U.S. patent number 3,659,647 [Application Number 05/016,327] was granted by the patent office on 1972-05-02 for well packer.
Invention is credited to Joe R. Brown.
United States Patent |
3,659,647 |
Brown |
May 2, 1972 |
WELL PACKER
Abstract
A single piece, tubular mandrel extends centrally through a
closely surrounding composite outer body. The outer body includes
metal anchoring slips and resilient packers to respectively anchor
the outer body and supporting central mandrel to a surrounding well
pipe and to seal the annular space formed between the mandrel and
the surrounding well pipe. The outer body includes setting
components which are moved axially by hydraulic setting pressure
introduced through the mandrel into expandable chamber means formed
in the outer body. The setting components wedge under the anchoring
slips and axially foreshorten the packer, forcing the slips and
packer radially outwardly into engagement with the surrounding well
conduit. Reverse axial movement of the setting components is
prevented by a one-way acting friction lock which retains the
anchoring slips and packer in engagement with the well conduit even
after reduction of the hydraulic setting pressure. The anchoring
slips and packers are released from their set position by moving
the mandrel axially with respect to the expanded slips and packer
in the outer body. Undesired relative movement of the mandrel is
prevented by a pressure expanded, normally retracted mechanical
hold-down linkage extending between the mandrel and the set outer
body. In the absence of a pressure differential across the set
packer, the mechanical linkage returns to a normally retracted
position which provides no obstacle to relative movement between
the mandrel and outer body. In the preferred form of the invention,
the hold-down linkage includes a series of radially movable pistons
acting against a resilient snap ring to retain the snap ring in
engagement with a groove in the outer body. In a modified form, the
hold-down linkage is an outwardly biased annular ring having
internal grooves adapted to mate with external grooves formed on
the mandrel. The ring is moved toward the mandrel by axially
movable, tapered wedging means driven by hydraulic pressure.
Inventors: |
Brown; Joe R. (Houston,
TX) |
Family
ID: |
21776572 |
Appl.
No.: |
05/016,327 |
Filed: |
March 4, 1970 |
Current U.S.
Class: |
166/120;
166/134 |
Current CPC
Class: |
E21B
33/128 (20130101); E21B 33/1295 (20130101) |
Current International
Class: |
E21B
33/1295 (20060101); E21B 33/12 (20060101); E21B
33/128 (20060101); E21b 023/06 (); E21b
033/129 () |
Field of
Search: |
;166/120,134,130 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Claims
I claim:
1. A well tool adapted to be set in a surrounding well conduit
comprising:
a. anchoring means for selectively engaging said well conduit to
anchor said tool to said conduit;
b. sealing means included with said tool for selectively engaging
said well conduit to form a seal between said tool and said conduit
whereby the area in said well conduit at the first end of said
sealing means is sealed away from the area in said well conduit at
the second end of said sealing means;
c. releasable locking means included with said tool for locking
said anchoring means and said sealing means in engagement with said
well conduit;
d. pressure sensitive hold-down means included with said tool for
selectively locking said anchoring means and said sealing means in
engagement with said well conduit when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to prevent pressure induced release of said releasable
locking means;
e. tubular support means extending centrally through said anchoring
means and said sealing means;
f. pressure actuated setting means mounted on said tubular support
means for setting said anchoring means and said sealing means in
said well conduit by moving said anchoring means and said sealing
means into gripping and sealing engagement with said well conduit
to respectively hold said tool against axial movement in said
conduit and to form a pressure seal between said tubular support
means and said conduit; and
g. releasing means included with said releasable locking means and
connecting said setting means and said tubular support means
whereby axial movement of said tubular support means unsets said
tool by releasing said anchoring means and said sealing means from
engagement with said well conduit.
2. The tool as defined in claim 1 wherein said hold-down means
includes:
a. pressure communication means extending within the well tool
between said second sealing means end and said hold-down means and
opening into the well conduit area adjacent said second sealing
means end for communicating the pressure in said well conduit at
said second sealing means end to said pressure sensitive hold-down
means; and
b. movable actuating means connected with said pressure
communication means and movable when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to mechanically lock movable components of said tool to
each other to prevent relative movement between said
components.
3. The tool as defined in claim 1 wherein said releasing means
includes threads carried by said tubular support means cooperating
with threads carried on said setting means whereby rotation of said
tubular support means releases said cooperating threads to permit
said tubular support means to be moved axially to unset said
tool.
