U.S. patent application number 12/554674 was filed with the patent office on 2009-12-31 for system and method for connecting multiple stage completions.
This patent application is currently assigned to SCHLUMBERGER TECHNOLOGY CORPORATION. Invention is credited to Jason K. Jonas.
Application Number | 20090321069 12/554674 |
Document ID | / |
Family ID | 38192274 |
Filed Date | 2009-12-31 |
United States Patent
Application |
20090321069 |
Kind Code |
A1 |
Jonas; Jason K. |
December 31, 2009 |
SYSTEM AND METHOD FOR CONNECTING MULTIPLE STAGE COMPLETIONS
Abstract
A technique is provided to facilitate connection of multiple
stage completions. A first completion stage is deployed at a
wellbore location. Subsequently, the next completion stage is moved
downhole into engagement with the first completion stage. The
completion stages each have communication lines that are coupled
together downhole via movement of the completion stages into
engagement.
Inventors: |
Jonas; Jason K.; (Missouri
City, TX) |
Correspondence
Address: |
SCHLUMBERGER RESERVOIR COMPLETIONS
14910 AIRLINE ROAD
ROSHARON
TX
77583
US
|
Assignee: |
SCHLUMBERGER TECHNOLOGY
CORPORATION
Sugarland
TX
|
Family ID: |
38192274 |
Appl. No.: |
12/554674 |
Filed: |
September 4, 2009 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
11561546 |
Nov 20, 2006 |
|
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12554674 |
|
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60597402 |
Nov 29, 2005 |
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Current U.S.
Class: |
166/242.6 |
Current CPC
Class: |
E21B 17/028 20130101;
E21B 17/046 20130101; E21B 17/08 20130101 |
Class at
Publication: |
166/242.6 |
International
Class: |
E21B 17/04 20060101
E21B017/04; E21B 17/00 20060101 E21B017/00 |
Claims
1. A completion system, comprising: a lower completion stage having
an integrated first communication line; and an upper completion
stage having an integrated second communication line, wherein
movement of the upper completion stage into engagement with the
lower completion stage at a downhole location automatically couples
the integrated second communication line to the integrated first
communication line.
2. The completion system as recited in claim 1, wherein the lower
completion stage comprises a plurality of integrated first
communication lines and the upper completion stage comprises a
plurality of integrated second communication lines.
3. The completion system as recited in claim 1, further comprising
a circumferential feature that enables automatic coupling of the
integrated second communication line and the integrated first
communication line regardless of the rotational orientation of the
upper completion stage relative to the lower completion stage.
4. The completion system as recited in claim 1, further comprising
a pressure compensation system.
Description
CROSS-REFERENCE TO RELATED APPLICATION
[0001] This present application is a Continuation application based
on U.S. patent application Ser. No. 11/561,546, filed Nov. 20, 2006
which claims priority to U.S. provisional application Ser. No.
60/597,402, filed Nov. 29, 2005, which are incorporated herein by
reference.
BACKGROUND
[0002] Many types of wells, e.g. oil and gas wells, are completed
in multiple stages. A lower stage of the completion is moved
downhole on a running string and may comprise either a stand-alone
screen or a screen with a gravel pack in the annulus between the
screen and the open hole or casing. After the lower completion
running string is retrieved, an upper stage of the completion is
deployed.
[0003] In many applications, it is desirable to instrument the
lower completion with electrical or optical sensors or to provide
for transmission of fluids to devices in the lower completion. For
example, a fiber optic cable can be placed in the annulus between
the screen and the open or cased hole. To enable communication of
signals between the sensor in the lower completion and the surface
or seabed, a wet-mate connection is needed between the upper and
lower completion equipment.
[0004] Optical, electrical and fluid wet-mate connectors typically
are designed as discrete stand-alone components. The stand-alone
connectors are mated in a downhole environment that can be full of
debris and contaminants. For instance, the mating can take place
after an open hole gravel pack which creates a high probability for
substantial amounts of debris and contaminants in the wellbore at
the vicinity of the connectors during the mating sequence. Existing
discrete optical, electrical and fluid wet-mate connectors have
proven to be very susceptible to contamination by debris during the
mating process.
