U.S. patent number 3,776,307 [Application Number 05/283,322] was granted by the patent office on 1973-12-04 for apparatus for setting a large bore packer in a well.
This patent grant is currently assigned to Gearhart-Owen Industries, Inc.. Invention is credited to James Douglas Young.
United States Patent |
3,776,307 |
Young |
December 4, 1973 |
APPARATUS FOR SETTING A LARGE BORE PACKER IN A WELL
Abstract
Apparatus for setting a large bore packer in a well penetrating
subterranean formations characterized by a packer assembly
including an expansible liner that can be expanded into contact
with the conduit, such as casing, of the well for tight sealing
engagement without requiring setting anchors or the like; connector
means that is connected with the liner at one end and connected
with a seal sub at the other end, the seal sub having an unusually
large bore for receiving a sealing relationship a large bore, or
seal unit; and settable retainer, such as slips and cones, for
effecting a supplementary retaining force in addition to that of
the expanded liner for setting the large bore packer at a given
depth and retaining it there against unusually large forces. Also
disclosed is a combination of the apparatus with setting tool,
swage, and retainer setting means, as well as specific preferred
embodiments.
Inventors: |
Young; James Douglas (Fort
Worth, TX) |
Assignee: |
Gearhart-Owen Industries, Inc.
(Fort Worth, TX)
|
Family
ID: |
23085471 |
Appl.
No.: |
05/283,322 |
Filed: |
August 24, 1972 |
Current U.S.
Class: |
166/125; 166/138;
166/207 |
Current CPC
Class: |
E21B
43/103 (20130101); E21B 33/12 (20130101); E21B
23/06 (20130101) |
Current International
Class: |
E21B
33/12 (20060101); E21B 23/00 (20060101); E21B
23/06 (20060101); E21B 43/02 (20060101); E21B
43/10 (20060101); E21b 023/04 (); E21b
043/10 () |
Field of
Search: |
;166/206,207,123,125,138 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Claims
What is claimed is:
1. A combination of a packer assembly and apparatus for setting the
packer assembly in conduit in a well penetrating subterranean
formations comprising:
a. a liner including an annular body portion having substantially
cylindrical interior and exterior surfaces that are at least
partially coextensive, having an outside diameter less than the
diameter of said conduit, having sufficient malleability for and
adapted for being expanded to conformingly engage said conduit,
having a wall thickness sufficient to effect a wall after expansion
capable of withstanding the pressure within or outside said liner,
and having a modulus of elasticity in compression sufficient to
retain tight frictional and sealing engagement with said conduit
after expansion thereagainst;
b. a connector means connected at its one end with said body
portion and at its other end with a seal sub; said connector means
having an expansible portion for retaining a sealing
interconnection after expansion of said body portion;
c. a seal sub having a longitudinally extending internal sealing
surface defining a bore for receiving in sealing relationship a
large bore seal unit;
d. settable retainer means for retaining said seal sub at a set
depth by supplementing the retaining force exerted by said annular
body portion when said annular body portion is expanded into said
tight frictional and sealing engagement with said conduit; said
retainer means being connected with said seal sub; said retainer
means having a preset outside diametral dimension less than said
given diameter and being expansible out into positive mechanical
engagement with said conduit upon setting of said combination; and
being lockable into its expanded and set position;
e. swage means adjacent said liner for moving through and expanding
said liner outwardly into tight frictional and sealing engagement
with said conduit, the external dimensions of said swage means
having been pre-selected in accordance with the internal dimensions
of said conduit and the diameter and wall thickness of said liner
to effect said tight frictional and sealing engagement with said
conduit after expansion;
f. retainer setting means for expanding said retainer means into
said positive mechanical engagement with said conduit for setting;
said retainer setting eans being connected with said swage means
and being removable upwardly through said conduit after said liner
and said setting means have been set;
g. an adapter rod means for connecting said swage means and said
retainer setting means with a force generating means; said adapter
rod means being connected at one end with said swage means and said
retainer setting means and having, at its other end portion, means
for engagement with a force generating means for subjecting said
swage means to a force acting to move said swage means completely
through said liner and expand said liner into tight frictional and
sealing engagement with said conduit; and for subjecting said
retainer setting means to a force acting to move said retainer
setting means through said retainer means and expand said retainer
means into said positive mechanical engagement with said conduit;
and
h. setting sleeve means disposed radially of the central axis of
said adapter rod means and adjacent said liner and having means for
engagement with said force generating means for opposing movement
of said liner by transmission of a reaction force that acts
oppositely to said force from said force generating means; said
setting sleeve means being constructed and disposed so as to allow
movement of said swage means completely out of said annular body of
said liner while said reaction force is still being applied to said
liner; all such that said packer assembly can be emplaced at a
given location in said conduit by expansion of said annular body
portion into frictional and sealing engagement with said conduit
and said retainer means expanded into positive mechanical
engagement with said conduit; and said packer assembly will remain
locked into its set position and will resist being displaced
upwardly or downwardly against an unusually large force, such as by
a weight and the force of a pressure acting thereon.
