U.S. patent number 3,712,376 [Application Number 05/166,066] was granted by the patent office on 1973-01-23 for conduit liner for wellbore and method and apparatus for setting same.
This patent grant is currently assigned to Gearhart-Owen Industries, Inc.. Invention is credited to Harrold D. Owen, Wayne O. Rosenthal, James Douglas Young.
United States Patent |
3,712,376 |
Owen , et al. |
January 23, 1973 |
CONDUIT LINER FOR WELLBORE AND METHOD AND APPARATUS FOR SETTING
SAME
Abstract
A method of emplacing a liner in a conduit in a well penetrating
subterranean formations characterized by positioning with a wire
line a cylindrical annular liner at a given depth in the well, the
liner being disposed adjacent a swaging mandrel and a setting
sleeve, both being connected with a setting tool; actuating the
charge in the setting tool to force the swaging mandrel through the
liner and to oppose movement of the liner by a reactive force on
the setting sleeve, thereby expanding the liner outwardly into
tight frictional engagement with the conduit without requiring an
anchor or supplemental support; and removing the other apparatus
from the well. Also disclosed are specific arrangements and
combinations of respective embodiments and some of the uses of the
liner.
Inventors: |
Owen; Harrold D. (al of Forth
Worth, TX), Rosenthal; Wayne O. (al of Forth Worth, TX),
Young; James Douglas (AL OF Forth Worth, TX) |
Assignee: |
Gearhart-Owen Industries, Inc.
(Forth Worth, TX)
|
Family
ID: |
22601689 |
Appl.
No.: |
05/166,066 |
Filed: |
July 26, 1971 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
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878108 |
Nov 19, 1969 |
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Current U.S.
Class: |
166/277; 166/63;
166/297; 166/380 |
Current CPC
Class: |
E21B
43/105 (20130101); E21B 23/04 (20130101) |
Current International
Class: |
E21B
23/04 (20060101); E21B 23/00 (20060101); E21B
43/10 (20060101); E21B 43/02 (20060101); E21b
023/04 (); E21b 043/10 () |
Field of
Search: |
;166/277,315,63,206,207,297 ;29/522,523 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Parent Case Text
CROSS REFERENCE TO RELATED APPLICATIONS
This application is a continuation-in-part of application Ser. No.
878,108, filed Nov. 19, 1969, now abandoned.
Claims
What is claimed is:
1. A method of emplacing a liner in a conduit in a well penetrating
subterranean formations comprising:
a. positioning via a wire line at a given depth in said conduit an
annular liner having substantially cylindrical interior and
exterior surfaces that are at least partially coextensive, having
an outside diameter less than the internal diameter of said
conduit, having sufficient malleability for and being adapted for
being expanded to conformingly engage said conduit, having a
thickness sufficient to effect a wall after expansion capable of
withstanding the pressure within or outside said conduit, and
heaving a modulus of elasticity in compression sufficient to retain
tight frictional engagement with said conduit after expansion
thereagainst; said liner being disposed adjacent a swage means for
expanding said liner outwardly into said tight frictional
engagement with said conduit and adjacent a setting sleeve means
for holding said liner at the desired setting depth against the
force of said swage means as said swage means is forced through
said liner; said swage means engaging a force generating means
suspended on said wire line for subjecting said swage means to a
force acting to force said swage through said liner; and said
setting sleeve means engaging said force generating means for
subjecting said setting sleeve means to a reaction force opposing
movement of said liner as said swage means is forced
therethrough;
b. actuating said force generating means and applying said force to
said swage means and said reaction force to said setting sleeve
means, thereby forcing said swage means completely through and out
of said liner while said reaction force is still acting on said
liner, and expanding said liner outwardly into tight frictional
engagement with said conduit; and thereafter;
c. removing said force generating means and said swage means from
said well, leaving said liner expanded into said tight frictional
engagement with said conduit and having an unusually large aperture
penetrating longitudinally therethrough.
2. The method of claim 1 wherein said liner is disposed below both
said swage means and said setting sleeve means and is connected
with said setting sleeve means; said swage means engaging said
force generating means for subjecting sad swage means to a force
acting downwardly and said setting sleeve means being connected
with said force generating means for subjecting said setting sleeve
means to a reaction force acting upwardly; and wherein said force
generating means is actuated to push said swage means downwardly
completely out of the bottom of said liner, which is held by said
setting sleeve means, while said reaction force is still acting
upwardly on said liner.
3. The method of claim 2 wherein said setting sleeve means is
connected with the top of said liner and is detachably connected
with said force generating means; and wherein said setting sleeve
means is detached during the operation of setting said liner and is
left in said conduit with said liner expanded into tight frictional
engagement with said conduit.
4. The method of claim 3 wherein a reduced outside diameter of said
swage means is effected to facilitate removal of said swage means
upwardly through the expanded liner.
5. The method of claim 1 wherein said liner is disposed above both
said swage means and said setting sleeve means and is connected
with said setting sleeve means, said swage means being connected
with said force generating means for subjecting said swage means to
a force acting upwardly and said setting sleeve means engaging said
force generating means for subjecting said setting sleeve means to
a reaction force acting downwardly; and wherein said force
generating means is actuated to pull said swage means completely
through and out of the top of said liner, which is held by said
setting sleeve means, while said reaction force is still acting
downwardly on said liner.
6. The method of claim 5 wherein said setting sleeve means is
connected with the bottom of said liner and has a portion that
abuts a portion of a downwardly extending thrust member that is
subjected to said reaction force from said force generating means,
and said setting sleeve means is left in said conduit with said
liner expanded into tight frictional engagement with said
conduit.
7. The method of claim 6 wherein said setting sleeve means has
connection means for connecting with a supplemental element
emplaced therewithin.
8. The method of claim 7 wherein a seal unit is emplaced within
said liner and said setting sleeve means, and has seal means
engaging a longitudinally extending surface defining an internal
bore in said liner, said longitudinally extending surface being
effected by said swage means in expanding said liner outwardly into
said tight frictional engagement with said conduit; said seal unit
having a mating second connection means engaging said connection
means.
9. The method of claim 1 wherein said liner is disposed above said
swage means and below said setting sleeve means, said swage means
being connected with said force generating means for subjecting
said swage means to a force acting upwardly and said setting sleeve
means engaging said force generating means for subjecting said
setting sleeve means to a reaction force acting downwardly; and
wherein said force generating means is actuated to pull said swage
means completely through and out of the top of said liner, which
bears against said setting sleeve means, and into a portion of said
setting sleeve means while said reaction force is still acting
downwardly on said liner.
10. The method of claim 9 wherein said swage means is pulled
upwardly through said liner in a single stroke.
11. The method of claim 9 wherein said force generating means
comprises a setting tool of a type wherein a piston assembly and a
cylinder assembly are powered for relative movement by an ignitable
charge.
12. The method of claim 11 wherein said setting sleeve means is
connected with said setting tool, has flexible expander means and
an expander support ring disposed concentrically within said
expander means for support and wherein said swage means moves said
expander support ring from within said expander means upon its
passage therepast, said expander means expanding outwardly to allow
passage of said swage means and springing inwardly to a position of
normal repose thereafter, whereby a large upwardly acting force may
be applied to said swage means without distorting said setting
sleeve means, and said liner can be emplaced in said conduit with a
single actuation of said force generating means and a single
passage upwardly of said swage means.