4. The well tool as defined in claim 3 wherein said hold-down means
includes:
a. pressure communication means extending within the well tool
between said second sealing means end and said hold-down means and
opening into the well conduit area adjacent said second sealing
means end for communicating the pressure in said well conduit at
said second sealing means end to said pressure sensitive hold-down
means; and
b. movable actuating means connected with said pressure
communication means and movable when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to mechanically lock movable components of said tool to
each other to prevent relative movement between said
components.
5. The well tool as defined in claim 4 wherein said movable
actuating means includes radially movable piston means adapted to
move a resilient snap ring radially.
6. The well tool as defined in claim 4 wherein said movable
actuating means includes axially movable annular piston means
adapted to engage and move a resilient snap ring radially.
7. The tool as defined in claim 3 wherein said release means
further includes severable connecting means securing said tubular
support means to said setting means for preventing relative
movement between said support means and said setting means with
said connecting means being severable by axial movement of said
support means to unset said tool.
8. The well tool as defined in claim 7 wherein said hold-down means
includes:
a. pressure communication means extending within the well tool
between said second sealing means end and said hold-down means and
opening into the well conduit area adjacent said second sealing
means end for communicating the pressure in said well conduit at
said second sealing means end to said pressure sensitive hold-down
means; and
b. movable actuating means connected with said pressure
communication means and movable when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to mechanically lock movable components of said tool to
each other to prevent relative movement between said
components.
9. The well tool as defined in claim 8 wherein said movable
actuating means includes radially movable piston means adapted to
expand a resilient snap ring radially outwardly.
10. The well tool as defined in claim 8 wherein said movable
actuating means includes axially movable annular piston means
adapted to engage and compress a resilient snap ring radially
inwardly.
11. A well tool adapted to be set in a surrounding well conduit
comprising:
a. anchoring means for selectively engaging said well conduit to
anchor said tool to said conduit;
b. sealing means included with said tool for selectively engaging
said well conduit to form a seal between said tool and said conduit
whereby the area in said well conduit at the first end of said
sealing means is sealed away from the area in said well conduit at
the second end of said sealing means;
c. releasable locking means included with said tool for locking
said anchoring means and said sealing means in engagement with said
well conduit;
d. pressure sensitive hold-down means included with said tool for
selectively locking said anchoring means and said sealing means in
engagement with said well conduit when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to prevent pressure induced release of said releasable
locking means;
e. pressure communication means in said hold-down means extending
within the well tool between said second sealing means end and said
hold-down means and opening into the well conduit area adjacent
said second sealing means end for communicating the pressure in
said well conduit at said second sealing means end to said pressure
sensitive hold-down means;
f. movable actuating means connected with said pressure
communication means and movable when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to mechanically lock movable components of said tool to
each other to prevent relative movement between said components;
and
g. radially movable piston means included in said movable actuating
means adapted to move a resilient snap ring radially.
12. A well conduit adapted to be set in a surrounding well conduit
comprising:
a. anchoring means for selectively engaging said well conduit to
anchor said tool to said conduit;
b. sealing means included with said tool for selectively engaging
said well conduit to form a seal between said tool and said conduit
whereby the area in said well conduit at the first end of said
sealing means is sealed away from the area in said well conduit at
the second end of said sealing means;
c. releasable locking means included with said tool for locking
said anchoring means and said sealing means in engagement with said
well conduit;
d. pressure sensitive hold-down means included with said tool for
selectively locking said anchoring means and said sealing means in
engagement with said well conduit when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to prevent pressure induced release of said releasable
locking means;
e. pressure communication means in said hold-down means extending
within the well tool between said second sealing means end and said
hold-down means and opening into the well conduit area adjacent
said second sealing means end for communicating the pressure in
said well conduit at said second sealing means end to said pressure
sensitive hold-down means;
f. movable actuating means connected with said pressure
communication means and movable when the pressure at said first
sealing means end is less than the pressure at said second sealing
means end to mechanically lock movable components of said tool to
each other to prevent relative movement between said components;
and
g. axially movable annular piston means included in said movable
actuating means adapted to engage and move a resilient snap ring
radially.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
The present invention relates to expandable packer tools employed
for forming pressure seals within conduits. More specifically, the
present invention relates to hydraulically set, retrievable well
packers which may be employed in oil and gas wells to form a
pressure seal in the annular area formed between a tubular well
conduit such as production tubing and a surrounding conduit such as
well casing.
