U.S. patent application number 09/184844 was filed with the patent office on 2001-08-16 for apparatus and method for hydraulically actuating a downhole from a remote location.
Invention is credited to GRIGSBY, TOMMY F., MULLEN, BRYON D..
Application Number | 20010013415 09/184844 |
Document ID | / |
Family ID | 22678594 |
Filed Date | 2001-08-16 |
United States Patent
Application |
20010013415 |
Kind Code |
A1 |
MULLEN, BRYON D. ; et
al. |
August 16, 2001 |
APPARATUS AND METHOD FOR HYDRAULICALLY ACTUATING A DOWNHOLE FROM A
REMOTE LOCATION
Abstract
An apparatus (100) for actuating a hydraulically controllable
device (102) disposed in a wellbore is disclosed. The apparatus
(100) comprises a downhole hydraulic fluid source (134), a
hydraulic fluid passageway (136) providing a communication path
between the downhole hydraulic fluid source (134) and the
hydraulically controllable device (102), a valve (144) disposed
within the hydraulic fluid passageway (136) and a downhole
electronics package (138). The downhole electronics package (138)
receives a signal from the surface to operate the valve (144) from
the closed position to the open position such that hydraulic
pressure from the downhole hydraulic fluid source (134) actuates
the hydraulically controllable device (102).
Inventors: |
MULLEN, BRYON D.;
(CARROLLTON, TX) ; GRIGSBY, TOMMY F.; (HOUMA,
LA) |
Correspondence
Address: |
LAWRENCE R. YOUST
SMITH & DANAMRAJ, P.C.
12900 PRESTON ROAD
SUITE 1200, LB-15
DALLAS
TX
75230-1328
US
|
Family ID: |
22678594 |
Appl. No.: |
09/184844 |
Filed: |
November 2, 1998 |
Current U.S.
Class: |
166/374 ;
166/120; 166/128; 166/386; 166/66.6 |
Current CPC
Class: |
E21B 23/06 20130101;
E21B 33/1295 20130101; E21B 33/1285 20130101 |
Class at
Publication: |
166/374 ;
166/66.6; 166/120; 166/128; 166/386 |
International
Class: |
E21B 023/00 |
Claims
What is claimed is:
1. A method for actuating a downhole device comprising the steps
of: sending a signal to a downhole electronics package;
transmitting hydraulic pressure from a downhole hydraulic source to
the downhole device in response to the signal; and actuating the
downhole device in response to the hydraulic pressure.
2. The method as recited in claim 1 wherein the step of
transmitting hydraulic pressure further comprises the step of
operating a valve from the closed position to an open position.
3. The method as recited in claim 1 wherein the step of sending a
signal to a downhole electronics package further comprises sending
a signal from a surface installation.
4. The method as recited in claim 1 wherein the step of sending a
signal to a downhole electronics package further comprises sending
an acoustic signal.
5. The method as recited in claim 1 wherein the step of sending a
signal to a downhole electronics package further comprises sending
a pressure pulse signal.
6. The method as recited in claim 1 wherein the step of sending a
signal to a downhole electronics package further comprises sending
an electromagnetic signal.
7. The method as recited in claim 1 wherein the step of
transmitting hydraulic pressure from a downhole hydraulic source to
the downhole device further comprises utilizing hydrostatic
pressure to transmit the hydraulic pressure from the downhole
hydraulic source to the downhole device.
8. The method as recited in claim 1 wherein the step of actuating
the downhole device further comprises setting a downhole
device.
9. The method as recited in claim 8 wherein the downhole device is
a packer assembly.
10. The method as recited in claim 1 wherein the step of actuating
the downhole device further comprises manipulating a downhole
device.
11. The method as recited in claim 1 wherein the step of actuating
the downhole device further comprises axially shifting a component
of the downhole device.
12. The method as recited in claim 1 wherein the step of actuating
the downhole device further comprises rotatably operating a
component of the downhole device.