13. The method of claim 9 wherein said liner positioned at said
given depth in said conduit is connected with a second said liner
via a connector means, which includes an elongate sleeve portion;
said swage means is connected with a second swage means that has a
slightly smaller diameter than said swage means and is arranged
below said second liner; said swage means is pulled through said
liner and said second swage means is pulled through said second
liner to expand both liners outwardly into frictional and sealing
engagement with said conduit; and both said swage means are removed
in accordance with step (c) of claim 1.
14. The method of claim 13 wherein said swage means and said second
swage means are drawn, respectively, through said liner and said
second liner singly, whereby said force generating means does not
have to generate a force great enough to pull both swaging means
through both liners simultaneously.
15. A combination of liner and apparatus for setting the liner 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
conduit, and having a modulus of elasticity in compression
sufficient to retain tight frictional engagement with said conduit
after expansion thereagainst;
b. swage means adjacent said liner for moving through and expanding
said liner outwardly into tight frictional 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 engagement with said conduit after
expansion;
c. an adapter rod means for connecting said swage means with a
force generating means; said adapter rod means being connected at
one end portion with said swage means and having, at the 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 said
tight frictional engagement with said conduit; and
d. 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.
16. The combination of claim 15 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.
17. The combination of claim 16 wherein said top portion has a
plurality of notches in its top edge.
18. The combination of claim 15 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 below said liner with its upper end portion connected
with said liner and has a portion that abuts a downwardly extending
thrust member, said thrust member having means for engaging said
force generating means and adapted for transmitting a downwardly
acting reaction force for opposing movement of said liner when said
swage means is pulled upwardly therethrough; and space is provided
above the top of said annular body of said liner to allow said
swage means to pass completely out of the top of said annular body
while said reaction force is still being applied to said setting
sleeve means.
19. The combination of claim 31 wherein said setting sleeve means
has connection means for connection with a supplemental element
emplaced therewithin; is sealingly connected with said liner, and
removably abuts said thrust member such that said thrust member may
be removed with said swage means and said setting sleeve means left
in said conduit with said liner expanded into tight frictional
engagement with said conduit.
20. The combination of claim 15 wherein said swage means is
disposed above said liner; said adapter rod means is adapted for
transmitting said force downwardly for pushing said swage means
downwardly through said liner; said setting sleeve means is
disposed above said liner with its lower end portion connected with
said liner and is connected with a tensile means for transmitting a
tensile force upwardly, said tensile means having means for
engaging said force generating means and adapted for transmitting
said reaction force upwardly for opposing movement of said liner
when said swage means is pushed downwardly therethrough; and space
is provided below the bottom of said annular body of said liner to
allow said swage means to pass completely out of the bottom of said
annular body while said reaction force is till being applied to
said setting sleeve means.
21. The combination of claim 20 wherein said swage means has a
frusto-conical section and a sectioned ring means for effecting
said external dimensions of said swage means; said sectioned ring
means being disposed peripherally of said frusto-conical section
and freely movable longitudinally thereof, said sectioned ring
means having a plurality of sections coupled together so as to
effect an outside diameter when positioned at the largest portion
of said frusto-conical section that effects said external
dimensions of said swage means and is continuous for effecting a
smooth bore in said liner; said sections being displacable
sectionally vertically so as to effect a reduced outside diameter
that can be readily withdrawn upwardly through said liner after
emplacement.
22. The combination of claim 20 wherein said setting sleeve means
is connected with the top of said liner and is connected with said
tensile means via detachable connector means for being detached
from said tensile means and left in place with said liner in said
conduit.
23. The combination of claim 22 wherein said detachable connector
means comprises a plurality of paired, mating, tension-sustaining
connectors that are separable by lateral movement, one portion
being carried by said setting sleeve means and one portion being
carried by a biased portion of said tensile means that is biased
for lateral movement so as to disengage from said setting sleeve
means when not restrained, and a restraining means is disposed
adjacent said biased portion for maintaining connection with said
setting sleeve means until said swage means has passed completely
out of said annular body of said liner.
24. The combination of claim 23 wherein said restraining means
comprises a restraining ring and a shearable means for maintaining
said restraining ring adjacent said biased portion; and said
adapter rod means has a shoulder portion for shearing said
shearable means and moving said restraining ring downwardly to
release said biased portion after said swage means has passed
downwardly through said liner and expanded it into tight frictional
engagement with said conduit.
25. The combination of claim 23 wherein said paired connectors
comprise respective mating apertures and protrusions.
26. The combination of claim 25 wherein said apertures are disposed
in said setting sleeve means and said protrusions are carried by
said biased portion, and said biased portion comprises inwardly
biased collet fingers.
27. The combination of claim 15 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; and 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.
28. The combination of claim 27 wherein one of said adapter rod and
said setting sleeve means are operatively connected with one of a
piston assembly of a setting tool and a cylinder assembly of said
setting tool for transmission respectively of said force acting
upwardly and said downward acting reaction force; and said setting
tool comprises a fluid actuated means means comprising a head
assembly including igniter means, said cylinder assembly and said
piston assembly within said cylinder assembly, with said piston
assembly being slideable relative to said cylinder assembly; means
including a combustion chamber adapted for receiving a combustible
material power charge and disposed within said cylinder assembly
for imparting relative motion to said cylinder assembly relative to
said piston assembly to move said swage means upwardly through said
liner, movement of which is opposed by said setting sleeve
means.
29. The combination of claim 27 wherein said setting sleeve means
expandably engages the top of said liner via flexible spring
fingers for retaining said liner in place during setting, said
spring fingers being adapted to flex outwardly to allow passage of
said swage means therethrough and spring back into position after
said swage means has passed therethrough.
30. The combination of claim 29 wherein an expander support ring is
employed in said setting sleeve and is held in place adjacent said
liner and within said flexible spring fingers with a shearable
means for supporting said fingers during the interaction of the
large force and reactive force pulling said swage means through
said liner, said expander support ring having a shoulder for
conformingly engaging a portion of said swage means after said
swage means has passed through said liner and for moving said
expander support ring upwardly as said swage means passes upwardly
out of said liner.
31. The combination of claim 27 wherein the bottom of said body
portion of said liner is sealingly connected with one end of a
connector means and said connector means is sealingly connected at
its other end with a terminal element.
32. The combination of claim 31 wherein said terminal element is at
least a section of a production liner whereby said section of said
production liner and any extensions thereof desired can be emplaced
at a given location in said conduit by expansion of said body
portion into frictional and sealing engagement with said conduit,
and said production liner will resist being displaced upwardly by
pressure or downwardly by its own weight.
33. The combination of claim 31 wherein said terminal element is a
bull plug seal means and wherein said bull plug seal means 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 bull plug seal means will resist being
displaced upwardly or downwardly by force of a pressure acting
thereon.
34. The combination of claim 31 wherein said terminal element is a
second liner smaller than the diameter of said conduit, said second
liner is sealingly connected at one end to said connector means via
an expansible portion, and said connector means includes an
elongate sleeve portion, to form a straddle patch for emplacing in
said conduit for blocking a communicating passageway between the
interior of said conduit and the exterior of said conduit; and
wherein said swage means is connected with a second swage means
below said second liner, said second swage means having a diameter
slightly less than said swage means, said second swage means and
said second liner cooperating to effect sealing engagement of said
second liner with said conduit when said second swage means is
drawn upwardly through said second liner; whereby said second swage
means can also pass through said liner after said swage means has
expanded said liner into contact with said conduit.