2. Brief Description of the Prior Art
U.S. Pat. No. 3,361,209 assigned to the assignee of the present
invention discloses a hydraulically set well packer tool which is
particularly adapted for use in "multiple completion" wells
employed to produce a series of vertically separated petroleum
bearing formations penetrated by a single well bore. The packer of
the foregoing patent includes a central tubular body or mandrel
about which is mounted a composite outer body including metallic
anchoring slips and a resilient sealing means. The slips and seal
are set within the well conduit by introducing a relatively high
hydraulic pressure into the tool mandrel which is concentrically
mounted with and forms a part of the production tubing string. The
setting pressure is communicated to an expandable chamber in the
outer body to move the setting components of the outer body axially
causing the desired radial expansion of the seals and slips. The
packer is then released by moving the mandrel of the packer axially
with respect to anchored components of the outer body to sever a
connecting shear pin which permits relative movement between
components of the packer. The relative axial movement between the
mandrel and the anchored outer body is generally imparted by
raising the tubing string through the casing with the result that
the packer has been termed a "straight-pull release packer."
Because of restrictions imposed by various governmental agencies
controlling oil and gas production, simultaneous production of
several vertically spaced formations is often prohibited, and the
lowermost formation in such multiple completion wells must be
produced first. Single formation production requires that each of
the vertically separated producing formations be separated by means
of suitable packers set in the well conduit so that production
fluid may selectively be permitted to enter the production tubing
from any given one of the vertically spaced formations. After
production is completed in the lowermost formation, the tubing
extending down into such formation is plugged by means of any
suitable plugging means and the next higher formation is then
produced. This procedure is repeated until each of the succeedingly
higher zones is produced whereupon the packers are released and
retrieved from the well along with the production tubing.
In the past, there have been difficulties associated with plugging
of the lowermost packer in multiple completion wells since the
pressure in the lower formation acts against the entire cross
sectional area of the tubing at the point where the mandrel extends
through the packer. The increase in effective area exposed to the
formation pressure permits the formation pressure to exert an
upwardly directed force on the packer mandrel which in turn results
in an upward movement relative to the set seal and anchor slips of
the packer. This action duplicates the retrieval action for the
tool and thus causes undesirable release of the packer before the
next higher zone has been fully produced.
SUMMARY OF THE INVENTION
The hydraulically set, retrievable production packer of the present
invention includes a pressure actuated locking linkage which
mechanically locks the mandrel to relatively movable components in
the outer body of the packer to prevent inadvertent release of the
packer by pressure induced forces. When the pressure differential
across the set packer falls below a predetermined minimum value,
below that necessary for pressure induced release, the linkage
automatically releases the mandrel to permit normal retrieval by
straight pulling of the tubing from the surface.
Basically, the packer of the present invention includes a tubular
central mandrel extending through a closely surrounding body which
includes metallic anchoring slips, cone spreaders adapted to expand
the slips radially into engagement with the surrounding well tubing
or casing and a radially expandable seal assembly adapted to engage
with and seal the annulus between the mandrel and the casing. The
packer is hydraulically set by increasing the hydraulic pressure
within the production tubing string with the increased pressure
acting through a port in the mandrel to expand a pressure chamber
in the outer body causing sequential severing of shear pins
employed to retain the outer body members in retracted position.
The resulting relative axial movement of the outer body members
moves the cones under the slips and compresses the resilient
sealing means to provide the desired anchor and seal in the
casing.
After use, the packer tool of the present invention is retrieved by
pulling upwardly on the tubing string which moves the mandrel of
the packer axially relative to the set slips and sealing means to
shear a release pin. Rupture of the shear pin permits relative
axial movement between the tool components permitting retraction of
the slips and sealing assemblies. A back-up release mechanism is
provided by the interlocking of left hand threads in the outer body
whereby rotation of the tubing string to the right separates the
packing components to permit relative axial movement between the
set anchor slips and sealing assemblies to thereby permit retrieval
of the packer.
The set packer tool is held in position subsequent to plugging of
the mandrel by a mandrel hold-down assembly which includes pressure
actuated, radially movable pistons adapted to expand a resilient
snap ring into mechanical engagement with portions of the outer
body. The mandrel hold-down assembly prevents relative movement
between releasing components of the packer to thereby prevent
undesired shearing of the release pin. The radially movable pistons
of the hold-down assembly are moved outwardly anytime the formation
pressure is greater than the pressure in the annulus above the set
packer to ensure mechanical interlock under pressure conditions
tending to move the mandrel upwardly through the set anchor slips
and sealing assembly. Thus, the mandrel hold-down means of the
present invention is automatically actuated under pressure
conditions permitting inadvertent release of the bottom packer.