2. The combination of claim 1 wherein said swage means is disposed
below said liner; said adapter rod means passes through said liner
for pulling said swage means upwardly through and completely out of
the top of said liner; said setting sleeve means is disposed above
said liner with its lower end portion engaging the top of said
liner and has means at its upper end portion for engagement with
the force generating means and adapted for transmitting a
downwardly acting said reaction force for opposing upward movement
of said liner when said swage means is pulled upwardly
therethrough; said setting sleeve means has means allowing movement
of said swage means completely out of the top of said liner and
within a portion of said setting sleeve means while said reaction
force is still being applied to said setting sleeve means; and said
retainer means comprises slips, and spaced apart ramps disposed on
opposite sides of said slips; said ramps being movable into a more
closely spaced relationship to expand said slips into said
engagement with said conduit; said ramps being connected with a
locking ratchet for locking said ramps into a set position; said
retainer setting means is disposed below said retainer means and
includes an inverted frustum, and a plurality of collet fingers for
moving said ramps more closely together, said collet fingers being
supported on said inverted frustum before setting; a releasable
spacer means for retaining said inverted frustum and said collet
fingers in spaced relationship; said spacer means being releasable
under sufficient differential force to allow relative movement
between said inverted frustum and said collet fingers such that
after said slips are set said collet fingers can traverse along
said inverted frustum and contract their external diametral
dimension sufficiently to pass upwardly through an internal bore of
said seal sub and said set liner for removal from said conduit in
said well.
3. The combination of claim 1 wherein there is included a large
bore seal unit that conformingly and sealingly fits within said
bore of said seal sub and has a portion that seals contiguous said
sealing surface.
4. The combination of claim 3 wherein said large bore seal unit
comprises a body having a longitudinally extending aperture
penetrating therethrough.
5. The combination of claim 4 wherein said liner has a top portion
integrally connected with said body portion and said top portion
has an inner inverted frusto-conical section to form a stabbing
section to facilitate entry of other elements into said liner once
emplaced in said well.
6. A combustion packer assembly for a conduit in a well penetrating
subterranean formations and having a given diameter comprising:
a. a liner including an annular body portion having substantially
cylindrical interior and exterior surfaces that are at least
partially coextensive, having an outside diameter less than said
given diameter, having sufficient malleability for and adapted for
being expanded to conformingly engage said conduit, having a
thickness sufficient to effect a wall after expansion capable of
withstanding the pressures normally encountered within or outside
said liner and having a modulus of elasticity in compression
sufficient to retain tight frictional and sealing engagement with
said conduit after expansion thereagainst;
b. a connector means connected at its one end with said body
portion and at its other end with a seal sub; said connector means
having an expansible portion for retaining a sealing
interconnection after expansion of said body portion;
c. a seal sub having a longitudinally extending internal sealing
surface defining a bore for receiving in sealing relationship a
large bore seal unit; and
d. settable retainer means for retaining said seal sub at a set
depth by supplementing the force exerted by said annular body
portion when said annular body portion is expanded into said tight
frictional, sealing engagement with said conduit; said retainer
means being connected with said seal sub; said retainer means
having a preset outside diametral dimension less than said given
diameter and being expansible out into positive mechanical
engagement with said conduit upon setting of said combination; and
being lockable into its expanded and set position; such that said
packer assembly can be emplaced at a given location in said conduit
by expansion of said annular body portion into frictional and
sealing engagement with said conduit and said retainer means
expanded into positive mechanical engagement with said conduit; and
said packer assembly will remain locked into its set position and
will resist being displaced upwardly or downwardly against an
unusually large force, such as by a weight and the force of a
pressure acting thereon.