[0005] Furthermore, the discrete nature of the connectors results
in an unfavorable geometry that can be difficult to integrate into
the completion equipment. The outer diameter of the completion
equipment must fit within the inner casing diameter. A centralized,
large diameter inner port also is needed to provide access for
service equipment into the lower completion and to provide a large
flow area for production or injection of fluids. The remaining
annular space is not well suited to the typical circular cross
section of discrete connectors. This limitation compromises the
overall design of the completion equipment and also limits the
total number of channels that can be accommodated within a given
envelope.
[0006] The geometry of the discrete connectors also increases the
difficulty of adequate flushing and debris removal from within and
around the connectors prior to and during the mating sequence.
Attempts to protect the connectors from debris and/or to provide
adequate flushing have lead to completion equipment designs that
have great complexity with an undesirable number of failure
modes.
SUMMARY
[0007] In general, the present invention provides a system and
method for coupling control line connectors during engagement of
multiple stage completions. A first completion stage has a
communication line protected from debris and other contaminants.
Similarly, a subsequent completion stage has a communication line
protected from debris and other contaminants. Following deployment
of the first completion stage to a downhole location, the
subsequent completion stage is moved into engagement with the first
completion stage. During the engagement process, the communication
lines are coupled.
BRIEF DESCRIPTION OF THE DRAWINGS
[0008] Certain embodiments of the invention will hereafter be
described with reference to the accompanying drawings, wherein like
reference numerals denote like elements, and:
[0009] FIG. 1 is a schematic view of a wellbore with a multiple
stage completion having completion stages being moved into
engagement, according to an embodiment of the present
invention;
[0010] FIG. 2 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during a different
period of the engagement process, according to an embodiment of the
present invention;
[0011] FIG. 3 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0012] FIG. 4 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0013] FIG. 5 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0014] FIG. 6 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0015] FIG. 7 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0016] FIG. 8 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0017] FIG. 9 is a schematic view similar to that of FIG. 1 but
showing the first and second completion stages during another
period of the engagement process, according to an embodiment of the
present invention;
[0018] FIG. 10 is a schematic view illustrating full engagement of
the first and second completion stages, according to an embodiment
of the present invention;
[0019] FIG. 11 is a cross-sectional view of an alternate embodiment
of a multiple stage completion, according to another embodiment of
the present invention;
[0020] FIG. 12 is a schematic view of another embodiment of a
multiple stage completion having completion stages moved into
engagement, according to an alternate embodiment of the present
invention;
[0021] FIG. 13 is a schematic view of another embodiment of a
multiple stage completion having completion stages moved into
engagement, according to an alternate embodiment of the present
invention;
[0022] FIG. 14 is a schematic view of another embodiment of a
multiple stage completion having completion stages moved into
engagement, according to an alternate embodiment of the present
invention; and
[0023] FIG. 15 is an elevation view of one example of a completion
system utilizing a multiple stage connection system, according to
an embodiment of the present invention.
DETAILED DESCRIPTION
[0024] In the following description, numerous details are set forth
to provide an understanding of the present invention. However, it
will be understood by those of ordinary skill in the art that the
present invention may be practiced without these details and that
numerous variations or modifications from the described embodiments
may be possible.
[0025] The present invention relates to a system and methodology
for connecting multiple stage completions in a wellbore
environment. The system and methodology enable protection of
communication line connectors during deployment and engagement of
completion stages. The communication line connectors associated
with each completion stage are enclosed for protection from debris
and other contaminants that can occur during certain wellbore
procedures, e.g. gravel packing procedures. Protecting the
communication line connectors facilitates coupling of the
connectors upon the engagement of the separate stages at a downhole
location. Additionally, the design of the stages and communication
line connectors provides a desirable geometry that does not
interfere with or limit operation of the completion equipment.
[0026] For example, the system enables the deployment of a lower
assembly in a wellbore and the subsequent engagement of an upper
assembly and one or more control lines. In one embodiment, the
system is capable of deploying and connecting a fixed fiber optic
sensor network in a two-stage completion. In this embodiment, once
the connection is established, a continuous optical path is
established from a surface location to the bottom of an open hole
formation and back to the surface location to complete an optical
loop. The connection also may be established for other control
lines, such as electrical control lines or fluid control lines in
various combinations. The control line connections may be
established, broken and reestablished repeatedly. This type of
system may be used for land applications, offshore platform
applications, or subsea deployments in a variety of environments
and with a variety of downhole components. By way of example, the
system may utilize fiber sensing systems and the deployment of
fiber optic sensors in sand control components, perforating
components, formation fracturing components, flow control
components, or other components used in various well operations
including well drilling operations, completion operations,
maintenance operations, and/or production operations. The system
also may be used to connect fiber-optic lines, electric lines
and/or fluid communication lines below an electric submersible pump
to control flow control valves or other devices while allowing the
electric submersible pump to be removed from the wellbore and
replaced.