In a modified form of the invention, an axially movable piston is
employed to wedge a resilient snap ring into locking engagement
with the mandrel any time the pressure in the formation below the
sealed packer is greater than in the annulus above the packer. When
the pressure differential across the packer seal is substantially
zero or the pressure is greatest from above, the resilient ring
automatically releases the mandrel. In the event the mandrel
hold-down is engaged when release of the packer is desired, the
annular area above the packer seal is pressured to a pressure value
equal to or above that existing below the set packer. By such
means, the hold-down assembly in both forms of the present
invention is returned to its normally released position permitting
relative movement between the releasing components of the packer
with an upwardly directed force, or a rotating action as the case
may be, exerted from the well head.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a quarter sectional view, partially in elevation,
illustrating the well packer of the present invention as it appears
in its radially contracted condition preliminary to being set in a
surrounding well conduit;
FIG. 2 is the tool of FIG. 1 illustrated in its radially expanded
condition, set within the surrounding well conduit;
FIG. 3 is the upper portion of the tool of the present invention
illustrating the mandrel hold-down assembly in its activated or
locked condition;
FIG. 4 is a modified form of the present invention illustrating a
modified mandrel hold-down assembly in released condition;
FIG. 5 is the tool of FIG. 4 illustrating the hold-down assembly in
locked condition;
FIG. 6 is a horizontal cross-sectional view taken along line 6--6
of FIG. 2;
FIG. 7 is a horizontal cross-sectional view taken along line 7--7
of FIG. 3;
FIG. 8 is a horizontal cross-sectional view taken along line 8--8
of FIG. 4; and
FIG. 9 is a horizontal cross-sectional view taken along line 9--9
of FIG. 5 .
DESCRIPTION OF THE PREFERRED EMBODIMENTS
With reference to FIG. 1, the well packer tool of the present
invention is indicated generally at 10 as it appears in its unset
condition within a surrounding well conduit C. FIG. 2 illustrates
the tool 10 in set condition. It will be understood that the
conduit C may be a well casing or a tubing string extending down
through the well casing. The packer tool 10 includes a one piece,
central mandrel 11 which is threadedly engaged at its upper end
(not shown) and lower end with a tubing string T. The tubular bore
of the mandrel 11 is concentric with and forms a continuation of
the tubular bore of the tubing string T. A composite outer body
disposed about the mandrel 11 includes a plurality of metallic
anchoring slip segments 12 and two resilient elastomeric packer
seals 13 and 14.
As will be seen, during the setting of the packer tool 10, relative
axial movement between components in the outer body of the tool
radially expands the slip segments 12 and the seals 13 and 14 into
engagement with the surrounding conduit C to respectively anchor
the mandrel 11 and outer body to the conduit C and to form a
complete seal between the mandrel and conduit. During the setting
action, the slip segments 12 are spread radially outwardly by means
of an upper cone spreader 15 and a lower cone spreader 16 which,
when moved axially toward each other move under internally tapered
surfaces of the slip segments 12 to wedge the segments outwardly
into locking engagement with the conduit C. As will also be seen,
upper and lower bearing members 17 and 18 respectively are adapted
to move axially toward each other during the setting of the packer
tool 10 to axially foreshorten the sealing elements 13 and 14
causing them to expand radially into engagement with the well
conduit to provide the desired seal. An annular, axially movable
dual taper element 19 disposed between the two sealing elements 13
and 14 provides separation between the seals and assists in
directing the seals into proper sealing engagement with the
surrounding well conduit. Downward axial movement of the element 19
is limited by an annular shoulder formed on the internal
circumferential area of the element which is adapted to engage an
annular stop ring 20. The ring 20 limits only the downward movement
of the element 19 to ensure proper positioning of the upper sealing
member 14 and, as may be seen by reference to FIG. 2, to permit the
seal 14 to be moved axially upwardly during the compression and
radial expansion of both of the seals.
The tool 10 of the present invention is hydraulically set with the
desired axial setting movement of the cone spreaders 15 and 16 and
the seal bearing members 17 and 18 being effected by increasing the
hydraulic pressure of fluid contained within the central bore of
the mandrel 11 and tubing string T. When setting is desired, a
suitable plugging member P is pumped down the tubing string T until
it engages an annular seat S formed internally of the tubing below
the mandrel 11. With the plug P positioned as illustrated in FIG.
2, the hydraulic pressure of the fluid within the mandrel 11 may be
increased from the well surface to produce the required setting
movement.