7. The combination of claim 6 wherein said retainer means comprises
slips, and spaced apart ramps disposed on opposite sides of said
slips; said ramps being movable into a more closely spaced
relationship to expand said slips into said engagement with said
conduit; said ramps being connected with a locking ratchet for
locking said ramps into a set position effected by movement of the
ramps more closely together.
8. The combination of claim 7 wherein there is included a large
bore seal unit and said conduit; said annular body portion and said
retainer means have been expanded into their respective engagements
with said conduit; said seal sub has its longitudinally extending
internal sealing surface receiving in sealing relationship said
large bore seal unit and said annular body portion sealingly and
frictionally engages said conduit and said retainer means
positively mechanically engages said conduit to provide sufficient
force to support the weight of said packer in said well and resist
being displaced by pressure acting on said combination.
9. The combination of claim 6 wherein said large bore seal unit
comprises a body having a longitudinally extending aperture
penetrating therethrough.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention relates to apparatus for use in wells penetrating
subterranean formations. More particularly, it relates to liners
and seal subs, and packers and combinations of apparatus employing
the same in casing or tubing in an oil well or the like.
2. Description of the Prior Art
As described in co-pending U.S. Pat. applications Ser. No. 166,066,
now U.S. Pat. No. 3,712,376, entitled "Conduit Liner for Well Bore
and Method and Apparatus for Setting Same" and U.S. Pat. Ser. No.
166,032, entitled "Conduit Liner for Well Bore," inventers Harrold
D. Owen, Wayne O. Rosenthal and James Douglas Young, the prior art
is replete with practical and impractical liners, with and without
seal subs and packers. A wide variety of different types of packers
are also known in the prior art. Illustrative of the principle of
the packers are the so-called "production packers."
Production packers are used in subterranean wells today, primarily
to form a seal between the well casing and the well tubing. The
seal allows production and workover operations to be carried out in
the well. Production packers are generally classified as either
retrievable or permanent. The retrievable packers can be pulled
readily out of the well, if not too badly corroded; but may not be
as desirable and dependable as the permanent packers. The permanent
packers heretofore have been required to be drilled out or
otherwise destroyed to get them out. Most frequently, the need to
remove a permanent packer is caused by having to pass a large
diameter special purpose tool down the well to a point below where
the permanent packer is set. Presently available permanent packers
do not provide large enough openings through them to allow special
pupose tools to pass therethrough.
Moreover, many wells need to employ larger diameter tubing to
effect maximum production rates for most economical operation. The
presently available packers do not always provide a bore size as
large as required for the diameter of the tubing needed for most
efficient production. where each fraction of an inch of increased
bore size pays large dividends, presently available packers are
lacking.
Moreover, presently available packers employ the use of various
approaches to prevent the extrusion and destruction of their
expansible-type sealing elements when the packer is subjected to
high differential pressures. The difficulties with the expansible
type sealing elements is further complicated when the packer is
required to withstand high temperatures; for example, 350.degree. F
or more. Setting packers to withstand the high pressure
differential and the high temperatures has been heretofore
particularly expensive.
Accordingly, it is an object of this invention to provide apparatus
that can be employed to set a production packer that has an
internal bore that is large enough to obviate the disadvantages of
the prior art devices and, particularly, to allow passage of large
diameter special purpose tools and large diameter tubing.
It is also an object of this invention to provide a packer
effecting the foregoing object and also virtually eliminating the
extrusion of an expansible sealing element by greatly reducing all
possible extrusion space.
It is also an object of this invention to provide an apparatus for
setting a large bore packer that effects the foregoing objects and
also is suitable for use at the high temperatures mentioned
hereinbefore primarily because it employs a metal-to-metal seal
with the conduit in the well.
These and other objects will become apparent from the descriptive
matter hereinafter, particularly when taken in conjunction with the
drawings.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a schematic elevational view of the apparatus in
accordance with one embodiment of this invention in a casing in a
well penetrating subterranean formations.
FIG. 2 is a fragmented longitudinal sectional view of upper and
lower portions of the apparatus of FIG. 1, showing the apparatus in
its preset position.
FIG. 3 is a side elevational view, partly in section, showing a
large bore packer, or seal unit, in accordance with another
embodiment of this invention.
FIG. 4 is a side elevational view, partly in section, showing the
packer, comprising the liner, seal sub, and retainer means of FIGS.
1 and 2 in the set position in the conduit in the wellbore.