35. The combination of claim 34 wherein said second swage means is
immediately below and contiguous with said second liner and said
swage means is spaced a distance below said liner sufficient to
enable said second swage means to traverse through said second
liner before said swage means starts its traverse of said
liner.
36. The combination of claim 31 wherein said terminal element
comprises a seal sub having a longitudinally extending internal
sealing surface defining a bore for receiving in sealing
relationship a large bore packer including single bore packers such
as seal nipples; whereby said seal sub 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
seal sub will resist being displaced upwardly or downwardly by a
weight and the force of a pressure acting thereon.
37. The combination of claim 36 wherein there is included a large
bore packer that conformingly and sealingly fits within said bore
of said seal sub and has a portion that seals contiguous said
sealing surface.
38. The combination of claim 37 wherein said large bore packer
comprises a body having a longitudinally extending aperture
penetrating therethrough.
39. The combination of claim 38 wherein said large bore packer body
has a plurality of apertures extending longitudinally therethrough.
Description
BACKGROUND OF THE INVENTION
1. Field of the Invention
This invention relates to methods and apparatus for use in a well
penetrating subterranean formations. More particularly, it relates
to methods, liners and combinations of apparatus employing a liner
in casing or tubing in an oil well or the like.
2. Description of the Prior Art
The prior art is replete with practical and impractical liners, and
methods and apparatus for setting the liners in the casing or
tubing in a well. As is well known, the liners are ordinarily set
by being expanded outwardly into tight frictional engagement with
the conduit; such as, the casing or the tubing. The degree and type
of tight frictional engagement depends, of course, on the use, or
application, for which the liners are intended. For most
applications, the liners are set with a tightness that prevents
unwanted movement longitudinally of the conduit. Frequently, the
liners are set with both tight frictional and sealing engagement,
as will be apparent from a description of specific embodiments
hereinafter. The tight frictional engagement provides a finite
force that is designed for retaining the liner in place to do its
job. Obviously, forces larger than design can be generated that are
large enough to move the set liner longitudinally of its conduit.
Liners or plugs have been set in a well by detonation of explosives
within an enclosed chamber, or about a mandrel within a conduit;
bridge plugs have been set by drawing a mandrel up within an
expansible annular body and leaving the mandrel emplaced within the
annular body, and by driving an expanding body upwardly or
downwardly into and through an expansible body retained in position
by a supplemental anchor or support means; such as, a tubing stop
or a string of conduit supported on a bottom of the well. Liners
have been set by hydraulically forcing a swaging mandrel, or swage
means, upwardly through corrugated liners held in place by the
tubing string. Liners have also been set by jarring by repeated
firing of an explosive jar brought to the surface and reloaded
between firings and by explosively driving a swage means upwardly
or downwardly through a corrugated liner held in place by a
frangible member with a second explosive charge within the
frangible member to destroy it. While some of the prior art devices
have been useful, they have suffered from one or more of the
following disadvantages:
1. they depended upon a separate supplemental support which had to
engage the conduit and had to be individually set in the well for
satisfactory operation, the supplemental supports were often
unreliable and even if successful effected a surface discontinuity
that created corrosion problems later;
2. they depended upon an outside coating of resilient material for
effecting the sealing;
3. they required two parts; such as, an inner mandrel for setting
and retaining in place;
4. they were limited to thin walls because of the relatively large
flexure of certain corrugations in the walls;
5. they had regions of relatively low yield strength because of the
large amount of flexure induced by corrugations;
6. the resulting structure emplaced in the well-bore had a
restricted aperture that was not as smooth as desired
therethrough;
7. if they formed seats with a smooth internal diameter they were
limited to seating at joints;
8. they required a separate string of pipe for operation; for
example, either for rotating or jarring a tool or for conveying a
high pressure fluid thereto;
9. they required a plurality of trips into the well to effect
passage of the swage means completely through the liner;
10. they destroyed a portion of the equipment and sometimes damaged
other equipment in the well by an uncontained explosion; or
11. they employed in the liner materials that were objectionable
because of their physical, chemical, or electrochemical properties;
for example, they formed galvanic, or electrolytic, cells with the
conduit, thereby causing localized corrosion.
It is a primary object of this invention to provide an improved
method of and combinations of apparatus for setting a liner in a
conduit in a wellbore penetrating subterranen formations that
alleviate the disadvantages of the prior art devices and methods,
as enumerated hereinbefore.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a schematic elevational view of the liner and apparatus
for setting it in a casing in a well penetrating subterranean
formations, in accordance with one embodiment of the invention.
FIGS. 2 and 3 are fragmentary longitudinal sectional views of,
respectively, the upper and lower parts of the device of FIG. 1,
showing the device in one operative position.
FIGS. 4 and 5 are fragmentary longitudinal sectional views of,
respectively, the upper and lower parts of the device of FIG. 1,
showing the device in another operative position.
FIGS. 6 and 7 are fragmentary longitudinal sectional views
illustrating another embodiment of the invention employed in
hanging a production liner within a casing in a well.
FIGS. 8 and 9 are fragmentary longitudinal sectional views of
another embodiment of the invention employed in emplacing a bull
plug seal means in a casing in a well.
FIGS. 10, 11 and 12 are fragmentary longitudinal sectional views
illustrating another embodiment of the invention employed in
emplacing a straddle patch in a casing in a well.
FIG. 13 is a fragmentary longitudinal sectional view of another
embodiment of this invention employed in emplacing a seal sub in a
casing in a well.
FIG. 14 is an elevational cross sectional view of a seal nipple for
emplacing in the seal sub of FIG. 13.
FIG. 15 is a cross sectional view of a multiple bore packer
emplaced in the embodiment of FIG. 13.
FIG. 16 is a fragmentary longitudinal sectional view taken along
the line XVI -- XVI of FIG. 15.
FIG. 17 is a fragmentary longitudinal sectional view illustrating
another embodiment of this invention wherein the liner is disposed
above both the swage means and the setting sleeve means.
FIG. 18 is a fragmentary longitudinal sectional view of the
embodiment of FIG. 17 containing a seal unit and emplaced in the
conduit in the well.
FIG. 19 is a fragmentary longitudinal sectional view illustrating
another embodiment of this invention wherein the liner is disposed
below both the swage means and the setting sleeve means.
FIG. 20 is a fragmentary longitudinal sectional view of the
embodiment of FIG. 19 after the liner has been expanded into tight
frictional engagement with the conduit in the well.
FIG. 21 is a fragmentary longitudinal sectional view illustrating
another construction of the swage means of the embodiment of FIG.
19.
DESCRIPTION OF PREFERRED EMBODIMENTS
Referring now to the drawings, FIG. 1 illustrates a setting tool
device 11, having liner 13 disposed between swage means 15 and
setting sleeve means 17, all suspended from a wire line 19 at a
given depth in a section of casing 21 in 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 withdrawal of the setting tool
device.
The setting tool device which is illustrated in cross section in
FIGS. 2 and 3 is described in detail in U. S. Pat. No. 3,186,485,
"Setting Tool Devices," Harrold D. Owen. Reference is made to that
patent for a detailed description of the operation of the setting
tool. Broadly, the setting tool 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 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 slideable relative to the cylinder
assembly; and means including a combustion chamber adapted for
receiving a combustible material power charge and disposed within
the cylinder assembly for imparting motion to the cylinder assembly
relative to the piston assembly to move the swage means upwardly
through the liner, movement of which is opposed by the setting
sleeve means. For ease of explanation the setting tool is
illustrated herein as having its piston assembly connected with the
swage means and its cylinder assembly connected with the setting
sleeve means. Adapter means are available to effect the converse
connection in which the cylinder assembly is connected with the
swage means and the piston assembly is connected with the setting
sleeve means if desired.