[0027] In other embodiments, the system may comprise a well
operations system for installation in a well in two or more stages.
The well operations system may comprise a lower assembly, an upper
assembly, and a connector for connecting a control line in the
upper assembly to a corresponding control line in the lower
assembly. This type of connection system and methodology can be
used to connect a variety of downhole control lines, including
communication lines, power lines, electrical lines, fiber optic
lines, hydraulic conduits, fluid communication lines, and other
control lines. Additionally, the upper and lower assemblies may
comprise a variety of components and assemblies for multistage well
operations, including completion assemblies, drilling assemblies,
well testing assemblies, well intervention assemblies, production
assemblies and other assemblies used in various well operations.
The upper and lower assemblies also may comprise a variety of
components depending on the application, including tubing, casing,
liner hangers, formation isolation valves, safety valves, other
well flow/control valves, perforating and other formation
fracturing tools, well sealing elements, e.g. packers, polish bore
receptacles, sand control components, e.g. sand screens and gravel
packing tools, artificial lift mechanisms, e.g. electric
submersible pumps or other pumps/gas lift valves and related
accessories, drilling tools, bottom hole assemblies, diverter
tools, running tools and other downhole components.
[0028] It also should be noted that within this description, the
term "lower" also can refer to the first or lead equipment/assembly
moved downhole. Furthermore, the term "upper" can refer to the
second or later equipment/assembly moved downhole into engagement
with the lower unit. In a horizontal wellbore, for example, the
lower equipment/assembly is run downhole first prior to the upper
equipment/assembly.
[0029] Referring generally to FIG. 1, a portion of a wellbore 20 is
illustrated between a wellbore wall 22 and a wellbore centerline
24. A completion 26 is illustrated in cross-sectional profile as
having a first or lower completion stage 28 and a second or upper
completion stage 30. The lower completion stage generally is the
stage deployed first into either a vertical or deviated wellbore.
Also, the lower completion stage 28 and the upper completion stage
30 may comprise a variety of completion types depending on the
specific wellbore application for which the multiple stage
completion is designed. For example, the lower stage completion may
be designed with sand screens or screens with gravel pack
components. In FIG. 1, the lower completion stage 28 has been moved
to a desired downhole location with a service tool or with other
deployment or running equipment, as known to those of ordinary
skill in the art. Once lower completion stage 28 is positioned in
the wellbore and the deployment equipment is retrieved, the next
completion stage 30 can be moved downhole toward engagement with
the lower completion stage, as illustrated, to ultimately form a
connection.
[0030] The lower completion stage 28 comprises a housing 32 that
forms a receptacle 34 which is run into the wellbore and remains in
the wellbore with lower completion stage 28 when the service tool
is removed. Housing 32 comprises a lower body section 35 and a
shroud 36, e.g. a helical shroud or muleshoe, having an alignment
slot 38 and a flush port 40. Lower completion stage 28 also
comprises a passageway 42 through housing 32 for routing of a
communication line 44 to a communication line connector 46
integrated with the lower completion stage. Communication line 44
may comprise, for example, a fiber optic line, an electric line, an
auxiliary conduit or control line for transmitting hydraulic or
other fluids, or a tubing for receiving a fiber optic line.
Correspondingly, communication line connector 46 may comprise a
fiber optic connector, an electric line connector, a hydraulic
connector, or a tubing connector through which a fiber optic line
is deployed. By way of specific example, communication line
connector 46 comprises a fiber optic ferrule receptacle;
communication line 44 comprises an optical fiber disposed within a
flexible protected tube; and passageway 42 comprises an optical
fluid chamber. The optical fluid chamber can be compensated to
equal or near hydrostatic pressure in the wellbore, or the chamber
can be at atmospheric pressure or another pressure.
[0031] In this embodiment, the lower completion stage 28 further
comprises a displaceable member 48 movably disposed along a surface
of receptacle 34 to enclose communication line connector 46.