FIG. 5 is a side elevational view, partly in section, showing the
seal unit of FIG. 3 emplaced in the set packer assembly of FIG.
4.
DESCRIPTION OF PREFERRED EMBODIMENTS
Referring now to the drawings, FIG. 1 illustrates a setting tool
device 11 having a packer assembly 12; comprising an expansible
liner 13, a seal sub 15 and retainer means 17; suspended from a
wireline 19 at a given depth in a section of casing 21 in a
wellbore 23 penetrating subterranean formations 25. A collar
locator and cable head assembly 27 is ordinarily included to
facilitate accurate emplacement of the liner and seal sub and
withdrawal of the setting tool device.
The setting tool device 11 is illustrated in the aforementioned
U.S. Pat. applications Ser. Nos. 166,032 and 166,066 and is
described in detail in U. S. Pat. No. 3,186,485, "Setting Tool
Device," Harrold D. Owen. Reference is made to those documents for
a detailed description of the construction and operation of the
setting tool. Broadly, the setting tool device 11 is a type of
force generating means wherein a piston assembly and a cylinder
assembly are powered for movement relative to each other by an
ignitable charge in the tool. Briefly, setting tool device 11
includes a fluid actuated means comprising a head assembly
including igniter means; a cylinder assembly; and a piston assembly
within the cylinder assembly, with the piston assembly being
slidable relative to the cylinder assembly; and means including a
combustion chamber adapted for receiving a combustible material
powder charge and disposed within the cylinder assembly for
imparting relative movement to the cylinder assembly and the piston
assembly. When the setting tool device 11 is connected with a swage
means 31 and a retainer setting means 77, as described hereinafter,
this relative movement is translated into a movement of the swage
means 31 upwardly through the liner 13 and a movement of the
retainer setting means 77 upwardly through the retainer means 17;
movement of both of which is opposed by a setting sleeve means
29.
For ease of explanation, the setting tool device 11 is illustrated
in FIG. 2 as having its piston assembly connected with the swage
means 31 and its cylinder assembly connected with the setting
sleeve means 29. Adapter means are available to effect the converse
connection in which the cylinder assembly is connected with the
swage means 31 and the piston assembly is connected with the
setting sleeve means 29 if desired.
The packer assembly 12 is accurately positioned at a given depth;
for example, by use of collar locator 27. Thereafter, the setting
tool device 11 is activated to emplace the liner 13, seal sub 15
and retainer assembly 17 at the desired depth.
Referring to FIGS. 2 and 4, the liner 13 includes an annular body
portion 33 having interior and exterior surfaces 35 and 37 that
define cylinders that are at least partially coextensive. The body
portion 33 has an outside diameter less than the diameter of the
casing, or conduit; has sufficient malleability for and is adapted
for being expanded to conformingly engage the casing; and has a
wall thickness sufficient to effect a wall after expansion capable
of withstanding the differential pressure between the inside and
the outside of the liner 13. The body portion 33 of the liner 13
has a modulus of elasticity in compression sufficient to retain
tight frictional engagement with the conduit 21 after being
expanded thereagainst and prevent being displaced upwardly or
downwardly by forces normally expected to be imposed on the liner
13.
As illustrated, the liner 13 contains suitable seal means 49 for
ensuring a fluid impermeable connection between it and the casing
21. For example, the seal means 49 may comprise a plurality of
o-ring type seals disposed in grooves 51 extending peripherally
around the liner 13.
A connector means 39 is connected at its one end with the body
portion 33 and at its other end with the seal sub 15. The connector
means 39 has an expansible portion 41. The expansible portion 41
may be integrally formed with the liner 13; may be affixed by any
suitable expansible joints; for example, it may be thermally joined
thereto, as by welding or silver soldering; all as described in the
aforementioned copending U.S. Pat. applications Ser. Nos. 166,066
and 166,032. As illustrated herein, however, the top of the
connector means 39 and the bottom of the body portion 33 are
connected by means of threaded connection 43, FIG. 4, to facilitate
interconnection of the liner 13 and the seal sub 15. Suitable seal
means 45, such as an o-ring, is provided in conjunction with the
threaded connection 43 to ensure sealing even after expansion of
the expansible portion 41 and the liner 13 into their set position
engaging the conduit 21. Similarly as described with respect to the
connection between liner 13 and the connector means 39, the
connector means 39 may be connected with the seal sub 15 by any
suitable interconnection. As illustrated, the connector means 39 is
formed integrally with the seal sub 15. Any of the other types of
interconnection delineated hereinbefore, or other suitable
interconnection means, may be employed, if desired.