Referring to FIGS. 2 and 3, liner 13 is accurately positioned at a
given depth; for example, by use of collar locator 27. The given
depth may include a section of casing 21 having a leak such as
formed by an aperture 28 therein. Liner 13 includes an annular body
portion having interior and exterior surfaces that define cylinders
that are at least partially coextensive. The body portion 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
differential pressure between the inside and outside of the casing.
The body portion of the liner has a modulus of elasticity in
compression sufficient to retain tight frictional engagement with
the conduit after being expanded thereagainst and prevent being
displaced upwardly or downwardly by forces normally expected to be
imposed on the liner. The liner 13 is disposed adjacent a swage
means 15 for being expanded outwardly into tight frictional
engagement with the conduit such as the casing in the well; and is
disposed adjacent a setting sleeve means 17 for holding the liner
at the desired setting depth against the force of the swage means
15 as the swage means 15 is forced through the liner. As
illustrated, the liner 13 is disposed between swage means 15 and
setting sleeve means 17. Expressed otherwise, swage means 15 is
disposed below liner 13 for moving through and expanding the liner
outwardly and into contact with the casing, the external dimensions
of the swage means having been preselected in accordance with the
internal dimensions of the casing and the diameters and wall
thickness of the liner to effect the necessary frictional
engagement and the necessary thickness of the wall after expansion
into engagement with the casing.
An adapter rod means such as adapter rod 29, FIG. 3, is provided
for connecting the swage means 15 with a force generating means
such as the setting tool device 11. As illustrated in FIG. 3,
adapter rod 29 passes through the liner 13, is connected at one end
portion with swage means 15 and is adapted for connection at the
other end with a force generating means for subjecting the swage
means to a force acting upwardly for pulling the swage means
upwardly through the liner.
Setting sleeve means 17 is disposed radially of the central axis of
the adapter rod 29. As illustrated, the setting sleeve means 17
encircles the adapter rod 29 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 by transmission of a downwardly acting
reactive force from the force generating means.
When setting tool device 11 is employed as the force generating
means, adapter rod 29 is connected at its upper end with bottom
piston 31 of the piston assembly of setting tool device 11. Setting
tool device 11 also includes a top piston 33, a top piston
connecting rod 35, a top piston extension rod 37, and a firing head
39 surmounted by a quick change assembly 41. Setting sleeve means
17 is connected with bottom cylinder 43 of the cylinder assembly of
setting tool device 11. The cylinder assembly also includes top
cylinder 45 and top sub 47.
A shear plug 49, having a predetermined shear value, is threadedly
inserted into matched holes in the upper cylindrical portion 51 and
lower body portion 53. Upon ignition of the ignitible charge in the
setting tool, shear plug 49 is sheared and a force generated to
pull swage means 15 through liner 13. Movement of liner 13 is
opposed by the downwardly acting reactive force via the cylinder
assembly and setting sleeve means 17 and another operative
position, illustrated in FIGS. 4 and 5, is assumed as the swage
means 15 is pulled through liner 13 to expand it out into
frictional and sealing engagement with casing 21.
Specifically, setting sleeve means 17 expandibly engages the top of
the liner via expander means; such as, flexible spring fingers 55.
The flexible spring fingers 55 are ordinarily of steel. The
flexible spring fingers 55 retain the liner in place during setting
but are adapted to flex outwardly to allow passage of the swage
means therethrough, as illustrated in FIG. 5 and spring back into
position after the swage means has passed therethrough.
To allow the flexible spring fingers to transmit the reactive force
and oppose the force pulling swage means 15 through liner 13, an
expander support ring 57 is employed in the setting sleeve means 17
and is held in place adjacent liner 13 and within the flexible
spring fingers with a shearable means; such as, shear pins 59; for
supporting the fingers during the interaction of the large force
and reactive force pulling the swage means through the liner.
Expander support ring 57 has an annular shoulder 61 for
conformingly engaging a shoulder portion 63 of the swage means
after the swage means has passed through the liner for moving the
expander support ring upwardly as the swage means passes upwardly
out of the liner.
The swage means is connected with the adapter rod by a tension
release portion 65 having a weak point to facilitate removal of the
setting tool device in the event malfunction occurs to prevent
removal of the liner and the swage means.
Swage means 15 is illustrated as a ball swage in which the exterior
surfaces form a circle such that upon being pulled through liner 13
an interior cylindrical surface is generated. Any other swage means
capable of generating a smooth, cylindrical interior surface and
having the requisite strength to expand liner 13 out against the
conduit with the force available in the force generating means can
be employed.
Swage means 15 contains a central passageway 83 and branch
passageways 85 and 86 to facilitate flow of fluids therethrough. In
this way the liner and the setting apparatus can be run rapidly
down casing 21 to reach the proper depth more quickly. Swage means
15 contains threaded apertures 87 at each end for receiving a
tension release portion 65 and allow interconnecting it with
adapter rod 29, as well as other adapter rods. Threaded aperture 87
is merely illustrative of a satisfactory interconnection means. Any
other interconnection means can be employed if desired.
As can be seen in FIGS. 4 and 5, when the combustible charge is
nearly spent, the piston assembly including bottom piston 31, top
piston 33, top piston connecting rod 35, and top piston extension
rod 37; firing head 39, and quick change assembly 41 will have
moved upwardly with respect to the cylinder assembly including
bottom cylinder 43, top cylinder 45 and top sub 47. As swage means
15 moves out of the top portion of liner 13, its shoulder portion
63 engages annular shoulder 61 of expander support ring 57,
shearing shear pins 59 and moving expander support ring 57
upwardly. Spring fingers 55 move outwardly to allow swage means 15
to pass therethrough, retaining engagement with the top edge of
liner 13.
The liner is placed in the well by the following procedure. The
liner and its setting apparatus, setting tool and any accessory
equipment are inserted through conventional wellhead and lubricator
equipment; and lowered to the desired depth on wire line 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 upwardly through the liner and expanding the liner outwardly
into physical contact with the conduit with sufficient force to
retain it in place. 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. 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
frictional engagement with the casing 21. Following the setting
operation, the setting tool, the swage means and the setting sleeve
means and accessories are removed from the well, leaving the liner
in place having an unusually large aperture penetrating
longitudinally therethrough.
The liner remaining emplaced in the casing has uniform
crystallographic structure since it has been substantially
uniformly expanded outwardly to engage the casing, or other
conduit, into which it is emplaced. The liner has a smooth bore
which will serve as a seat against which to seal other
elements.
The liner may be formed of any material having the requisite
malleability and modulus of elasticity in compression after
expansion against the conduit. 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 the well. A surprising and particularly preferred
material of construction is commercially pure iron such as is
employed in magnetic ingots for making iron cores of
electromagnets, relays, and the like. The commercially pure iron is
a highly refined open hearth grade of low-carbon, low-manganese
iron. It has less than one percent by weight of alloy constituents,
or other elements, and is described in detail in our co-pending
application Ser. No. 166,032 entitled "Conduit Liner for Wellbore,"
filed July 26, 1971.
