore region 368 can be
associated with the second hydrocarbon producing zone 348.
[0036] The first packing tube isolation assembly 100A can be
deployed to the first wellbore region 366, and the second packing
tube isolation assembly 100B can be deployed to the second wellbore
region 368. The particulate control device 352 can be also be
deployed to the first wellbore region 366, and the particulate
control device 354 can likewise be deployed to the second wellbore
region 368. In one or more embodiments, the first conduit 110 of
the first packing tube isolation assembly 100A can be configured to
extend through the packer assemblies 370, 380 and can connect with
the first conduit 110 of the second packing tube isolation assembly
100B. As such, the first conduits 110 of the adjacent packing tube
isolation assemblies 100A, B can be in fluid communication with one
another. Further, the packer assemblies 380, 385 can seal about the
exterior of the portion of the first conduit 110 extending
therethrough.
[0037] In an exemplary embodiment, after the packer assemblies 370,
380, 385 are set, gravel slurry 390 can be pumped or sent down the
first conduit 110 of the first packing tube isolation assembly
100A. The gravel slurry 390 can flow from the first flow path 115
(FIGS. 1 and 2) of the first packing tube isolation assembly 100A
through the second conduit 120 to the second flow path 125. The
gravel slurry 390 can flow along the second flow path 125 to outlet
128, which can be outlets 128A, 128B, 128C (FIGS. 1-2), of the
second conduit 120. The gravel slurry 390 can flow through the
outlet 128 into the annular region 364 of the first wellbore region
366. The gravel slurry 390 can pack about the first particulate
control device 352 as the fluid in the gravel slurry 390 migrates
through the particulate control device 352. The fluid of the gravel
slurry 390 that migrates through the particulate control device 352
can return to the surface, via the tube 305.
[0038] The gravel slurry 390 can be supplied to the annular region
364 of the first wellbore region 366, until the gravel slurry 390
at least partially covers or packs the outlet 128 and/or the second
conduit 120 of the first packing tube isolation assembly 100A. A
pressure differential can be created between the first conduit 110
of the first packer tube isolation assembly 100A and the first
wellbore region 366 when at least some of the outlets 128 (e.g.,
128A, 128B, 128C of FIGS. 1-2) and/or the second conduit 120 are at
least partially packed with gravel slurry 390.
[0039] With additional reference to FIGS. 1 and 2, in an exemplary
embodiment, the flow control device 165 can be configured to
rupture, open a pressure relief valve, shear frangible pins or
screws, and/or otherwise communicate the chamber 140 with the first
conduit 110 in response to the described pressure differential. For
example, a desired activation level of the pressure differential
can be predetermined, and the flow control device 165 can be
configured to allow communication through the inlet 160 in response
thereto. In an exemplary embodiment, the flow control device 165
can rupture, allowing a gravel slurry 390, and/or other fluid
within the first conduit 110 to communicate with a space 145 in the
chamber 140, via inlet 160, thereby applying the pressure
differential across the sealing member 150. In another exemplary
embodiment, after the pressure differential is recorded, for
example, with a pressure transducer (not shown), a user or computer
at the surface can transmit a control signal to the flow control
device 165 via control lines or wireless telemetry. This can prompt
the flow control device 165 to move into an open position, which
can allow the communication of fluid therethrough and/or to release
the sealing member 150 from the first position, if the sealing
member 150 has been restrained therein.
[0040] The ingress of gravel slurry 390 or other fluids from the
first conduit 110 into the space 145 can be propelled by the
pressure differential between the first conduit 110 and the packed
first wellbore region 366. The ingress of the gravel slurry 390 can
urge, propel, actuate, and/or slide the sealing member 150 from the
first position to the second position as the gravel slurry 390
enters the chamber 140. In an exemplary embodiment, the sealing
member 150 can also, or instead, be urged manually from the first
position to the second position using a mechanical device (not
shown). The sealing member 150 in the second position can block the
second conduit 120 and isolating the flow paths 115, 125 from one
another, as shown in FIG. 2. The isolation of the first and second
flow paths 115, 125 of the first packing tube isolation assembly
100A from one another, can effectively prevent undesired fluid loss
of the gravel slurry 390 through the flow path 125 as lower
wellbore regions are gravel packed, and can prevent hydrocarbons
produced in wellbore region 366 from entering the first conduit 110
of the first packing tube isolation assembly 100A.