The seal sub 15 has a seal surface 53 defining an internal bore and
extending longitudinally thereof. The seal surface 53 is provided
with a smooth finish for sealing engagement with a seal nipple,
packer or the like that it is to sealingly receive.
The retainer means 17 are settable for retaining the seal sub at a
set depth by supplementing the force exerted by the annular body
portion 33 when it is expanded into the tight frictional and
sealing engagement with the conduit 21. The retainer means 17 has a
preset outside diametral dimension less than the diameter of the
conduit 21 and is expansible radially outwardly into positive
mechanical engagement with the conduit 21 upon setting at the
desired depth. The retainer means 17 is lockable into its expanded
and set position. Specifically, the retainer means 17 comprises a
plurality of pairs of slips 55 held in position intermediate spaced
apart ramps 57 and 59 via suitable means, such as C-ring 61.
Ordinarily, the ramps 57 and 59 comprise frusto-conical sections,
that are commonly referred to as cones, for setting the slips. As
illustrated, the cone ramp 57 is an integral part of the seal sub
15 that also has an interiorly extending cylindrical portion 63.
The frusto-conical ramp 59 and its body are disposed exteriorly of
the interiorly extending cylindrical portion 63 and are movable
longitudinally thereof to move the spaced apart cones 57 and 59
more closely together for setting the slips 55. The body actually
comprises a lock ring 65 and a force ring 67. The lock ring 65 has
interiorly protruding ratchet teeth 69 that co-act with exteriorly
extending ratchet teeth 71 to form a locking ratchet for locking
the ramps 57 and 59 into a set position when they are moved more
closely together to expand the slips 55 outwardly into contact with
conduit 21. The lock ring 65 has a pluarlity of slots 73 that are
spaced around it and extend longitudinally a short distance to
allow the requisite flexibility for the ratchet teeth to engage
each other for locking, yet ratchet over each other for movement of
the body longitudinally upwardly for setting. The ratchet teeth on
the respective interior cylinder 63 as well as on the lock ring 65
are, in fact, continuous and form peripheral rings interiorly and
exteriorly of their respective supports. The teeth rings have
inversely inclined mating surfaces to prevent slipping of the teeth
with respect to each other once they are engaged. Thus, once the
retainer means 17 is set, it is locked into position and cannot
slip or fail to provide the supplemental support needed for
resisting displacement by any unusually large force, such as high
differential pressures or high weight imposed on the liner and seal
sub assembly.
Referring to FIG. 2, the liner 13, seal sub 15 and retainer means
17 are emplaced adjacent the respective setting elements that are
connected with the setting tool device 11 for being lowered into
the well to a given depth and set in the casing 21. The liner 13 is
disposed adjacent the swage means 31 for being expanded outwardly
into tight frictional and sealing engagement with the casing 21 in
the well; and is disposed adjacent a setting sleeve means 29 for
holding the liner 13 at the desired setting depth against the force
of the swage means 31, as the swage means 31 is forced through the
liner. As illustrated, the liner 13 is disposed between swage means
31 and the setting sleeve means 29. Expressed otherwise, the swage
means 31 is disposed below the liner 13 for moving upwardly through
and expanding the liner outwardly into sealing contact with the
casing 21. The external dimensions of the swage means 31 are
pre-selected in accordance with the internal dimensions of the
casing 21 and the diameters and wall thickness of the liner 13 to
effect the necessary frictional engagement and the necessary
thickness of the wall of the liner 13 after expansion into
frictional and sealing engagement with the casing 21. As
illustrated, the swage means 31 has a frusto-conical section 75 to
facilitate upward passage through the liner 13 and expansion
outwardly thereof. If desired, the frustoconical section 75 may
have an arcuate cross sectional profile for greater strength. The
swage means has an exterior contour capable of generating a smooth,
cylindrical interior surface and having the requisite strength to
expand the liner 13 out against the conduit 21 with the force
available in the force generating means.