When softer metals; such as, aluminum, magnesium, or alloys of
copper; are employed as the body portion of the liner, it is
preferable to include a top portion integrally connected with the
body portion. The top portion should have a plurality of notches in
its top edge to afford niches into which the metal can extrude when
the swage means is pulled upwardly through the body portion of the
liner. In this way, the metal does not extrude between the spring
fingers of the setting sleeve.
When the liner is to be employed as other than a patch for the
conduit, it is preferable to include integrally connected with the
body portion of the liner a top portion that has an inner inverted
frusto-conical section to form a stabbing section to facilitate
entry of other elements into the liner once emplaced in the
well.
If desired, a coating of a supplementary material may be employed
on the exterior surface of the liner to facilitate effecting a seal
with the conduit into which the liner is emplaced. When such an
external coating is employed, care should be taken that the
material of which the coating is made does not extrude from between
the liner and the conduit under the differential pressures that may
exist thereacross and that the material is not soluble in fluid in
contact with it so as to be dissolved from between the liner and
the conduit.
In other embodiments, the liner can be employed with a connector
means for connecting with a terminal element. The connector means
is connected at one of its ends with the body portion of the liner
and at the other of its ends with the terminal element. The
terminal element may comprise conventional or newly developed
downhole equipment; and, typically, includes equipment such as a
production liner; a bull plug seal means; a seal sub for a seal
nipple or packer; or an intermediate conduit of a straddle patch.
Preferably for most downhole applications, the connector means is
sealingly connected with the liner and with the terminal element;
and has an expansible portion for retaining the sealing
interconnection after the body portion of the liner has been
expanded outwardly into tight frictional engagement with the
conduit in the well. The connector means may be connected with
either the top or the bottom of the respective liner, as most
expeditious in connecting with the terminal element. The connector
means may be connected with the terminal element by conventional
means; such as, a threaded connection; or by an expansible portion,
depending upon the nature of the terminal element. The connector
means may be integral with or carried by either the terminal
element or the liner, or it may be detachably connected with either
or both, as by threaded connection. A variety of typical connector
means are illustrated in the figures hereinafter referred to and
the accompanying descriptive matter.
Referring to FIG. 6, liner 13 is connected at its lower extremity
with connector means 67. The expansible connector portion of the
connector means 67 is illustrated as being integrally formed with
liner 13. If desired, and as implied hereinbefore, it may be
affixed by any suitable expansible joint; for example, it may be
thermally joined thereto; as by welding, or silver soldering. At
its other end, or lower end portion 69, connector means 67 may be
threaded to facilitate joining with sub 71 onto which at least a
section 73 of a production liner is affixed. While threaded
connections between connector means 67, sub 71 and production liner
73 are illustrated, any suitable means can be employed for such
interconnection.
The liner 13 of FIG. 6 is arranged and emplaced similarly as
described hereinbefore. Specifically, the liner 13 is disposed
between swage means 15 and setting sleeve means 17 for accurate
placement within the conduit when swage means 15 is pulled through
liner 13. The adapter rod 29 is connected with a force generating
means for pulling swage means 15 through liner 13 and setting
sleeve means 17 is connected with the force generating means for
imparting an opposing, or reactive, force to retain the liner
accurately positioned and oppose its being displaced upwardly by
the movement of swage means 15 therethrough. The force generating
means is actuated to pull swage means 15 through liner 13 and
expand it out into frictional and sealing engagement with conduit
75 which may be the same as casing 21. The force generating means
pulls swage means 15 through liner 13, effecting simple, rapid,
long lasting emplacement of the liner. Thereafter, the force
generating means, swage means 15, and setting sleeve means 17, as
well as the intermediate connections, are removed from the
well.
FIG. 7 illustrates the liner 13 expanded into place against conduit
75, the connector means 67 with its upper expansible portion
expanded with liner 13, the sub 71, and the production liner 73
emplaced in a conduit 75 in the well-bore. The production liner may
be employed as a sand screen, or in connection with a gravel pack.
Such production liners are frequently employed in wells operating
under secondary recovery techniques; such as, flooding or thermal
recovery. While the liners are ordinarily of steel, in certain
instances, such as thermal recovery, they may be of stainless
steel, titanium or other oxidation resistant metals or metallic
alloys. The tough metals such as titanium require greater forces in
setting, however, when they are employed in liner 13. Production
liners are well known in the technology of producing oil from
subterranean formations and need not be described in great detail
herein.
When emplaced with liner 13, the production liner does not move
downwardly from its own weight. Neither is it moved upwardly by any
pressure differential. Ordinarily, there is relatively small
differential pressure between the inside and the outside of a
production liner.
FIG. 8 illustrates liner 13 and connector means 67 employed to
support a bull plug seal means 79 within conduit 75 inside a
wellbore. In this embodiment of the invention, the liner is run
downwardly through conduit 75 relatively slowly to allow fluids
within the conduit to flow past the bull plug seal means 79 and
liner 13. Threaded connections are illustrated as the means by
which bull plug seal means 79 is connected with the connector means
67. Any other suitable means may be employed to interconnect the
two.
After the desired depth has been achieved in the wellbore,
operation of the setting apparatus is effected by actuation of the
force generating means as described hereinbefore. Upon actuation of
the force generating means, swage means 15 is pulled upwardly
through liner 13, expanding the liner outwardly and into frictional
and sealing engagement with conduit 75. Setting sleeve means 17 is
also connected with the force generating means for opposing the
relatively upward movement of swage means 15 with downwardly acting
reactive force to retain liner 13 at the desired depth in conduit
75 for emplacement.
FIG. 9 illustrates the liner 13 emplaced in conduit 75, the upper,
or expansible, portion 81 of connector means 67 being expanded
outwardly to accommodate the increased diameter of liner 13, and
the lower portion retaining the original diameter and threadedly
and sealingly connected with bull plug seal means 79.
In FIG. 9 spring fingers 55 are seen clearly after swage means 15
has passed upwardly therethrough, moving expander support ring 57
upwardly from within fingers 55. Setting sleeve means 17, swage
means 15, as well as the remainder of the force generating means
are removed from conduit 75 to leave bull plug seal means 79 firmly
emplaced via liner 13 in conduit 75. Liner 13 sealingly and
frictionally engages conduit 75 with sufficient force to prevent
movement of bull plug seal means 79 upwardly or downwardly by the
force of any differential pressure across it normally expected to
be encountered. Such differential pressure may be appreciable since
the purpose of the bull plug seal means is for isolating a zone of
a particular fluid pressure from the remainder of conduit 75. For
example, the differential pressure may run as high as 1000 to 3000
pounds per square inch, or higher. It is apparent, therefore, that
the frictional engagement of liner 13 with conduit 75 must resist
displacement with a large frictional force. In some instances where
a large differential pressure is expected, the force generating
means may generate a force sufficient to expand the liner outwardly
to the extent that conduit 75 is also distorted slightly to
increase the force resisting movement upwardly or downwardly.
FIG. 10 illustrates another embodiment of the invention in which
the connector means 67 is sealingly connected with liner 13,
includes an elongate sleeve portion 93, and is sealingly connected
at its other end with the annular body portion of a second liner 99
to form a straddle patch for emplacing in the conduit for blocking
a communicating passageway between the interior of the conduit 75
and the exterior of the conduit 75.
Specifically, liner 13 is threadedly connected with the connector
means 67 via an expansible portion comprising conforming threaded
section 89 and 91, and sealing means; such as, O-rings 95; that are
employed to ensure that liner 13 is sealingly connected with
connector means 67 after expansion.