13. A method for hydraulically actuating a downhole device from a
remote location comprising the steps of: sending a signal from a
surface installation to a downhole electronics package;
establishing a communication path between a downhole hydraulic
source and the downhole device in response to the signal; and
transmitting hydraulic pressure from the downhole hydraulic source
to the downhole device, thereby hydraulically actuating the
downhole device.
14. The method as recited in claim 13 wherein the step of sending a
signal from a surface installation to a downhole electronics
package further comprises sending an acoustic signal.
15. The method as recited in claim 13 wherein the step of sending a
signal from a surface installation to a downhole electronics
package further comprises sending a pressure pulse signal.
16. The method as recited in claim 13 wherein the step of sending a
signal from a surface installation to a downhole electronics
package further comprises sending an electromagnetic signal.
17. The method as recited in claim 13 wherein the step of
establishing a communication path between a downhole hydraulic
source and the downhole device further comprises operating a valve
from a closed position to an open position.
18. The method as recited in claim 13 wherein the step of
transmitting hydraulic pressure from a downhole hydraulic source to
the downhole device further comprises utilizing hydrostatic
pressure to transmit the hydraulic pressure from the downhole
hydraulic source to the downhole device.
19. The method as recited in claim 13 wherein the step of actuating
the downhole device further comprises setting a downhole
device.
20. The method as recited in claim 19 wherein the downhole device
is a packer assembly.
21. The method as recited in claim 13 wherein the step of actuating
the downhole device further comprises axially shifting a component
of the downhole device.
22. The method as recited in claim 13 wherein the step of actuating
the downhole device further comprises rotatably operating a
component of the downhole device.
23. An apparatus for actuating a hydraulically controllable device
disposed in a wellbore comprising: a downhole hydraulic fluid
source; a hydraulic fluid passageway providing a communication path
between the downhole hydraulic fluid source and the hydraulically
controllable device; a valve disposed within the hydraulic fluid
passageway; and a downhole electronics package receiving a signal
from the surface to operate the valve from the closed position to
the open position, thereby transmitting hydraulic pressure from the
downhole hydraulic fluid source to the hydraulically controllable
device and actuating the hydraulically controllable device.
24. The apparatus as recited in claim 23 wherein the hydraulic
fluid source further comprises a housing and a sleeve slidably
disposed about the housing, the sleeve and the housing defining a
hydraulic fluid chamber therebetween having hydraulic fluid
contained therein, the sleeve operating from a first position to a
second position relative to the housing in response to hydrostatic
pressure once the valve is operated from the closed position to the
open position.
25. The apparatus as recited in claim 24 wherein the sleeve and the
housing further define an air chamber therebetween having air
contained therein.
26. The apparatus as recited in claim 23 wherein the downhole
electronics package further comprises an acoustic transducer.
27. The apparatus as recited in claim 23 wherein the downhole
electronics package further comprises a pressure pulse
transducer.
28. The apparatus as recited in claim 23 wherein the downhole
electronics package further comprises an electromagnetic
transducer.
29. The apparatus as recited in claim 23 wherein the downhole
electronics package further comprises a battery pack.
30. The apparatus as recited in claim 23 wherein the hydraulically
controllable device is a packer assembly.
31. A well service apparatus comprising, in combination: a downhole
hydraulic fluid source; a hydraulically controllable device
operably associated with the downhole hydraulic fluid source; a
hydraulic fluid passageway providing a communication path between
the downhole hydraulic fluid source and the hydraulically
controllable device; a valve disposed within the hydraulic fluid
passageway, the valve having open and closed positions; and a
downhole electronics package receiving a signal from the surface to
operate the valve from the closed position to the open position to
allow hydraulic pressure to transfer from the downhole hydraulic
fluid source to the hydraulically controllable device, thereby
actuating the hydraulically controllable device.
32. The apparatus as recited in claim 31 wherein the hydraulic
fluid source further comprises a housing and a sleeve slidably
disposed about the housing and defining a hydraulic fluid chamber
therebetween, the sleeve operating from a first position to a
second position relative to the housing in response to hydrostatic
pressure once the valve is operated from the closed position to the
open position.