Enclosing communication line connector 46 protects the connector
from wellbore debris and other contaminants prior to completing
engagement of upper completion stage 30 with the lower completion
stage. In the embodiment illustrated, displaceable member 48 is a
sleeve, such as a spring loaded sleeve biased toward a position
enclosing communication line connector 46. Displaceable member,
e.g. sleeve, 48 may be sealed to housing 32 via at least one lower
seal 50 and at least one upper seal 52. As illustrated, sleeve 48
also may comprise one or more debris exclusion slots 54.
[0032] The upper completion stage 30 comprises an upper completion
housing 56 that forms a stinger 58 designed for insertion into and
engagement with receptacle 34. Housing 56 may comprise an inner
tubing 60, a surrounding upper body portion 62, and an alignment
key 64. The inner tubing 60 has any interior 66 for conducting
fluid flow and one or more radial flush ports 68 through which a
flushing fluid can be conducted from interior 66 to the exterior of
stinger 58. The surrounding upper body portion 62 may comprise a
passageway 70 for routing of a communication line 72 to a
communication line connector 74 integrated with the upper
completion stage. As with lower completion stage 28, the
communication line may comprise, for example, a fiber optic line,
an electric line, an auxiliary conduit or control line for
transmitting hydraulic or other fluids, or a tubing for receiving a
fiber optic line. Correspondingly, communication line connector 74
may comprise a fiber optic connector, an electric line connector, a
hydraulic connector, or a tubing connector through which a fiber
optic line is deployed. By way of specific example, communication
line connector 74 comprises a fiber optic ferrule plug or
receptacle; communication line 72 comprises an optical fiber
disposed within a flexible, protected tube that is extensible; and
passageway 70 comprises an optical fluid chamber. The optical fluid
chamber can be compensated to equal or near hydrostatic pressure in
the wellbore, or the chamber can be at atmospheric pressure or
another pressure.
[0033] The upper completion stage 30 further comprises an upper
completion displaceable member 76 movably disposed along an outer
surface of housing 56 to enclose communication line connector 74.
Enclosing communication line connector 74 protects the connector
from wellbore debris and other contaminants prior to completing
engagement of upper completion stage 30 with the lower completion
stage 28. Similar to displaceable member 48, upper completion
displaceable member 76 may be formed as a movable sleeve, such as a
spring loaded sleeve biased toward a position enclosing
communication line connector 74. Displaceable member, e.g. sleeve,
76 may be sealed to housing 56 via at least one lower seal 78 and
at least one upper seal 80. As illustrated, sleeve 76 also may
comprise one or more debris exclusion slots 82.
[0034] As stinger 58 is moved into receptacle 34, alignment key 64
engages alignment slot 38, as illustrated best in FIG. 2. As the
stinger continues to move into receptacle 34, alignment key 64 and
alignment slot 38 cooperate to orient the upper completion stage 30
with respect to the lower completion stage 28 such that the lower
communication line connector 46 and upper communication line
connector 74 are properly aligned when the upper and lower
completion stages are fully landed, i.e. engaged.
[0035] While the upper completion stage 30 is lowered into the
wellbore and into engagement with lower completion stage 28, a
flushing fluid is circulated continuously from the interior 66 of
tubing 60 through a bottom opening 84 of tubing 60 and through
radial flush ports 68. From radial flush ports 68, the fluid can
circulate outwardly through flush ports 40 of lower completion
stage 28 along a flushing flow path 86, as best illustrated in FIG.
3. The fluid velocity and flushing effectiveness increases as the
gap narrows between upper completion stage 30 and lower completion
stage 28. The completion may be designed such that seals on the
upper completion stage 30 engage the lower completion stage 28 in a
manner that blocks further flow through bottom opening 84. This
forces all of the flushing fluid flow through radial flush ports 68
and 40 to further increase the flushing effectiveness in the
vicinity of communication line connectors 46 and 74.
[0036] As the upper completion stage 30 is continually lowered, the
upper sleeve 76 contacts the lower sleeve 48, as illustrated best
in FIG. 4. The contact between sleeve 76 and sleeve 48 blocks
further flow of flushing fluid from port 68 to port 40. The upper
completion stage 30 is then allowed to move further into lower
completion stage 28. This movement causes the upper sleeve 76 to
retract and seals 78 to engage and move along the lower sleeve 48
until the upper body portion 62 reaches a mechanical stop 88, as
illustrated best in FIG. 5.