Similarly, the lower end portion 97 incorporates threaded sections
89 and 91 with O-rings 95 to form a second expansible portion 97
that sealingly connects the connector means 67 with the second
liner 99. As illustrated, the connector means 67, incorporating its
elongate sleeve portion 93 and two expansible portions, is
connected with the bottom of the top liner 13 and the top of the
bottom liner 99 to form the straddle patch.
Swage means 15 is connected with a second swage means 101 below
second liner 99. Second swage means 101 has a diameter slightly
less than the diameter of swage means 15 so that it will freely
pass through the aperture left in liner 13 by the passage of swage
means 15 therethrough. Moreover, the diameter of the second swage
means 101 and the diameters and wall thickness of second liner 99
are selected so that they cooperate to effect sealing engagement of
second liner 99 with conduit 75 when second swage means 101 is
drawn upwardly through second liner 99 expanding it outwardly into
sealing and frictional engagement with conduit 75.
It is important that the swage means pass through the associated
liners to expand them outwardly into engagement with conduit 75
singly rather than simultaneously. In this way, setting sleeve
means 17 is not required to supply the large force that would be
required by simultaneous passage of both swaging means through both
liners. It is not critical which swage means is pulled through its
associated liner first.
As illustrated, second swage means 101 is immediately below and
contiguous with second liner 99 and swage means 15 is spaced a
distance below liner 13 sufficient to enable second swage means 101
to transverse through second liner 99 before swage means 15 starts
its traverse of liner 13.
Swage means 15 is connected via adapter rod 29 with the force
generating means and setting sleeve means 17 is connected with the
force generating means as described hereinbefore.
Swage means 15 is connected with second swage means 101 by a second
adapter rod 107 and a second tension release means 109. Second
tension release means 109 enables removal of the portion of the
apparatus thereabove in the event there is a malfunction which
prevents removal of the second swage means from the conduit 75
within the well.
The straddle patch formed by the two liners and the intermediate
second conduit will straddle passageways 103 communicating with an
undesired strata by emplacing the straddle patch at the appropriate
depth in conduit 75.
The force generating means is actuated to pull second swage means
101 through second liner 99 and swage means 15 through liner
13.
An intermediate position in which second swage means 101 has passed
through second liner 99 and in which swage means 15 is in the
process of being passed upwardly through liner 13, is illustrated
in FIG. 11. Therein, second liner 99 has been expanded outwardly to
sealingly and frictionally engage conduit 75. Lower expansible end
portion 97 of connector means 67 has been expanded with the body
portion of second liner 99. The conforming threaded sections 89 and
91 are expanded outwardly to retain sealing engagement. O-rings 95
also retain sealing engagement and ensure there is no leakage.
It may be advantageous to employ a connector means wherein the
elongate sleeve portion 93 is threadedly and sealingly connected at
each end portion to the respective expansible portions, in the
manner as sub 71 was engaged in FIG. 6. In this way, the threaded
sealed portions of the connector means are not expanded, thus
lessening the chances of a leak.
As swage means 15 is pulled upwardly through liner 13, spring
fingers 55 engage the top portion 105 of the liner and resist its
being displaced upwardly. Moreover, as swage means 15 passes
through the lower portion of the liner 13 and the upper portion of
connector means 67, they are expanded outwardly to frictionally and
sealingly engage a portion of conduit 75, and help to retain the
liner in place. Expander support ring enables spring fingers 55 to
withstand the large force engendered by the interaction between the
upward acting force on adapter rod 29 and the downward acting
reactive force on setting sleeve means 17 without bowing or
otherwise distoring.
FIG. 12 illustrates the straddle patch emplaced within conduit 75.
Therein, liner 13 and second liner 99 are sealingly and
frictionally emplaced in conduit 75 and co-act with connector means
67 to effect a straddle patch which isolates passageway 103 from
the interior of conduit 75. Liner 13 has a stabbing section 111
comprising an inverted frusto-conical section. As illustrated, top
portion 111 has notches 113 to allow room for extrusion of metal
thereinto during the passage of the swage means through liner 13.
Notches 113 are not ordinarily necessary in second liner 99 since
there are no adjacent spring fingers 55 into which metal will
extrude. Moreover, extrusion of metal in second liner 99 by passage
of second swage means 101 therethrough, is of less significance
than at the top of liner 13.
A variety of other applications, or uses, of the liner 13 will be
apparent once this invention becomes known. Illustrative of such
other uses is the use of a seal sub as the terminal element, the
seal sub being used to sealingly receive a "large bore packer," or
the like. The term "large bore packer" is used in its broad sense
to include single bore packers and similar devices such as seal
nipples, as well as packers having a plurality of bores. The liner
13 connected via connector means 67 having an expansible portion
131 with a seal sub 133 is illustrated emplaced in casing 21 in
FIG. 13. The connector means is connected with the body portion of
the liner 13 via threaded connection 135 and suitable sealing means
137; such as, an O-ring in an annular recess. On the other hand,
the connector means 67 is integrally formed with the seal sub 133.
As illustrated, the liner 13 contains suitable seal means 139 for
ensuring a fluid impermeable interconnection between it and the
casing 21. For example, the seal means 139 may comprise a plurality
of O-ring type seals disposed in grooves 141 extending peripherally
around the liner 13. The seal sub 133 has a seal surface 145
defining an internal bore and extending longitudinally thereof. The
seal surface 145 is provided with a smooth finish for sealing
engagement with the seal nipple, packer, or the like, that it is to
sealingly receive.
A seal nipple 147 suitable for emplacing within the seal sub 133 is
illustrated in FIG. 14. The seal nipple 147 is provided with a top
and bottom connection means such as female threads 149 for
sealingly receiving male threads on a compatible element; such as,
a joint of pipe in a string of conduit. In this way, the joint of
pipe, or conduit, may be screwed into the seal nipple 147 and
lowered until the seal nipple 147 is emplaced within the seal sub
133. If desired, suitable seal means 151 such as O-ring type seals
may be emplaced in grooves 153 extending peripherally around the
seal nipple 147. An undercut portion 155 is provided for being
gripped with a wrench or the like in order to hold the seal nipple
147 while screwing the respective joints of pipe into the threads
149, or for other purposes.
A packer 159 emplaced in the seal sub 133 is illustrated in FIGS.
15 and 16. Whereas the seal nipple 147, FIG. 14, had a single
aperture 161, the packer 159 has a plurality of apertures 163-165
for receiving respective strings of conduit such as tubing and
spaghetti strings. Such supplemental strings of conduit may be
necessary in the production of a plurality of zones or in operating
supplemental downhole equipment such as gas lift valves or gas
operated devices in which the gas is injected through the spaghetti
strings. On the other hand, the spaghetti strings may be employed
for injection of chemicals; such as, corrosion inhibitors; paraffin
deposition suppression chemicals; or the like. In any event, the
packer has a sealing surface 167 for being disposed adjacent the
seal surface 145 of the seal sub 133. If desired, suitable seal
means 151 may be provided also in the body of the packer 159. The
seal means 151 may be disposed in suitable grooves 153 extending
peripherally around the body of the packer 159, similarly as
described with respect to the seal nipple 147.