[0041] After the sealing member 150 of the first packing tube
isolation assembly 100A is actuated, the gravel slurry 390 can flow
to lower wellbore regions, such as the second wellbore region 368,
as shown in FIG. 4. FIG. 4, with continuing reference to FIG. 3,
depicts the sand completion system 300, with the first wellbore
region 366 having been gravel packed as described above, and the
sealing member 150 effectively isolating the first and second flow
paths 115, 125 of the first packing tube isolation assembly 100A
from one another. Consequently, the flow of gravel slurry 390 can
bypass the first wellbore region 366 and can flow to the first flow
path 115 of the second packing tube isolation assembly 100B. The
gravel slurry 390 can flow from the flow path 115 of the second
packing tube isolation assembly 100B to the flow path 125 of the
second packing tube isolation assembly 100B. Once the gravel slurry
390 gravel packs an annulus 365 of the second wellbore region 368,
the sealing member 150 of the second packing tube isolation
assembly 100B can block the continued flow of gravel slurry 390, in
a similar operation as that just described with reference to the
first packing tube isolation assembly 100A.
[0042] Gravel packing, as described for the first and second
wellbore regions 366, 368, can be repeated for any additional
wellbore regions of the wellbore 340. When gravel pack operations
of one or more wellbore regions of the wellbore 340 are completed,
production operations can be conducted. During production
operations, hydrocarbons produced from each of the hydrocarbon
producing zones 342, 348 (and any others) can be communicated to
the surface, via the tube 305. In one or more embodiments, the
completion system 300 can be adapted to allow for selective
simultaneous production of hydrocarbons from each hydrocarbon
producing zone 342, 348 or hydrocarbons can be independently
produced from one or more of the hydrocarbon producing zones 342,
348. For example, flow control devices (not shown) can be disposed
about the tube 305 and can be selectively actuated to control the
flow of hydrocarbons into the tube 305.
[0043] FIGS. 5 and 6 depict another embodiment of the packing tube
isolation assembly 100. The packing tube isolation assembly 100 can
be substantially similar to those described above with reference
to, and shown in, FIGS. 1 and 2, and can include a flapper or reed
200 connected to or adjacent the chamber 140, such that the flapper
200 pivots from a first flapper position to a second flapper
position. When the flapper 200 is in the first flapper position,
the flapper 200 can be generally parallel to, and, in one or more
embodiments, flush with the first portion 122 of the second conduit
120. In this position, the flapper 200 can cover at least a portion
of the sealing member 150, thereby opposing the sealing member 150
moving out of the first or "open" position.
[0044] When the activation level of pressure differential is
present or it is otherwise desired to move the sealing member 150
to the second position, as described above with reference to FIGS.
1 and 2, the sealing member 150 can push the flapper 200 into the
second flapper position, as shown in FIG. 6. When the flapper 200
is in the second flapper position, the flapper 200 can extend at
least partially through the first portion 122 of the second conduit
120, thereby allowing the sealing member 150 to, for example,
descend partially out of the chamber 140 into the second conduit
120. In one or more embodiments, the flapper 200 can have a small
cross-section relative to a cross-section of the first portion 122.
Accordingly, even when the flapper 200 is in the second flapper
position, it can allow relatively free fluid communication between
the second conduit 120 and the first conduit 110.