33. The apparatus as recited in claim 32 wherein the sleeve and the
housing further define an air chamber therebetween having air
contained therein.
34. The apparatus as recited in claim 31 wherein the downhole
electronics package further comprises an acoustic transducer.
35. The apparatus as recited in claim 31 wherein the downhole
electronics package further comprises a pressure pulse
transducer.
36. The apparatus as recited in claim 31 wherein the downhole
electronics package further comprises an electromagnetic
transducer.
37. The apparatus as recited in claim 31 wherein the downhole
electronics package further comprises a battery pack.
38. The apparatus as recited in claim 31 wherein the hydraulically
controllable device is a packer assembly.
Description
TECHNICAL FIELD OF THE INVENTION
[0001] This invention relates general to the field of actuating
hydraulically controllable downhole tools and, in particular to, a
remotely operated service tool having a self-contained hydraulic
system for actuating hydraulically controllable downhole tools
disposed within a wellbore.
BACKGROUND OF THE INVENTION
[0002] Without limiting the scope of the invention, its background
is described in connection with setting a packer assembly in a
wellbore that traverses a hydrocarbon formation, as an example.
[0003] Heretofore in this field, during the treatment and
preparation of the wellbore for production, a packer assembly and
sand control screen along with a service tool are run into the
wellbore on a work string. The setting of the packer assembly
against the casing is typically accomplished by manipulating the
service tool. The success of such operations is dependent upon the
ability to reciprocate the service tool vertically or to rotate it
relative to the packer assembly. It has been found, however, that
rotational displacement of the service tool in deviated wells is
difficult to perform reliably because of frictional binding between
the work string and the casing. Accordingly, vertical reciprocal
movements have been preferred for setting and releasing packer
assemblies in such instances.
[0004] During run-in, the packer assembly is mechanically locked in
the unset condition by shear pins and anti-preset lugs that support
the weight of the packer assembly along with the hang weight of
other components such as a swivel shear sub, blank pipe, a sand
control screen, a polished nipple, a tail screen, and a packer
assembly. The shear pins and anti-preset lugs can safely support
the combined weight of the downhole equipment. The shear pins are
rated to yield to a preset shearing force to separate and release
the service tool after the packer assembly has been set. It has
been found, however, that in deviated or otherwise obstructed
wellbores, shear pins designed to shear in response to vertical
reciprocation may be damaged and the packer assembly may sometimes
be inadvertently preset in response to frictional loading between
the packer assembly and the wellbore in tight spots.
[0005] It has also been found that when operating in slanted or
deviated wellbores, it is sometimes difficult to transmit
sufficient force downhole from the surface to set mechanically
actuated packer assemblies. The frictional engagement between the
wellbore and the work string interferes with the transmission of
the necessary mechanical force to set the packer assembly.
[0006] To overcome these difficulties, pressure may be applied to
the fluid column within the work string to transmit the required
packer assembly setting force. For example, the packer assembly may
be set by dropping a ball through the work string into the service
tool. Pressurized fluid is then pumped down the work string to
shear the shear pins, thereby setting the packer assembly. During
gravel packing or frac packing operations, it is desirable to
remove the ball from the service tool. It has been found, however,
that in slanted or deviated wellbores or in tapered work strings it
is difficult to reverse the ball out of the work string. In
addition, it has been found that the ball, in certain installation,
may damage downhole equipment when it is run-in the service
tools.
[0007] Therefore a need has arisen for an improved service tool for
running and setting a packer assembly in a wellbore. A need has
also arisen for an improved service tool for setting a packer
assembly without the need for translational or rotational movement
of the service tool with respect to the packer assembly and without
the need for running a ball into the service tool. A need has
further arisen for such a service tool that can set a packer
assembly in a deviated or slanted wellbore.
SUMMARY OF THE INVENTION
[0008] The present invention disclosed herein comprises a service
tool for hydraulically actuating a downhole device from a remote
location. The service tool utilizes hydraulic pressure for
actuating the downhole device without the need for translational or
rotational movement of the service tool and without the need for
running a ball into the service tool. The service tool of the
present invention may be used in any wellbore including a deviated
or slanted wellbore.