In operation, the liner 13 is set in the casing 21 as described
hereinbefore. Specifically, the liner is emplaced at the desired
depth and the setting tool activated to pull the swage means
upwardly through the liner to expand it out into tight frictional
engagement with the casing 21. The expansible portion of the
connector means 67 expands outwardly to retain sealing engagement
with the liner 13 as it is expanded. Consequently, the seal sub 133
is sealingly connected with the liner 13. When the respective
elements such as the seal nipple 147 or the packer 159 is
thereafter emplaced sealingly within the seal surface 145 of the
seal sub 133, there is a fluid impermeable block formed; although
fluid may flow through the bores of the respective apertures within
the element so emplaced. The bores 163-165 may have conduits
sealingly emplaced within them so that the conduits define the flow
passageways, whereas the single aperture 161 of the seal nipple 147
may define the flow passageway therethrough.
While the straddle patch illustrated in FIGS. 10-12 employed a
unitary elongate sleeve portion 93, the sleeve portion may comprise
a plurality of joined sections, if desired.
In the embodiments illustrated and described hereinbefore, the
liner has been shown above the swage means and below the setting
sleeve means to facilitate expansion of liner outwardly into the
conduit by drawing the swage means upwardly therethrough. If
desired, the liner may be disposed either above both the swage
means and the setting sleeve means or below both the swage means
and setting sleeve means.
For example, FIGS. 17 and 18 illustrate an embodiment in which the
liner 13 is disposed above both swage means 171 and setting sleeve
means 173. In FIG. 17 the combination comprises, in addition to the
swage means 171 and the setting sleeve means 173, adapter rod means
175 and thrust means 177 for effecting the desired interconnection
between the respective elements of a force generating means such as
setting tool device 11 and the swage means 171 and setting sleeve
means 173.
The swage means 171 has its external dimensions sized, as described
hereinbefore with respect to swage means 15, to effect expansion of
the liner 13 into tight frictional engagement with the conduit,
such as the casing 21, in the wellbore. The swage means 171 has a
spherical exterior surface 179 for effecting a smooth internal bore
in the liner after it has been expanded. The swage means 171 has a
cylindrical interior 181 and is movable longitudinally with respect
to thrust member 183 of the thrust means 177. The swage means 171
is structurally strong so as to expand the liner 13 outwardly into
tight frictional engagement with the casing 21 without being
compressed inwardly enough to bind on thrust member 183 as the
swage means 171 passes upwardly through the liner 13.
The adapter rod means 175 is connected at one end portion with the
swage means 171 and has, at its other end portion, means 185 for
connection with a portion of a force generating means; such as, the
bottom piston 31 of the piston assembly of the setting tool device
11; for pulling the swage means 171 upwardly through the liner 13.
The adapter rod means 175, as illustrated, comprises a generally
cylindrical member that is disposed exteriorly radially of the
thrust member 183 and has slots 201 for accommodating movement of a
crossover pin longitudinally thereof. The adapter rod means 175
extends downwardly through liner 13.
The setting sleeve means 173 has its upper end portion connected
with the liner 13, as by threaded connection 187. Setting sleeve
means 173 has a first shoulder portion 189 that removably abuts a
second shoulder portion 191 of the thrust member 183. Thus, the
setting sleeve means 173 is adapted for transmitting a tensile
force to hold downwardly on the liner 13 to prevent its movement
upwardly as the swage means 171 is drawn upwardly therethrough.
Space 205 is provided above the top of the annular body of the
liner 13 to allow the swage means 171 to pass completely out of the
top of the annular body while the reaction force from the force
generating means is still being applied to the setting sleeve means
via thrust member 183. The setting sleeve means 173 has connection
means 205 for connection with a supplemental element emplaced
therewith after liner 13 has been expanded into tight frictional
engagement with the casing 21 and the remainder of the setting tool
device 11, swage means 171, and the thrust member 183 have been
removed from the casing 21. Such an arrangement, with the
connection means 205 engaging second mating connection means 207 of
a seal unit 209 emplaced within the liner 13 and the setting sleeve
means 173, is illustrated in FIG. 18.
The thrust means 177 comprises an adapter means including a
crossover pin 193, skirt 195, and thrust member 183. The crossover
pin 193 is retained in skirt 195 by annular ring 197 which is held
in place by suitable means such as shear pin 199. The crossover pin
193 traverses longitudinally in slots 201 in adapter rod means 175,
as indicated hereinbefore. The skirt 295 engages, as by threaded
connection or abutting engagement, the other portion of a force
generating means; for example, the bottom cylinder 43 of setting
tool device 11; for transmission of the reaction force opposing
movement of the liner 13 as the swage means 171 is pulled upwardly
therethrough.
Central passageway 83 and branch passageways 85 and 86 are
provided, as described hereinbefore, for allowing fluid flow
therethrough, facilitating rapidly changing depths in the borehole
without creating pressure surges.
In operation, the adapter rod means is connected with the bottom
piston 31 of the setting tool device 11, and the sleeve 195 abuts
the bottom end of cylinder 43 of setting tool device 11. The liner
13 has its bottom interior shoulder bearing on swage means 171 and
setting sleeve means 173 has its shoulder portion 189 bearing on
the second shoulder portion 191 of thrust member 183. The assembled
combination is lowered to the desired depth in the well bore where
the liner 13 is to be set. Thereafter, the setting tool device 11
is actuated, as described hereinbefore. Setting sleeve means 173
and the liner 11 are initially moved downwardly as the swage means
71 is moved upwardly. The liner 13 is expanded outwardly into
engagement with the casing 121, however, to stop movement of the
liner, as described more fully hereinbefore. Thereafter, the swage
means 171 is moved upwardly completely out of the top of the liner
13 to complete the swaging operation.
After the liner 13 has been expanded outwardly into tight
frictional engagement with the casing 21, the thrust member 183,
the swage member 171, and the setting tool device 11 may be moved
upwardly out of the wellbore leaving the setting sleeve means 173
emplaced with the liner 13. Subsequently, any suitable device may
be installed in the liner. For example, as illustrated in FIG. 18,
a seal unit 209 may be lowered into place, and its mating
connection means 207 engaged with connection means 205 such that
resilient seals 209 engage the interior surface 211 of liner
13.
FIGS. 19-21 illustrate another embodiment in which the liner 13 is
disposed below both swage means 221 and setting sleeve means 223.
In FIG. 19, the combination comprises, in addition to the swage
means 221 and setting sleeve means 223, adapter rod means 225
connecting the swage means with the force generating means, and
tensile means 227 for transmitting a tensile reaction force
upwardly for opposing movement of the liner 13 as the swage means
221 is pushed downwardly therethrough.
The swage means 221 has external dimensions sized as described
hereinbefore to effect expansion of the liner 13 into tight
frictional engagement with the casing 21. Swage means 221 has a
frusto-conical section 229. A sectioned ring means such as
sectioned ring 231 is provided for defining the cylindrical
exterior having the desired outside diameter. The sectioned ring
231 is disposed peripherally of the frusto-conical section 229 and
is movable longitudinally thereof. Preferably, the sectioned ring
231 has a plurality of sections such as section 233 and V-shaped
section 235 to facilitate withdrawal of the swage means 221
upwardly through the liner after the liner has been set. Sections
233 and 235 are coupled together to effect the desired uniform
outside diameter when positioned at the largest portion of the
frusto-conical section 229. The sections join smoothly together to
effect the desired external dimensions delineated hereinbefore and
to form a continuous surface for effecting a smooth bore in the
expanded liner. Sections 233 and 235 are displacable sectionally;
for example, vertically; to effect a reduced outside diameter that
can be readily withdrawn upwardly through the liner after the
latter's expansion. If desired, other forms of the sectioned ring;
such as ring 237, FIG. 21; can be employed.