[0037] Further movement of the upper completion stage 30 causes the
lower sleeve 48 to retract, as illustrated best in FIG. 6. It
should be noted that in the embodiment illustrated, displaceable
members 48 and 76 are being described as spring biased sleeves that
are biased in a direction toward enclosing the communication line
connector ends in a sealed environment. The retraction of lower
sleeve 48 enables the upper sleeve 76 to continually move downward,
creating a seal against lower body 35 in receptacle 34, until a
mechanical stop 90 is reached. At this point, the upper completion
stage 30 has become sealingly engaged with the lower completion
stage 28.
[0038] The mechanical stops 88 and 90 determine the relative
locations between upper body portion 62 and lower sleeve 48 and
between upper sleeve 76 and lower body portion 35. Those relative
locations remain fixed throughout the remainder of the
landing/engagement sequence. Relative spring rates on spring biased
sleeves 48, 76 can be used to control the opening sequence by
determining which of the two sleeves retracts first.
[0039] As the insertion of upper completion stage 30 into lower
completion stage 28 continues, lower sleeve 48 and upper sleeve 76
continue to retract, as illustrated best in FIG. 7. The continued
retraction of the lower and upper sleeve creates a communication
line connection chamber 92 that is sealed between upper body
portion 62, lower body portion 35, upper sleeve 76 and lower sleeve
48. Continued insertion of upper completion stage 30 into lower
completion stage 28 expands the size of chamber 92 until
communication line connectors 46 and 74 are exposed to
communication line connector chamber 92, as illustrated best in
FIG. 8.
[0040] One or both of the communication line connectors can be
moved into chamber 92 for coupling with the other connector. In the
embodiment illustrated, however, communication line connector 74 is
moved into and through chamber 92. In this embodiment, upper body
portion 62 is formed as a telescoping body having a first component
96 and a second component 98 that can be moved together to force
communication line 72 through passageway 70 of first component 96.
The movement of communication line 72 pushes communication line
connector 74 into chamber 92, as illustrated best in FIG. 9.
Ultimately, the telescoping movement of upper body portion 62
pushes connector 74 into full engagement with connector 46, e.g.
into full engagement of a ferrule plug with a ferrule receptacle.
The coupling of connectors is accomplished without exposing either
of the communication line connectors to detrimental debris or
contaminants from the surrounding environment. Also, a telescoping
spring (not shown) can be used to hold telescoping body 62 in an
open position to ensure that sleeves 48 and 76 are retracted and
chamber 92 is fully opened before the telescoping process begins.
Relative spring rates between the telescoping spring and the spring
biased sleeves can be used to control this mating sequence.
[0041] Telescoping body 62 can be designed in a variety of
configurations. For example, the telescoping body 62 can be
attached to upper completion stage 30 such that allowing the upper
completion stage to move further downhole automatically compresses
a telescoping spring and cause movement of second component 98
toward first component 96. In another configuration, a piston
chamber can be ported to the interior of tubing 60 on one side and
to annulus pressure on the other side. A piston within the piston
chamber can be used to compress a telescoping spring by increasing
tubing pressure above annulus pressure. In another configuration,
the piston chamber can be ported to a control line extending to the
surface instead of to the interior of tubing 60. Pressure within
the control line can be increased above annulus pressure to
compress the telescoping spring. Alternatively, both sides of the
piston chamber can be ported to control lines run to a surface
location. Increasing control line pressure in one control line and
taking returns with the other control line can be used to again
compress the telescoping spring and move second component 98 toward
first component 96. These and other configurations can be used to
move one or both of the control line connectors into and through
chamber 92 in forming a control line coupling.
[0042] The geometry of lower completion stage 28 and upper
completion stage 30 enables efficient and thorough flushing and
cleaning of the area around and between the communication line
connection components prior to initiating the mating of the two
completion stages. Additionally, the communication line connectors
and communication lines are fully sealed from wellbore fluids
during running of the lower completion stage and the upper
completion stage in hole, during the mating sequence, and after the
wet-mate connection has been established. The seals used, e.g.
seals 52 and 78, can be high-pressure seals that are durable in
downhole applications. The sleeve members 48 and 76 and other
members forming chamber 92 can be correspondingly sized to
withstand high pressures, e.g. the maximum hydrostatic pressure
plus injection pressure expected in the wellbore, while the sealed
chamber remains at atmospheric pressure.