A retainer setting means 77 is provided for expanding the retainer
means 17 into the requisite positive mechanical engagement with the
conduit 21 for setting at the desired depth. The retainer setting
means 77 is removable upwardly through the conduit after the liner
13 and the setting means 17 have been set. Specifically, and as
illustrated, the retainer setting means 77 is disposed below the
retainer means 17 and includes an inverted frustum 79 and a
plurality of collet fingers 81 for moving the ramp 59 more closely
adjacent the ramp 57 for expanding the slips 55 outwardly into
contact with the casing 21. The collet fingers 81 are supported on
the inverted frustum 79 before setting such that they engage the
force ring 67 for moving it and ramp 59 upwardly relative to ramp
57 and the cylindrical portion 63. A releasable spacer means 83 is
provided for retaining the inverted frustum 79 and the collet
fingers 81 in spaced relationship. The spacer means 83 is
releasable under sufficient differential force between the inverted
frustum 79 and the collet fingers 81 to allow relative movement
therebetween such that after the slips are set the collet fingers
can traverse interiorly along the inverted frustum and contract
their external diametral dimension sufficiently to pass upwardly
through the internal bore of the seal sub and the set liner for
removal. Specifically, the spacer means includes a shear pin 85
screwed into apertures 87 and holding an adapter rod 89 and spacer
ring 91 in spaced relationship until sheared. The collet finger 81
are integrally formed with a threaded section, or ring, 93 that
engages a threaded portion of the shear ring 91, as illustrated.
Roll pin 95 prevents the threaded connection from coming unscrewed
while it is being used in the well. Thus, it can be seen that when
sufficient force is exerted on the adapter rod 89 to move it
upwardly relative to the ramp 57, the lower ramp 59 is moved
upwardly to first set the slips into engagement with the conduit
21. Simultaneously, the ratchet lock is engaged by the engagement
of the interiorly and exteriorly extending ratchet teeth 69 and 71
to hold whatever position is attained. As the force becomes great
enough, due to the interlocking of the collet fingers 81 and the
force ring 67 and the upward movement of the adapter rod 89, the
shear pin 85 is sheared, allowing the inverted frustum 79 to move
upwardly and the collet fingers to slide down the inverted frustum
79 and retract inwardly, and to pass on upwardly through the seal
sub 15 and liner 13. As illustrated, the inverted frustum 79 is
screwed onto the adapter rod 89 by way of mating threaded
connection 97. A lock nut 99 is also screwed onto the threaded
portion of the adapter rod 89 to lock the frustum 79 in a
predetermined position for correct assembly.
An adapter rod means such as adapter rod 89, FIG. 2, is provided
for connecting the swage means 31 and the retainer setting means 77
with a force generating means, such as the setting tool device 11.
As indicated hereinbefore, the adapter rod 89 is connected with the
retainer setting means 77 at its lower end by threaded connection
97 and shear pin 85; is connected with the swage means 31 via
threaded connection 101; and is adapted for connection at its other
end with a force generating means for subjecting the swage means 31
and the retainer setting means 77 to a force acting upwardly for
pulling them upwardly through their respective liner 13 and
retainer means 17.
The setting sleeve means 29 is disposed radially of the central
axis of the adapter rod 89. As illustrated, the setting sleeve
means 29 encircles the adapter rod 89 and has its lower end portion
engaging the top of the liner and being adapted at its upper end
portion for connection with the force generating means for opposing
upward movement of the liner 13 by transmission of a downwardly
acting reaction force from the force generating means.
When the setting tool device 11 is employed as the force generating
means, the adapter rod 89 is connected at its upper end with bottom
piston 103 of the piston assembly of the setting tool device 11. As
described in the aforementioned co-pending U.S. Pat. applications
Ser. nos. 166,066 and 166,032, setting tool device 11 also includes
a top piston, a top piston connecting rod, a top piston extension
rod, and a firing head surmounted by quick change assembly (not
shown). The setting sleeve means 39 is connected with the bottom
cylinder 105 of the setting tool device 11. The cylinder assembly
of the setting tool device 11, as described in the above-mentioned
applications, also includes a top cylinder and a top sub (not
shown). As described also in U.S. Pat. Ser. No. 166,066, a shear
plug, having a predetermined shear value, is threadedly inserted
into matched holes in an upper cylindrical portion and a lower body
portion. Upon ignition of the ignitable charge in the setting tool,
the shear plug is sheared and a force generated to pull the swage
means 31 upwardly through the liner 13, and to pull the retainer
setting means 77 upwardly through the retainer means 17. Movement
of the liner 13 and the seal sub 15 upwardly is opposed by the
downwardly acting reaction force via the cylinder assembly and
bottom cylinder 105 and setting sleeve means 29. Specifically, the
setting sleeve means 29 expandably engages the top of the liner 13
by expander means; such as flexible spring fingers 107. The
flexible spring fingers are ordinarily of steel. The flexible
spring fingers 107 retain the liner 13 in place during setting but
are adapted to flex outwardly to allow passage of the swage means
31 therethrough, and spring back into position after the swage
means 31 has passed therethrough.