During the setting procedure, the hydraulic pressure existing
within the mandrel 11 is communicated into the outer body of the
packer tool 10 through a radial bore 11a extending through the
mandrel wall. The bore 11a communicates with a pressure activated
expansion chamber 21 formed between movable components in the outer
body of the packer tool. As best illustrated by joint reference to
FIGS. 1 and 2, the expansion chamber 21 is formed in the annular
space bounded between a tubular sleeve 22 and a second radially
spaced tubular housing sleeve 23. The lower surface of the chamber
21 is formed by an annular spacing collar 24 which is threadedly
engaged between the tubular members 22 and 23. The upper surface of
the chamber 21 is formed by a composite movable assembly which
includes an annular piston 25 designed to slide axially between the
tubular sleeve 22 and the lower internal wall of the spreader cone
16. The piston 25 is retained in position between the sleeve 22 and
the cone spreader 16 by means of an annular snap ring 26 which is
set in an annular groove formed on the internal cylindrical surface
at the spreader base. A sliding seal is maintained between the
sleeve 22 and the piston 25 by means of an O-ring 27 with a similar
sliding seal being formed between the piston 25 and the internal
surface of the cone spreader 16 by means of an O-ring 28. An O-ring
29 forms a sliding seal between the outer surface of the cone
spreader 16 and the inner surface of the housing sleeve 23 whereby
the piston 25 and the cone spreader 16 cooperate to form a
pressure-tight, axially movable upper surface to the expansion
chamber 21. In addition to the seal at the upper end of the
expansion chamber, the chamber is further sealed by means of
O-rings 30, 31 and 32 with the O-rings 30 and 31 forming a sliding
seal between the outer body components and the mandrel 11 and the
O-ring 32 sealing the threaded connection between the spacing
collar 24 and the housing sleeve 23.
In the setting components of the outer body, helical springs 35
positioned between the slip segments 12 and a retaining cage 34
bias the slip segments radially inwardly to a normally retracted
position. Pins 16a and 15a extend radially from the cone spreader
16 and 15 respectively into axially extending slots 34a formed in
the cage 34 for maintaining suitable alignment between the movable
components of the outer body. During the setting of the packer 10,
expansion of the chamber 21 under the influence of hydraulic
pressure moves the piston 25 and the lower cone 16 upwardly. The
initial upward movement of the spreader cone 16 severs a shear pin
33 connecting the housing sleeve 23 with the cone 16. Continued
upward movement of the cone 16 advances the cone over the sleeve 22
and under the concavely tapered internal surfaces of the slip
segments 12. The upward movement of the cone spreader 16 begins to
move the slip segments 12 outwardly against the biasing force of
the springs 35 and the segments 12 continue to move radially
outwardly until a collar 36 secured to the lower cone spreader 16
by means of a shear pin 37 engages the lower ends of the slip
segments 12. Continued upward movement of the spreader 16 moves the
slip members 12 upwardly through the cage 34 causing the upper end
of the slip member 12 to engage an annular collar 38 secured to the
upper cone spreader by means of a shear pin 39. With the collars 36
and 38 engaging the slip segments 12 and with the shear pins 37 and
39 intact, upward movement of the cone spreader 16 is transmitted
through the slips 12 to the upper cone spreader 15 and to the lower
bearing member 18 to compress and radially expand the seals 13 and
14. By this means, the seals 13 and 14 are set before the slips 12
engage the surrounding walls of the conduit C. When the seals 13
and 14 have firmly engaged the walls of the surrounding conduit C,
continued upward movement of the upper cone spreader 15 and
attached collar 38 is prevented, resulting in severance of the
shear pin 39. When the pin 39 has sheared, continued upward
movement of the cone spreader 16 advances the slip segments 12 over
the tapered surface of the cone spreader 15 causing them to move
radially outwardly against the biasing force of the spring 35 into
engagement with the walls of the conduit C. With the slips thus
set, continued upwardly directed movement of the cone spreader 16
forces the slips 12 into firm locking engagement with the walls of
the conduit C locking the slips in place and causing the pin 37
connecting the collar 36 to the cone spreader 16 to shear.
During the previously described setting action, the upward movement
of the piston 25 in the upper assembly of expansion chamber 21 acts
to move an annular tapered locking ring 40 upwardly with the upward
movement of the assembly. Hydraulic pressure acting against the
piston 25 drives the locking ring 40 into wedging engagement
between the external surface of the sleeve 22 and a tapered
internal surface formed on the cone spreader 16 to prevent downward
movement of the spreader 16 relative to the tubular member 22. It
will be appreciated that downward motion of the locking ring 40 is
prevented by the frictional engagement formed between
circumferentially extending teeth provided on the internal surface
of the locking ring which engage and dig into the external surface
of the sleeve 22. The lock ring 40 therefore acts to maintain the
components of the packer tool 10 in set position even after the
hydraulic pressure in the chamber 21 has been relieved.