[0043] Referring generally to FIG. 11, an alternate embodiment of
the connection assembly is illustrated. The cross-sectional view of
FIG. 11 is taken at to different levels to show a plurality of
integrated lower stage communication lines 44, e.g. control lines,
coupled with a plurality of upper completion stage communication
lines 72, e.g. control lines. This approach accommodates multiple
communication channels along the completion. In the embodiment
illustrated, the plurality of communication channels formed by
corresponding communication lines 44, 72 are spaced
circumferentially around completion 26, although the communication
channels can be located or spaced differently depending on the
application.
[0044] Referring generally to FIGS. 12-14, additional alternate
embodiments of the connection assembly are illustrated. In these
embodiments, the communication line connectors also are integrated
into the completion stages and thereby protected from debris and
other contaminants to improve the connections formed. The
connections may be formed by bringing the appropriate components,
e.g. ferrules, contacts or ports, into alignment with each other
axially and radially. The connection does not require lateral
travel of the ferrules or other components. To form such a
connection, each of the communication lines, e.g. hydraulic ports,
is sealed individually and isolated from each other in addition to
the circumferential sleeve seals used to isolate ports from the
wellbore.
[0045] In FIG. 12, one alternate configuration is illustrated that
is suitable for hydraulic connections but can also be used for
optical or electrical connections. In this embodiment, a plurality
of communication lines 44, e.g. hydraulic ports, is provided and
the ports are disposed sequentially in an axial direction along
lower completion stage 28. The communication lines 44 are
integrated with the lower completion stage and are coupled with
communication line connectors 46. Similarly, a plurality of
communication lines 72, e.g. hydraulic ports, is provided and the
ports are located sequentially in an axial direction along upper
completion stage 30. The communication lines 72 are integrated with
the upper completion stage and comprise communication line
connectors 74 that engage connectors 46. The sequential ports are
hydraulically isolated by circumferential sleeve seals 102.
Generally, the communication lines/ports are not located in the
same axial plane but are spaced from each other. Once the
connection is made and each set of integrated ports is aligned,
optical fiber can be pumped through the connection system in
applications utilizing optical fibers. Additionally, this
embodiment as well as other illustrated embodiments can utilize a
combination alignment system in which key 64 and alignment groove
38 provide for coarse alignment. However, a separate fine alignment
key 104 and corresponding fine alignment slot 106 can be used to
provide fine alignment of the lower and upper completion
stages.
[0046] Another alternate embodiment is illustrated in FIG. 13. In
this embodiment, the connection system has integrated control line
connectors 46/74 that do not require rotational alignment. The
communication line connections are accomplished by features that
extend around the circumference of stinger 58 and receptacle 34.
For example, the communication lines 72 are coupled to
circumferential features 108 that engage with corresponding
circumferential features 110 coupled to communication lines 44.
Because the features are circumferential, the rotational position
of the upper completion stage can vary relative to the lower
completion stage. To form a hydraulic connection, for example,
circumferential features 108 and corresponding circumferential
features 110 may be formed as grooves on the outside of the stinger
body and the inside of the receptacle body, respectively, to create
flow paths for fluids. To form other types of connections, such as
electrical connections, the circumferential features can comprise
conductors or other suitable elements extending circumferentially
to enable the communication of appropriate signals.