[0009] The service tool of the present invention comprises a
downhole hydraulic fluid source, a hydraulic fluid passageway that
provides a communication path between the downhole hydraulic fluid
source and the hydraulically controllable device, a valve disposed
within the hydraulic fluid passageway and a downhole electronics
package. The downhole electronics package receives a signal from a
surface installation to operate the valve from the closed position
to the open position, thereby transmitting hydraulic pressure from
the downhole hydraulic fluid source to the hydraulically
controllable device and actuating the hydraulically controllable
device.
[0010] The hydraulic fluid source includes a housing and a sleeve
that define a hydraulic fluid chamber therebetween having hydraulic
fluid contained therein. The sleeve is slidably disposed about the
housing and has first and second positions relative to the housing.
The sleeve is operated from the first position to the second
position, responsive to hydrostatic pressure, once the valve is
operated from the closed position to the open position. The sleeve
and the housing also define an atmospheric air chamber therebetween
having air contained therein.
[0011] The downhole electronics package includes a transducer that
receives the signal from a surface installation. The transducer may
be selected from a variety of transducers that are suitable for
downhole reception of a signal including, but not limited to, an
acoustic transducer, a pressure pulse transducer, an
electromagnetic transducer and the like. The transducer receives
the signal and relays the signal to the controller of the valve.
The downhole electronics package also includes a battery pack to
provide a source of electrical power.
[0012] The method for actuating a downhole device of the present
invention involves sending a signal to a downhole electronics
package, transmitting hydraulic pressure from a downhole hydraulic
source to the downhole device in response to the signal and
actuating the downhole device in response to the hydraulic
pressure. The method may also include operating a valve to
establish a communication path between the downhole hydraulic
source and the downhole device and utilizing hydrostatic pressure
to transmit the hydraulic fluid from the downhole hydraulic source
to the downhole device.
[0013] In the method of the present invention, the signal may be
sent to a downhole electronics package from a surface installation.
The signal may be an acoustic signal, a pressure pulse signal, an
electromagnetic signal or other suitable signal the may be received
downhole.
[0014] The actuation of the downhole device may further include the
setting a downhole device such as a packer assembly, or the
manipulating a downhole device such as a sliding sleeve, a fluid
control device or a well control device. Additionally, the
actuation of the downhole device may be achieved by axially
shifting a component of the downhole device or rotatably operating
a component of the downhole device.
BRIEF DESCRIPTION OF THE DRAWINGS
[0015] For a more complete understanding of the features and
advantages of the present invention, references now made to the
detailed description of the invention along with the accompanying
figures in which corresponding numerals in the different figures
refer to corresponding parts and in which:
[0016] FIG. 1 is a schematic illustration of an offshore oil and
gas platform operating a service tool of the present invention;
[0017] FIGS. 2A-2F are quarter-section views of a service tool of
the present invention in the run-in position that is attached to a
packer assembly in the unset position; and
[0018] FIGS. 3A-3F are quarter-section views of a service tool of
the present invention after operation of the service tool and
actuation of a packer assembly to the set position.
DETAILED DESCRIPTION OF THE INVENTION
[0019] While the making and using of various embodiments of the
present invention is discussed in detail below, it should be
appreciated that the present invention provides many applicable
inventive concepts which can be embodied in a wide variety of
specific contexts. The specific embodiments discussed herein are
merely illustrative of specific ways to make and use the invention,
and do not delimit the scope of the invention.
[0020] Referring to FIG. 1, a service tool operably coupled to a
packer assembly in use with an offshore oil and gas platform is
schematically illustrated and generally designated 10. A
semi-submersible platform 12 is centered over a submerged oil and
gas formation 14 located below sea floor 16. A well 18 extends
through the sea 20 penetrating sea floor 16 to form wellbore 22
which traverses various earth strata.