MANDREL HOLD-DOWN ASSEMBLY
A mandrel hold-down assembly indicated generally at 41 is included
with the packer 10 of the present invention for the purpose of
preventing undesired release or unsetting of the tool. The assembly
41 mechanically locks the relatively movable components of the
outer body to the mandrel 11 to prevent undesired, pressure induced
movement between the mandrel 11 and the outer body components. The
hold-down assembly 41 includes a plurality of cylindrical, radially
movable pistons 42 which are adapted to be moved radially outwardly
under the influence of a pressure differential existing between the
annular areas A--1 and A--2, respectively below and above the seals
13 and 14. As illustrated in FIGS. 3 and 7, movement of the pistons
42 forces a split, annular snap ring 43 into locking engagement
with a groove 44 formed in a tubular housing member 45 positioned
at the upper portion of the outer body. The mechanical interlock
between the mandrel 11 and housing 45 prevents severance of a
release shear pin 46 extending between the housing 45 and a piston
bore sleeve 47 threadedly engaged along its upper circumferential
area with the mandrel 11. The lower circumferential surface of the
housing 45 is threadedly engaged with an annular connecting member
48 which in turn is threadedly engaged with the upper bearing
member 17 and a tubular sleeve 49. The sleeve 49 telescopes over
the mandrel 11 and is releasably attached to the lower sleeve 22 to
form part of the release mechanism of the packer tool as will
subsequently be more fully described.
When the tool 10 is set, the pressure existing in the annular well
area A--1 is communicated past the seals 13 and 14 to the hold-down
assembly 41 by means of a path described by radial bores 15a
extending through the upper cone spreader 15, longitudinal slots
22a formed in the lower sleeve 22, and an annular space formed
between the mandrel 11 and the composite structure formed by the
upper tubular connecting member 49, the member 48 and the piston
sleeve member 47. The pressure conducting path extending from the
area A--1 to the hold-down assembly 41 is maintained pressure-tight
by means of O-rings 50, 51, 52, 53 and 54 with a pressure seal
being maintained between the radially movable pistons 42 and the
piston bore sleeve 47 by means of O-rings 55.
OPERATION OF THE WELL PACKER
With joint reference to FIGS. 1 and 2, the packer 10 of the present
invention is lowered into the conduit C as an integral part of the
tubing string T with one or more vertically spaced packers being
included in the tubing string as desired. When the string T and
included packers 10 have been properly placed vertically in the
well conduit C, a plug P is set in the tubing to permit the tubing
pressure to be increased. The density of the plug P is such that
the plug is buoyant in the hydraulic fluid employed to pressurize
the tubing T thus permitting the plug to "float" to the well
surface after the packer tools have been set. It will be understood
that other plugs, such as a tapered plug member having annular
O-rings and adapted to engage a suitable seat formed within the
tubing T or mandrel 11 may also be employed. Similarly, different
plugs may be employed for selective setting of only certain ones of
the packers included in the tubing string.
Once the plug P has been set in the seat S, the pressure of the
hydraulic fluid in the tubing T is increased from the well surface
by a suitable pump or other means. The increasing hydraulic
pressure within the mandrel 11 is communicated through the mandrel
bore 11a to the expansion chamber 21 to exert an upwardly directed
force on the lower cone member 16 which causes the pin 33 to shear.
Once pin 33 has sheared, the cone spreader 16 is permitted to move
upwardly through the outer housing sleeve 23 to slide under the
slip segments 12 until the lower end of the slip segments engage
the lower collar 36 attached to the cone spreader 16. Continued
upward movement of the cone spreader moves the slip segments 12
axially upwardly into engagement with the upper collar 38 secured
to the upper cone spreader 15. With the collars 38 and 36 engaging
the spreader 12 and with the shear pins 39 and 37 intact, continued
upward movement of the cone spreader 16 produces no further radial
expansion of the slip segments 12 and an upward force is exerted
against the upper cone spreader 15 causing the spreader and
attached bearing member 18 to move axially upwardly.