[0047] In another embodiment, the connection assembly comprises a
compensation system 112, as illustrated in FIG. 14. Compensation
system 112 can be used to prevent wellbore fluids from being
transmitted to the internal components and connectors in the
overall system while still allowing the internal components and
connectors to be referenced to hydrostatic pressure. This approach
reduces the pressure differential to which the seals are subjected
without exposing the components and connectors to debris or other
corrosive or harmful effects of the wellbore fluids. The
compensation system comprises a compensator piston 114 that is
sealed within and moves within a chamber 116, e.g. a bore. On one
side of compensator piston 114, chamber 116 contains uncontaminated
fluid 118 in fluid communication with, for example, fluid
communication lines 72. On the other side of piston 114, chamber
116 is referenced to the surrounding wellbore by an external port
118 that extends either to the annulus or the tubing. Optionally, a
spring 120 can be used on either side of compensator piston 114 to
keep fluid 118 at a pressure significantly or slightly above or
below the hydrostatic pressure in the wellbore. The compensator
piston 114 moves back and forth in chamber 116 to accommodate
changes in wellbore pressure as well as the expansion and
compression of internal fluids due to temperature changes. A relief
valve 122 also can be utilized to limit the maximum pressure
differential. In the embodiment illustrated, a single compensation
system 112 is located in a running tool and connected to a
plurality of hydraulic ports or passageways to equalize pressure
acting on the communication lines in receptacle 34 and the lower
completion assembly during installation. Alternatively, separate
compensation systems 112 can be connected to individual
communication line passageways. Additional flexibility can be added
by providing single or multiple lines connected from the running
tool to the surface to allow pressure inside the lines/passageways
to be actively controlled either collectively or individually from
a surface location during installation of receptacle 34. The
compensation system can be combined with the various connector
assembly embodiments described herein.
[0048] The various multiple stage connection assemblies described
herein can be used with many types of completion systems depending
on the specific wellbore application for which a given completion
system is designed. In FIG. 15, one example of a completion system
124 utilizing a multiple stage connection assembly 126 is
illustrated. It should be noted that the multiple stage connection
assembly 126 is representative of the several embodiments described
above. Additionally, the completion system 124 is representative of
a variety of completion systems, and the components and arrangement
of components can vary substantially from one well application to
another.
[0049] In the embodiment illustrated, completion system 124
comprises a wellbore assembly 128 deployed in a wellbore 130
extending downwardly from a wellhead 132. By way of example,
wellbore assembly 128 may comprise an upper completion assembly or
stage, e.g. stage 30, having a ported production packer 130 and a
contraction joint 132. A communication line, e.g. communication
line 72, in the form of a cable, conduit or other suitable
communication line extends downwardly to the multiple stage
connection assembly. The wellbore assembly 128 also comprises a
lower completion assembly or stage, e.g. stage 28, having a variety
of components. In one example, the lower completion assembly
comprises a gravel pack packer 134, a gravel pack circulation
housing 136, a formation isolation valve 138, one or more gravel
pack screens 140, and a turnaround loop 142. Additionally, a
communication line, e.g. communication line 44, may be in the form
of a cable, conduit or other suitable communication line that
extends below the multiple stage connection assembly 126.
[0050] It should be noted that multiple stage connection assembly
126 can be utilized in many other locations within completion
system 124 and with other types of completion systems. For example,
the multiple stage connection assembly can be placed above or below
gravel pack packer 134. Additionally, the multiple stage connection
assembly 126 can be used for connecting many types of communication
lines, including fluid lines, electrical lines, optical lines and
other types of communication lines. Furthermore, the multiple stage
connection assembly can be used to form communication line
connections utilized in controlling the operation of flow control
components incorporated into completion system 124 or located
within wellbore 130 at locations separate from the completion
system.
[0051] In general, the multiple stage completions have been
described in terms of connecting previously installed electric,
fiber optic, fluid, or other communication lines. These
communication lines or cables can be used for variety of purposes
including communication of data. The lines themselves also can be
used as sensors or for other purposes. The communication line
connectors can be designed for connecting a blank control line in
the lower completion stage with a blank control line in the upper
completion stage. This control line can then be used to control
valves or other devices located in the lower completion. It can
also be used to transmit fluids for release into the lower
completion in chemical injection or scale inhibitor applications.
An optical fiber or other communication line can then be pumped
through the coupled blank control line to form a continuous
communication line through the multiple stage completion. In other
applications, the mating sequence may be adjusted to form the
communication line coupling prior to completing the landing of the
upper completion stage in the lower completion stage. Other
adjustments also can be made to the mating sequence depending on
the specific well application. Furthermore, a variety of additional
or alternate components can be incorporated into the lower
completion stage and/or the upper completion stage to accommodate
various well procedures.
[0052] Accordingly, although only a few embodiments of the present
invention have been described in detail above, those of ordinary
skill in the art will readily appreciate that many modifications
are possible without materially departing from the teachings of
this invention. Accordingly, such modifications are intended to be
included within the scope of this invention as defined in the
claims.
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