To allow the flexible spring fingers to transmit the reaction force
and oppose the force pulling the swage means 31 through the liner
13, as well as allow the retainer setting means 77 to set the
retainer means 17, an expander support ring 109 is employed in the
setting sleeve means 29. The expander support ring 109 is held in
place adjacent the liner 13 and within the flexible spring fingers
107 with a shearable means; such as, shear pins 111; for supporting
the flexible spring fingers 107 during the interaction of the large
force and reaction force pulling the swage means 31 through the
liner 13 and, subsequently, shearing to allow the expander support
ring to move upwardly with the swage means 31. The expander support
ring 109 has an annular shoulder 113 for conformingly engaging a
shoulder portion 115 of the flexible spring fingers 107. The
expander support ring 109 is adapted to be picked up by the swage
means 31 as it moves upwardly and to be moved upwardly
longitudinally within the setting sleeve means 29 after the swage
means 31 has passed through the liner 13 and sheared shear pins
111. The setting sleeve means 29 has concentric interior space for
receiving the swage means 31 and allowing it to pass upwardly
completely out of the liner 13.
In operation, the packer assembly 12 is placed in the well by the
following procedure. The packer assembly and its setting apparatus,
setting tool and any accessory equipment are inserted through
conventional well head and lubricator equipment and lowered to the
desired depth on wireline 19. As indicated hereinbefore, once the
liner is accurately positioned at the desired depth in the conduit
in the well, the force generating means comprising an ignitable
charge in the setting tool is actuated; thereby, normally in a
single stroke, pulling the swage means 31 and the retainer setting
means 77 upwardly through, respectively, the liner 13 and the
setting means 17. Upward passage of the swage means 31 expands the
liner 13 outwardly into physical and sealing contact with the
conduit 21 with sufficient force to retain it in place. Upward
movement of the retainer setting means 77 also sets the retainer
means 17.
In detailed operation, as relative longitudinal movement starts to
occur between the liner 13 and the swage means 15 in response to
the upwardly and downwardly acting forces from the force generating
means, the liner is forced outwardly to engage the casing 21. The
engagement of the liner 13 with the casing 21 stops downward
movement of the liner, obviating the need for an anchor of any
sort; and regardless of whether or not the setting means 17 have
been set prior to or after the liner 13 is expanded into engagement
with the conduit 21. Thereafter, for all practical purposes, the
force of the setting tool is directed to pulling the swage means 15
upwardly through the liner 13 which has been immobilized in tight
fritctional and sealing engagement with the casing 21.
As the swage means 31 moves out of the top portion of the liner 13,
it engages the expander support ring 109, shearing shear pin 111
and moving the expander support ring 109 upwardly. The spring
fingers 107 move outwardly to allow the swage means 31 to pass
therethrough, retaining engagement with the top edge of the liner
13.
The detailed operation of the setting tool device 11 in moving the
swage means upwardly relative to the liner 13 is explained in the
aforementioned U.S. Pat. application Ser. No. 166,066 and need not
be repeated in detail herein. It is sufficient to note that upon
firing of the charge, there is relative movement, after shearing of
the shear pin, between the piston assembly and the cylinder
assembly and this relative movement is translated into relative
movement of the shear means 31 and the retainer setting means 77
with respect to their respective liner 13 and retainer means 17.
Considering specifically the setting of the retainer means 17, upon
initial movement in the illustrated embodiment the force ring 67 is
moved upwardly by collet fingers 81 to move the ramps, or cones, 59
upwardly and set slips 55 into engagement with the interior walls
of the conduit. Simultaneously, the ratchet lock is engaged to hold
this set position. When sufficient force has been reached to shear
the shear pin 85, it shears, moving the inverted frustum 79
upwardly, allowing the collet fingers to move down its slope and
retract their outside diametral dimensions sufficiently to pass
upwardly within force ring 69 and interiorly of the retainer means
17.