The upward movement of bearing member 18 compresses the sealing
members 13 and 14 causing them to expand radially outwardly into
contact with the surrounding surface of the conduit C. When the
seals 13 and 14 have been firmly seated against the conduit C,
continued upward movement of the bearing member 18 and cone
spreader 15 is essentially terminated and continued upward force
exerted by the slip segments 12 severs the shear pin 39 to permit
the collar 38 to move axially upwardly over the cone spreader 15.
Once the pin 39 has sheared, the two cone spreaders 15 and 16 are
permitted to advance axially toward each other which in turn
expands the slip segments radially outwardly against the biasing
force of the springs 35 and into engagement with the surrounding
walls of the conduit C. When the slip segments 12 have firmly
engaged the well conduit C, further axial movement of the segments
is prevented and continued upward movement of the lower cone
spreader 16 severs the pin 37 permitting the cone spreader 16 to
continue to move under the slips 12 to firmly set them against the
conduit C.
With the well packer 10 set as previously described, the hydraulic
pressure induced from the well head may be relieved. Once such
pressure is relieved, the cone spreader 16 is no longer driven
upwardly by pressure existing within the expansion chamber 21 and
tends to move axially downwardly. The locking ring 40 which is also
driven axially upwardly under the influence of the pressure
existing in the expansion chamber 21 acting through the annular
piston 25, is wedged radially inwardly by the cooperating tapered
surfaces between the cone spreader 16 and the ring 40 causing the
downwardly pitched teeth of the lock 40 to dig into and
frictionally lock with the sleeve 22. By this means, the frictional
locking engagement of the lock ring 40 prevents the cone spreader
16 from moving axially downwardly to thus retain the packer 10 in
its set condition irrespective of the pressure existing in the
expansion chamber 21. When the packing members 13 and 14 are sealed
against the conduit C, the pressure in the annular space A--1 is
communicated behind the set sealing members to the mandrel
hold-down assembly 41. With the pressure in the well area A--1
greater than that in the area A--2, the snap ring 43 and tubular
member 45 are thus mechanically engaged to prevent relative axial
movement between the tubular member 45 and the mandrel 11. By this
means, the components of the packer 10 are held fixed relative to
each other by the automatic action of the mandrel hold-down
assembly 41 to prevent pressure induced relative movement between
the mandrel 11 and the outer body components which, if unchecked,
would sever the pin 46 causing release and unsetting of the packer
10.
RELEASE OF THE WELL PACKER
When it is desired to retrieve the well packer from the conduit C,
the mandrel 11 must be moved axially upwardly with respect to the
set seals 13 and 14 and slip segments 12. The retrieving action is
normally effected by raising upwardly on the tubing string T and
attached mandrel 11 to sever the shear pin 46 which permits the
desired axial movement between the mandrel 11 and the slips and
seals. It will be appreciated that axially upwardly directed
movement of the mandrel 11 is prevented when the snap ring 43 is in
engagement with the groove 44. As previously described, engagement
of the snap ring 43 and groove 44 occurs when the pressure in the
annular area A--2 is less than the pressure in the area A--1 below
the set packer. When retrieval of the packer is desired under the
foregoing pressure conditions, the area A--2 is pressurized from
the well surface to raise the pressure in the area up to or above
that existing in the annular area A--1. Once the pressure
differential has thus been eliminated or reversed, the piston 42 is
permitted to move radially inwardly under the biasing force of the
resilient split ring 43 to the position illustrated in FIGS. 1, 2
and 6. With the ring 43 thus radially retracted, the upwardly
directed forces exerted from the surface on the mandrel 11 are
effective to sever the pin 46, permitting the mandrel 11 to be
moved axially upwardly with respect to the outer body of the
packer.
Relatively small axial movement between the mandrel 11 and the
outer body draws a recessed mandrel area 11b under the joint
between the two connecting sleeve members 49 and 22. With the
recess 11b below the joint area of the two sleeve members, the
slotted upper portion of sleeve 22 is free to move radially
inwardly into the recess 11b, permitting the upper sleeve 49 to
separate and be moved axially upwardly. It will be appreciated that
upward movement of the sleeve 22 is prevented by the cooperating
wedging of the lock ring 40, lower cone spreader 16 and slips 12.
An annular ridge 11c formed at the upper portion of the mandrel 11
is adapted to engage the tubular member 45 in the outer body so
that continued upward movement of the mandrel 11 draws the sleeve
45, connecting member 48 and sleeve 49 upwardly which separates the
two bearing members 17 and 18 to permit retraction of the packers
13 and 14. Continued upward mandrel movement engages the lower end
of the sleeve 49 with the lower bearing member 18 to pull the cone
spreader 15 out from under the set slip segments 12. Once the upper
cone spreader 15 has been pulled away from the slip segments, the
segments are free to return to their radially retracted position
under the influence of the compressed springs 35 to completely
release the tool from the surrounding well conduit C.