[0045] In one or more embodiments, the flapper 200 can be
elastically deformed by the movement of the sealing member 150 to
second position, such that the flapper 200 essentially fails and
releases the sealing member 150. In one or more embodiments, the
flapper 200 can be hinged and restrained in the first flapper
position by any suitable device, such as a pin, solenoid and/or the
like, and then released such that movement of the sealing member
150 to the second position releases the flapper 200.
[0046] In one or more embodiments, the sealing member 150 can be
urged from the first position (FIG. 5) to the second position (FIG.
6) using a biasing member 202, which can be or include a spring or
the like. In one or more embodiments, the biasing member 202 can be
or include a leaf spring, compression spring, or any resilient
member. The biasing member 202 can be restrained in a compressed
state when the sealing member 150 is in the first position. The
biasing member 202 can thus supply a force to aid the movement of
the sealing member 150 to the second position.
[0047] FIG. 7 depicts yet another illustrative packing tube
isolation assembly 100, which can be substantially similar to any
of the illustrative packing tube isolation assemblies 100 described
above. In one or more embodiments, the packing tube isolation
assembly 100 can include a magnetic actuator 250. The magnetic
actuator 250 can be a passive fixed-pole magnet, such that the
magnetic actuator 250 can supply a generally constant magnetic
field to attract the sealing member 150, thereby aiding in drawing
the sealing member 150 from the first position to the second
position. In one or more embodiments, the magnetic actuator 250 can
instead apply a repulsive force on the sealing member 150 to
maintain the sealing member 150 in the first position. In one or
more embodiments, the magnetic actuator 250 can additionally
include or instead be an electromagnet which may be
remotely-controlled via wired connections or wireless telemetry,
for example, such that the magnetic actuator 250 can provide a
magnetic field of selectable strength and direction to attract or
repel the sealing member 150. Furthermore, the magnetic actuator
250 can be a solenoid that connects to the sealing member 150, or
can be a disk or block magnet or the like.
[0048] Accordingly, in one or more embodiments, the amount of force
required to move the sealing member 150 from the first position to
the second position can be balanced between any combination of
components that resist and those that assist the movement of the
sealing member 150 from the first position to the second position.
For example, the resistance of any combination of the restraining
member 151 (FIG. 1), flapper 200 (FIG. 5), and/or the magnetic
actuator 250 (FIG. 7), can be balanced with the urging of the
biasing member 202 (FIG. 6), the magnetic actuator 250 (FIG. 7),
and/or the pressure differential described above, until the force
is sufficient to move the sealing member 150 to the second
position.
[0049] As used herein, the terms "up" and "down"; "upper" and
"lower"; "upwardly" and "downwardly"; "upstream" and "downstream";
and other like terms are merely used for convenience to describe
spatial orientations or spatial relationships relative to one
another in a vertical borehole. However, when applied to equipment
and methods for use in deviated or horizontal boreholes, it is
understood to those of ordinary skill in the art that such terms
are intended to refer to a left to right, right to left, or other
spatial relationship as appropriate.
[0050] Certain embodiments and features have been described using a
set of numerical upper limits and a set of numerical lower limits.
It should be appreciated that ranges from any lower limit to any
upper limit are contemplated unless otherwise indicated. Certain
lower limits, upper limits and ranges appear in one or more claims
below. All numerical values are "about" or "approximately" the
indicated value, and take into account experimental error and
variations that would be expected by a person having ordinary skill
in the art.
[0051] Various terms have been defined above. To the extent a term
used in a claim is not defined above, it should be given the
broadest definition persons in the pertinent art have given that
term as reflected in at least one printed publication or issued
patent. Furthermore, all patents, test procedures, and other
documents cited in this application are fully incorporated by
reference to the extent such disclosure is not inconsistent with
this application and for all jurisdictions in which such
incorporation is permitted.
[0052] While the foregoing is directed to embodiments of the
present invention, other and further embodiments of the invention
may be devised without departing from the basic scope thereof, and
the scope thereof is determined by the claims that follow.
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