[0021] Platform 12 has hoisting apparatus 24 and a derrick 26 for
raising and lowering pipe strings such as work string 28. Attached
to the lower end of work string 28 is service tool 30 that is
landed within the bore of packer assembly 32. As will be explained
in greater detail below, packer assembly 32 has mechanically
actuated slips which set expandable annular seal elements 34
against the inside bore of tubular well casing 36. Packer assembly
32 is actuated by hydraulic fluid from service tool 30. Service
tool 30 is remotely operated by a signal generated at surface
installation 38. After setting packer assembly 32, service tool 30
remains sealed against the inner bore of packer assembly 32 to, for
example, allow a gravel laden slurry to be pumped through the work
string 28 and the service tool 30 into annulus 40 between the
casing 36 and a sand control screen 42. A seal is provided above
and below formation 14 by expanded annular seal elements 34 carried
on packer assembly 32 and expanded annular seal elements 44 carried
on packer assembly 46. During the gravel pack operation, the
annulus 40 is filled with slurry, and the slurry is pumped through
perforations 48 formed in the sidewall of the well casing 36 into
the surrounding formation 14.
[0022] Even though FIG. 1 depicts a cased vertical well, it should
be noted by one skilled in the art that the service tool of the
present invention is equally well-suited for operation in uncased
wells, deviated wells, inclined wells or horizontal wells.
[0023] Referring now to FIGS. 2A-2F, the service tool 100 of the
present invention is rigidly locked onto packer assembly 102 during
the initial run-in operation. According to this arrangement, the
service tool 100, packer assembly 102 and all the equipment which
is hung off of packer assembly 102 are run-in through the bore of
casing 36 as an assembled unit. As best seen in FIG. 2E, a group of
separation shear pins 104 having appropriate shear strength for
supporting the packer assembly hang weight connect the packer
assembly mandrel 106 to the service tool mandrel 108. The shear
pins 104 are rated to safely support the combined weight of the
downhole equipment, and are rated to yield to a preset shearing
force to separate and release the service tool 100 from the packer
assembly 102 after setting packer assembly 102.
[0024] Referring specifically to FIG. 2A, service tool 100 includes
a hydraulic power unit 110. Hydraulic power unit 110 has an inner
mandrel 112. Disposed about inner mandrel 112 is an air chamber
piston 114 and an air chamber sleeve 116. Disposed between air
chamber sleeve 116 and inner mandrel 112 is air chamber 118. Also
disposed about inner mandrel 112 is a retainer member 120. Between
retainer member 120 and air chamber piston 114 is an annular
housing extension 122 having a port 124 therein. Air chamber sleeve
116 includes a port 125. Disposed about inner mandrel 112 is a
retainer member 126. Atmospheric air may be contained within air
chamber 118.
[0025] Below air chamber 118 and disposed about inner mandrel 112
is a hydraulic piston 128, a hydraulic sleeve 130 and a retainer
member 132. Disposed between hydraulic sleeve 130 and inner mandrel
112 is a hydraulic fluid chamber 134 that contains hydraulic fluid.
Disposed between retainer member 132 and inner mandrel 112 is a
hydraulic fluid passageway 136.
[0026] Referring now to FIG. 2B, a control assembly 138 is disposed
about inner mandrel 112. Control assembly 138 includes a battery
pack 140 that provides electrical power to a transducer 142.
Transducer 142 receives signals from surface installation 38 of
FIG. 1 in the form of acoustic signals, electromagnetic signals,
pressure pulse signals or other suitable signals that may transmit
information from a remote location to transducer 142, such methods
being well-known to those skilled in the art. Disposed within
hydraulic fluid passageway 136 is a valve 144 that may be operated
responsive to signals received by transducer 142.
[0027] Referring now to FIGS. 2C-2D, at the lower end of inner
mandrel 112 is a connector member 146 that is threadably attached
to a connector member 148. Threadably and sealably connected to
connector member 148 is outer housing 150. Outer housing 150
includes the lower end of hydraulic fluid passageway 136. The upper
portion of service tool mandrel 108 extends into outer housing 150.