As a back-up or alternative release means, the tool 10 is adapted
to be retrieved by imparting a rotational movement to the tubing
string T from the well head to rotate the mandrel 11c causing it to
unthread from its engagement with the piston cylinder sleeve 47. It
will be appreciated that in the normally anticipated application,
the cooperating threads between the cylinder sleeve 47 and mandrel
11 are left hand whereby a right hand rotation (as viewed looking
downwardly from the well head) effect separation of the two mating
components without releasing the adjoining pipe segments forming
the tubing string T. Once the mandrel 11 has been separated from
the sleeve 47, the mandrel is free to move relative to the outer
body even with the shear pin 46 intact and the lock ring 43 engaged
in the groove 44. When the mandrel 11 and cylinder sleeve 47 have
been separated, retrieval of the tool follows the same process as
previously described.
MODIFIED HOLD-DOWN ASSEMBLY
FIGS. 4, 5, 8 and 9 illustrate a modified form of the mandrel
hold-down assembly which may be employed with the packer of the
present invention. With the exception of the hold-down assembly and
the alternate release means to be described, the packer tool 110
illustrated in FIGS. 4, 5, 8 and 9 is the same as the previously
described packer tool 10. Similar components in the modified
packers have been designated by numbers of 100 or above which
include as the last two digits the same numerals as the
corresponding or similar segment in the packer tool 10. With
reference to FIGS. 4 and 8, the modified hold-down assembly
indicated generally at 141 includes an annular, axially movable
piston 142 sealed by means of O-rings 155a and 155b between the
mandrel 111 and the outer tubular housing member 145 respectively.
After the packer has been set in the manner described with
reference to the packer tool 10, the pressure existing in the area
below the set seals acts through the annular space formed between
the mandrel 111 and the sleeve member 149 and connecting member 148
to move the annular piston 142 axially upwardly into engagement
with the annular, split snap ring 143. It will be understood that
the O-rings 155a, 155b, 153, 152 and 150 cooperate with the set
seals of the tool to maintain a continuous seal between the mandrel
and the walls of the conduit C. When the piston 142 is moved
axially upwardly, the internally tapered surface of the piston
engages the lower tapering surface of the snap ring 143 which moves
the ring 143 radially inwardly into engagement with the mandrel
111. Threads 143a formed on the internal surface of the snap ring
143 engage and lock with threads 111d formed on the external
surface of the mandrel 111. The engagement of the snap ring 143 and
mandrel 111 prevents relative movement between the mandrel and the
outer body components to retain the packer 110 in set position.
The engaged position of the snap ring 143 and mandrel 111 is
illustrated in FIGS. 5 and 9. When release of the tool 110 is
desired, the mandrel 111 is rotated to the right by means of force
applied at the well head. Rotation to the right (clockwise as
viewed looking down from the well head) separates or unthreads the
left hand mandrel threads 111d from the mating snap ring threads
143a to raise the threads 143a axially above the snap ring 143.
During the rotation of the mandrel 111, rotation of the snap ring
143 is prevented by means of an index pin 180 which, as best
illustrated in FIGS. 8 and 9, extends through the tubular body
member 145 and into the ring 143. When the mandrel 111 has been
separated from the ring 143, retrieval of the packer tool 110 may
be effected in the manner previously described with reference to
the well packer tool 10. It will be appreciated that in the
modified form of the invention illustrated in FIGS. 4, 5, 8 and 9,
release of the tool is possible without having to increase the
pressure in the annular area A--2 to or above that existing below
the set packer seals.
As an alternate release means for the tool 110, the annular area
A--2 may be pressured to a pressure value above that existing below
the packer seals. The increased pressure existing in the area A--2
is transmitted through the opening in the tubular member 145
housing the index pin 180 to drive the piston 142 downwardly away
from locking engagement with the snap ring 143. Thereafter, an
upwardly directed pull on the mandrel 111 will bias the radially
unrestricted snap ring open to permit the mandrel teeth 111d to
slide freely over the snap ring teeth 143a which frees the mandrel
to permit complete release of the packer 110.
The foregoing disclosure and description of the invention is
illustrative and explanatory thereof, and various changes in the
size, shape and materials as well as in the details of the
illustrated construction may be made within the scope of the
appended claims without departing from the spirit of the
invention.
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