The adapter rod means 225 comprises a strong rod-like member with a
relatively large diameter so as to be able to push the swage means
221 downwardly through the liner 13. The adapter rod means 225 is
connected with an adapter means, which includes cross link 239 and
skirt 241. The cross link 239 is retained in suitable apertures in
adapter rod means 225 and skirt 241 by an annular ring 243 that is
held in place by shear pin 245. The cross link 239 traverses
longitudinally in slots 247 in the tensile means 227. The skirt 241
engages, as by threaded connection or abutting engagement, the
bottom cylinder 43 of the setting tool device 11 for transmission
of the requisite downward force to push the swage means 221 through
the liner 13.
The setting sleeve means 223 has its lower end portion connected
with the liner 13 as by threaded connection 249. The setting sleeve
means 223 is connected with the tensile means 227. As illustrated,
setting sleeve means 223 is connected with the tensile means 227 by
a detachable connector means 251 for being detached from the
tensile means 227 and left in place with the liner 13. The
detachable connector means 251 comprises a plurality of paired,
mating, tension-sustaining connectors; such as, apertures 253 and
protrusions, or pins, 255; that are separable by lateral movement.
One portion of the connector; for example, the apertures 253; are
carried by the setting sleeve means 223 and the other portion; such
as, the protrusions 255; are carried by a biased portion; such as,
collet fingers 257; of the tensile means 251. The biased portion is
biased for lateral movement so as to disengage the tensile means
from the setting sleeve means when not restrained. Specifically,
the collet fingers 257 are biased so as to move their ends and the
protrusions 255 inwardly to disengage the apertures 253. A
restraining means; such as, restraining ring 259; is disposed
adjacent the collet fingers 257 for maintaining connection with the
setting sleeve means until the swage means has passed completely
out of the annular body of the liner 13. The restaining ring 259 is
maintained in place by shear pin 260. A shoulder portion 261 on the
adapter rod 225 is moved downwardly to shear the shear pin 260 and
move the restaining ring 259 from beneath the ends of the collet
fingers 257 after the swage means 221 has moved downwardly out of
the end of the annular body of liner 13. Thus, as illustrated in
FIG. 20, the liner 13 may be left emplaced in tight frictional
engagement with the casing 21 and the setting sleeve means 223
connected with the top of liner 13. Space is provided below the
bottom of the annular body of the liner 13 so as to allow the swage
means 221 to pass completely out of the bottom of the annular body
while the reaction force is still being applied to the setting
sleeve means.
The tensile means 227, containing its collet fingers 257 and slots
247, connects the setting sleeve means 223 with an upper means 185
for connection with a bottom piston 31 of the piston assembly of
the setting tool device 11 for pulling upwardly on the setting
sleeve means 223 to oppose downward movement of the liner 13 as the
swage means 221 is pushed downwardly therethrough. The tensile
means 227 comprises a cylindrical member which is disposed
exteriorly radially of the adapter rod means 225 and is movable
longitudinally with respect thereto.
In operation, combination is assembled with the tensile means 227
and the setting sleeve means 223. connected with the bottom piston
31 of the setting tool device 11; whereas the bottom cylinder 43 of
setting tool device 11 is connected by the adapter means with the
adapter rod means 225 so as to push the swage means 221 downwardly
through the liner 13. The liner 13 is connected with the setting
sleeve means 223, which is connected by the detachable connectors
251 with the tensile means 227. With the assemblage complete, the
combination is lowered to the desired depth in the casing 21 of the
wellbore and the setting tool device 11 actuated. The bottom
cylinder 43 of setting tool device 11 will push the swage means 221
downwardly through the liner while the reaction force is being
supplied by the piston assembly of the setting tool device to pull
upwardly via the detachable connector means 251 on the setting
sleeve means 223. After a small amount of initial movement, the
liner 13 is expanded into tight frictional engagement with the
casing 21 to constrain the liner to the desired depth. Thereafter,
the force generated by the setting tool device 11 pushes the swage
means 221 downwardly through the liner 13 to complete the
emplacement by expanding the liner outwardly into tight frictional
engagement with the casing. After the liner is set by the swage
means 221 moving out of the lower end of the liner 13, the
releasing shoulder portion 261 moves downwardly to shear the shear
pin 260 and push the restraining ring 259 from under the collet
fingers 257. The collet fingers 257 spring inwardly, moving the
protrusions 255 out of the apertures 253 and releasing the tensile
means 227 from the setting sleeve means 233. Thereafter, the swage
means, the tensile means, and the setting tool device 11 are
removed from the well. To facilitate removal from the wellbore, as
the swage means 221 is moved upwardly through the liner, the
sectional ring 231 will be moved to effect a reduced diameter if it
encounters the set liner 13.
Except for the liner 13, the materials of construction of the
respective elements employed in the invention are well known to
those skilled in wire line operations and need not be described in
detail herein.
The setting sleeve means has been illustrated and described herein
as being primarily cylindrical in shape. It has been described in
detail in specific embodiments; such as, having expansible fingers
for allowing passage of the swage means therethrough, being
connected with the setting tool so that it is removed with the
setting tool, and being connected with the liner for being left in
the conduit with the set liner. The setting sleeve means may take
any other structure, or form, of setting means as long as it
provides the two functions described hereinbefore; namely, (1)
transmitting the reaction force from the force generating means to
the liner, and (2) allowing passage of the swage means completely
out of the end of the liner; thereby obviating the need for an
anchor means in setting the liner in the conduit.
Also, the liner 13 has been described as having interior and
exterior surfaces that define cylinders. The cylinders so defined
need not be perfect cylinders in the mathematical sense. It is
deemed within the scope of this invention if the interior and
exterior surfaces define cylinders having small irregularities, or
grooves, whether accidentally or deliberately induced, as long as
the irregularities are not as severe as the corrugations of the
prior art; and are not sufficient to produce the nonuniform
crystallographic structure or result in a tight frictional
engagement with the conduit that is unsatisfactory for the
application for which the liner is emplaced.
It is apparent from the foregoing drawings and description that the
invention accomplishes its objects of providing an improved method
of setting a liner in a conduit in a wellbore penetrating
subterranean formations, and providing combinations of apparatus
that:
1. employ a cylindrical liner,
2. do not depend upon a separate supplemental support, or anchor,
to hold the liner in place for setting in the conduit,
3. do not depend on an outside coating of resilient material for
sealing,
4. do not require additional pieces to be retained in the well to
retain the liner in place in the conduit,
5. are not limited to thin walled sections,
6. effect a more nearly uniform crystallo-graphic structure at the
metallurgical crystalline structure level without regions of low
yield strength caused by large flexure such as corrugations,
7. have a large smooth internal bore that forms a uniform internal
diameter for seating additional elements thereon,
8. may be emplaced at any point without being restricted to
joints,
9. are operable by means of a wire line without requiring an
additional string of pipe,
10. do not require a plurality of trips into the well to effect
passage of the swage means completely through the liner,
11. do not destroy equipment by an uncontained explosion in the
well; and
12. in a particular embodiment, leave a liner that is physically,
chemically, and electrochemically, compatible with the conduit in
the well and the job the liner is required to do.
Although the invention has been described with a certain degree of
particularity, it is understood 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 the invention.
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