Outer housing 150 includes an outer housing extension 152. Disposed
between outer housing extension 152 and service tool mandrel 108 is
operating piston 154 which includes an operating piston extension
156. The relative movement of operating piston extension 156 and
service tool mandrel 108 is prevented by shear pins 184 as best
seen in FIG. 2E.
[0028] Below operating piston extension 156 is a transfer support
assembly 158 that includes a group of anti-preset lugs 160 carried
by a collet 162. Anti-preset lugs 160 are engaged against the lower
shoulder of annular flange 164 which is formed on a tube guide
extension 166. Setting sleeve extension 166 is aligned to receive
sleeve 168. The hang weight of packer assembly 102 is transmitted
through a setting sleeve 170 through the anti-preset lugs 160 and
collet 162 to service tool mandrel 108. As such, packer assembly
102 and the equipment attached thereto are supported by the work
string 28 through service tool mandrel 108, anti-preset lugs 160
and setting sleeve 170. This configuration results in a decoupling
of handling forces which arise during the run-in procedure with
respect to shear pins 104.
[0029] The service tool 100 is provided with a locking flange 172
which is engaged by a shoulder portion 174 of the collet 160.
Collet 160 is held in its position shown in FIG. 2E by its finger
portions 176 having their head portions 178 received in a detent
groove 180 formed in the service tool mandrel 108 above the upper
shoulder of the locking flange 172. The head portion 178 is engaged
and prevented from deflecting by a piston shoulder 182 which forms
a part of operating piston extension 156.
[0030] As best seen in FIGS. 2E-2F, connected to the lower end of
setting sleeve 170 is connector sub 186. Disposed between connector
sub 186 and packer assembly mandrel 106 is a slip ring assembly 188
that is used to retain the seal element 190 and casing slips 192 of
packer assembly 102 in the set position.
[0031] It should be apparent to those skilled in the art that the
use of directional terms such as above, below, upper, lower,
upward, downward, etc. are used in relation to the illustrative
embodiments as they are depicted in the figures, the upward
direction being towards the top of the corresponding figure and the
downward direction being toward the bottom of the corresponding
figure. It is to be understood that the downhole components
described herein, for example, service tool 100, may be operated in
vertical, horizontal, inverted or inclined orientations without
deviating from the principles of the present invention.
[0032] The operation of service tool 100 and packer assembly 102
will now be described with reference to FIGS. 3A-3F, wherein
service tool 100 and packer assembly 102 are shown following their
operation. Transducer 42 receives a signal from surface
installation 38 to initiate the actuation of a hydraulically
controllable device such as packer assembly 102. Transducer 142
converts the signal to an electrical signal that is used to open
valve 144, as best seen in FIG. 3B. Once valve 144 is open, the
hydrostatic pressure within annulus 40 downwardly biases air
chamber piston 114, air chamber sleeve 116, hydraulic piston 128
and hydraulic sleeve 130, as best seen in FIG. 3A. The hydraulic
fluid in hydraulic chamber 134 may now pass through hydraulic fluid
passageway 136 and valve 144. As best seen in FIG. 3D, the
hydraulic fluid downwardly biases operating piston 154 including
operating piston extension 156 and accumulates in hydraulic fluid
reservoir 194.
[0033] Operating piston 154 is guided for movement along the
external surface of the service tool mandrel 108 by outer housing
extension 152. Once the hydraulic pressure is increased to a level
great enough to cause shear pins 184 to shear, operating piston 154
is permitted to drive sleeve 168 downwardly against annular flange
164 of setting sleeve extension 166 as best seen in FIG. 3E. Collet
162 remains in place as operating piston 154 is driven downwardly
until shoulder 182 clears head portions 178, thereby permitting it
to deflect and also permitting transfer support assembly 158 to
move downwardly along the locking flange 172. Thereafter, the
spring loaded anti-preset lugs 160 retract radially inwardly. When
this occurs, the hang weight of packer assembly 102 is transferred
from anti-preset lugs 160 to shear pins 104.