As the swage means 31 moves upwardly concomitantly with the upward
movement of the adapter rod 89 to which it is connected, it expands
the liner 13 outwardly into engagement with the conduit, as
described Following the setting operation, the setting tool device
11, the swage means 31, the retainer setting means 77, the setting
sleeve means 29 and accessories are removed from the well, leaving
the packer assembly in place. The packer assembly has an unusually
large bore penetrating longitudinally through the seal sub 15 for
receiving a large bore seal unit or seal nipple therewithin.
The compositions of the liner in its preferred form, as well as
other forms, are delineated at length in the above-referenced U.S.
Pat. applications Ser. nos. 166,066 and 166,032. Briefly, the liner
may be formed of any material having the requisite malleability and
modulus of elasticity in compression. Ordinarily, the liner will be
a metallic liner. For example, alloys of copper, magnesium,
aluminum or iron may be employed. The soft steels form satisfactory
liners, since they have the requisite properties and do not set up
any galvanic cells regardless of the fluid in the conduit or
outside the conduit in a well. A surprising and particularly
preferred material of construction is commercially pure iron such
as is employed in magnetic ingots for making iron cores for
electromagnets, relays and the like. The commercially pure iron is
highly refined open hearth grade of low carbon, low manganese iron.
It has less than 1 percent by weight of alloy constituents, or
other elements, and is described in detail in the above-referenced
U.S. Pat. application Ser. No. 166,032. The liner remaining
emplaced in the casing will have uniform crystallographic
structure, since it has been substantially uniformly expanded
outwardly to engage the casing 21 into which it is emplaced. Also,
the liner will have a smooth bore that will serve to seat
satisfactorily against other elements, although this portion is not
critical, since the interior seal surface 53 of the seal sub 15
will ordinarily be employed for sealingly receiving its elements;
such as, a large bore seal unit.
FIG. 3 illustrates a large seal unit 117 that is suitable for being
emplaced within the packer assembly 12. As employed herein, the
term "seal unit" includes a packer, a seal nipple, and the like for
sealing interconnection with another element, such as a atring of
tubing. Suitable seal nipples have been described in the above
referenced U.S. Pat. application Ser. No. 166,066. The seal unit
117 has suitable seal means 119 disposed peripherally around a
portion of its exterior surface for sealingly engaging the seal
surface 53 of the seal sub 15. The seal means may be disposed in
suitable grooves 121 extending peripherally around the body of the
seal unit 117, similarly as described with respect to liner 13
hereinbefore. As illustrated, the seal unit 117 has, at its top
end, suitable receiving means; such as upset tubing threads 123 in
collar 125 for receiving mating threaded connection of tubing or
the like for production of fluids from the subterranean formation.
As illustrated, the collar 125 is threadedly connected with the top
end of the seal unit 117.
Referring to FIG. 5, the seal unit 117 is sealingly inserted into
the seal sub 15 with the bottom of collar 125 resting upon the
internal wall of the inverted frusto-conical stabbing section 127
of the liner 13. The seal means 119 sealingly engages the seal
surface 53 to form a fluid impermeable block. Thereafter,
production fluids may be produced to the surface through the
production conduit, such as tubing 129, the tubing 129 having been
previously threaded into the tubing threads 123.
The details of construction of the parts of the setting tool, the
swage means and other elements known to the prior art have been
described in the aforementioned U.S. Pat. application No. 166,066
and reference is made thereto for the details. For example, fluid
flow passageways may be provided through the respective means to
facilitate moving rapidly down a wellbore through fluids in the
conduit 21, if desired.
The particular desirable features of liner 13 and its setting
apparatus have been delineated at length in the above-referenced
applications, such as U.S. Pat. Ser. No. 166,066, and need not be
repeater herein. It is sufficient to note herein that the
additional support effected by setting means 17 increases the
flexibility of the liner and seal sub assembly once emplaced in the
well and allows it to resist being displaced upwardly or downwardly
against much greater force than with the liner alone.
From the foregoing it can be seen that this invention provides the
objects delineated hereinbefore and provides apparatus that can be
employed in setting a large bore seal unit that has a large
internal bore sufficient to obviate the disadvantages of the prior
art and allow use of large diameter production conduits, as well as
allow passage of large diameter special tools therethrough without
requiring a drilling out of the packer assembly.
Although this invention has been described with a certain degree of
particularity, it is underatood that the present disclosure has
been made only by way of example and that numerous changes in the
details of construction and the combination and arrangement of
parts may be resorted to without departing from the spirit and the
scope of this invention.
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