[0034] Setting sleeve 170 is movable relative to packer assembly
mandrel 106. Setting sleeve 170 is moved downwardly relative to
packer assembly mandrel 106 in response to continued extension of
operating piston 154. As operating piston 154 nears the limit of
its extension along service tool mandrel 108, slips 192 are engaged
and set against the inside bore of the well casing 36 as best seen
in FIG. 3F.
[0035] Because the packer assembly mandrel 106 is anchored onto the
service tool mandrel 108 by separation shear pins 104, setting
sleeve 170 continues its downward movement relative to packer
assembly mandrel 106. Once the desired slip setting pressure has
been achieved and packer assembly 102 is securely anchored in
place, service tool 100 can then be released from the packer
assembly 102 by pulling the work string 28 upward. Additionally,
prior to pulling work string 28 and service tool 100 out of
wellbore 22 a formation conditioning or sand control operation may
be preformed such as a high rate water pack, a frac pack, a gravel
pack or the like.
[0036] According to the foregoing arrangement, service tool 100
attaches to packer assembly 102 in such a way that packer assembly
102 can be run, set and service tool 100 released from packer
assembly 102 without any kind of rotation of service tool 100. The
hang load is transferred from the separation shear pins 104 by the
anti-preset lugs 160. Accordingly, any weight hanging below packer
assembly 102 is not applied to separation shear pins 104 during the
run-in procedure. Anti-preset lugs 106 are locked in the supporting
position during transit by the set of shear pins 184 which lock
operating piston extension 156 to service tool mandrel 108.
Movement of operating piston 154 in response to the transfer of
hydraulic fluid from hydraulic fluid chamber 134 through hydraulic
fluid passageway 136 into hydraulic fluid reservoir 194 causes pins
184 to shear, such that collet 162, which holds anti-preset lugs
160 in place, becomes unsupported, thereby permitting collet 162 to
carry anti-preset lugs 160 to a new position which permits
anti-preset lugs 160 to retract, thereby transferring the hang
weight to separation shear pins 104.
[0037] Continued movement of operating piston 154 downwardly brings
sleeve 168 of service tool 100 to bear against setting sleeve
extension 166 of packer assembly 102, thereby moving the outer
parts of packer assembly 102 relative to packer assembly mandrel
106, and in doing so, expanding seal elements 190 and setting slips
192. After slips 192 have been securely set and annular seal
elements 190 have been expanded, separation pins 104 are sheared.
Movement of service tool 100 is then possible by straight up or
down movement of work string 28 at the surface.
[0038] As a result, the unique service tool 100 of the present
invention provides for remote actuation of a hydraulically
controllable device such as packer assembly 102. Remote actuation
is achieved utilizing surface installation 38 to generate a signal
that is received by transducer 136 of hydraulic power unit 110.
This allows for the highly reliable use of hydraulic fluid transfer
to operate the hydraulically controllable device without axial or
rotational reciprocation of service tool 100 and without the need
to drop a ball down through work string 22 or run a hydraulic line
from the surface.
[0039] Even though the service tool of the present invention has
been described with reference to operating packer assembly 102
using hydraulic power unit 110 to axially shift operating piston
154, among other components, it should be noted by one skilled in
the art that the service tool of the present invention is equally
well-suited for actuating other hydraulically controllable downhole
devices. For example, the service tool of the present invention may
be used to rotatably operate components in a downhole device in
order to achieve a desired result. Similarly, the service tool of
the present invention may be used to hydraulically initiate the
actuation of a valve from either the closed position to the open
position or the open position to the closed position, to
hydraulically initiate the shifting of a sliding sleeve or to
hydraulically initiate the actuation of similarly operated downhole
devices.
[0040] While this invention has been described with a reference to
illustrative embodiments, this description is not intended to be
construed in a limiting sense. Various modifications and
combinations of the illustrative embodiments as well as other
embodiments of the invention, will be apparent to persons skilled
in the art upon reference to the description. It is, therefore,
intended that the appended claims encompass any such modifications
or embodiments.
* * * * *