U.S. patent number 3,744,563 [Application Number 05/300,927] was granted by the patent office on 1973-07-10 for retrievable well packer apparatus.
Invention is credited to Howard L. McGill.
United States Patent |
3,744,563 |
McGill |
July 10, 1973 |
RETRIEVABLE WELL PACKER APPARATUS
Abstract
In accordance with an illustrative embodiment of the present
invention, a retrievable well packer apparatus includes a mandrel
adapted for connection to a pipe string and carrying normally
retracted slips that can be expanded into anchoring engagement with
a well casing; a slip expander assembly on the mandrel below the
slips and movable upwardly to expand the slips, and
instrumentalities responsive to rotation of the mandrel by the pipe
string for mechanically retracting the slips so that the slips
cannot be accidentally set as the packer is being withdrawn from a
well.
Inventors: |
McGill; Howard L. (Houston,
TX) |
Family
ID: |
23161194 |
Appl.
No.: |
05/300,927 |
Filed: |
October 26, 1972 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
Issue Date |
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174598 |
Aug 25, 1971 |
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Current U.S.
Class: |
166/139; 166/134;
166/140 |
Current CPC
Class: |
E21B
33/1292 (20130101) |
Current International
Class: |
E21B
33/12 (20060101); E21B 33/129 (20060101); E21b
023/06 (); E21b 033/128 () |
Field of
Search: |
;166/138-140,134,216,217 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Brown; David H.
Parent Case Text
This application is a division of application Ser. No. 174,598,
filed Aug. 25, 1971.
Claims
I claim:
1. A well packer apparatus comprising: a body member adapted for
connection to a pipe string; normally retracted slip means on said
body member arranged to be expanded into anchoring engagement with
a well casing wall; upper expander means above said slip means and
lower expander means below said slip means, said lower expander
means being movable upwardly by said body member relatively toward
said upper expander means and said slip means to expand said slip
means; normally retracted packing means on said body member below
said lower expander means and adapted to be compressed and expanded
by movement of said body member upwardly relative to said slip
means and said lower expander means; means providing a slidable
spline connection between said slip means and said upper expander
means; means for limiting upward movement of said slip means along
said body member; and safetying means responsive to rotation of
said body member for causing said slidable spline connection to
effect a mechanical retraction of said slip means and to a
condition such that said lower expander cannot contact said slip
means during upward movement in a well bore.
2. The well packer apparatus of claim 1 wherein said safetying
means includes a sleeve structure connected to said upper expander
means, drag means to inhibit rotation of said sleeve structure in a
well bore, and control means having threaded connection to said
body member and outwardly directed shoulder extending into a
channel means in said sleeve structure, rotation of said body
member relative to said control means and said sleeve structure
causing said control means to feed upwardly along said body member
until said outwardly directed shoulder contacts an inwardly
directed shoulder on said sleeve structure, whereupon continued
rotation will feed said sleeve structure upwardly relative to said
slip means to cause said slidable spline connection to retract said
slip means.
3. The well packer apparatus of claim 2 wherein said channel means
extends generally longitudinally of said sleeve structure and
includes a transverse portion adapted to receive said outwardly
directed shoulder during downward movement of said apparatus in a
well bore.
Description
This invention relates generally to well packers used in well
bores, and more specifically to a well packer apparatus having new
and improved means for preventing inadvertent setting of the packer
as it is being retrieved to the surface after use.
Retrievable well packers commonly used for isolating well bore
zones are generally lowered into the well bore on a running-in
string of tubing or drill pipe. The packer has normally retracted
slips which can be expanded into engagement with the well casing to
anchor the tool at a preselected depth, as well as expansible
packing that functions when expanded to seal off the annulus
between the pipe string and the surrounding well conduit wall. When
it is desired to retrieve the tool, both the slips and the packing
can be retracted to positions enabling free running in the well
bore.
It is highly undesirable for the slips or the packing to be
accidentally operated while the tool is being moved through the
well casing because this may result in damage to the tool or to the
well casing or both. Particularly when retrieving the tool, such
premature operation may also result in damage to the running-in
string which is being pulled in tension at the surface. In any
event, it is desirable to have provision for disarming the well
packer so that it is not possible to accidentally operate the slips
or the packing as the tool is being withdrawn from the well
casing.
It is the principal object of the present invention to provide a
new and improved retrievable well packer apparatus having means for
positively preventing accidental operation of the tool as it is
being retrieved to the surface.
This and other objects are attained in accordance with the concepts
of the present invention through the provision of a well packer
apparatus including a body member which is adapted to be secured to
a running-in string and to be moved by the string in a well bore.
The body member carries normally retracted slips which can be
shifted outwardly into gripping contact with the well bore wall by
upper and lower expanders which are movable longitudinally on the
body member and relative to the slip means for shifting the slip
means outwardly. The upper expander has a slidable spline
connection to the slips. A lug sleeve threadedly secured to the
mandrel has lugs that engage in a channel system formed in a
control sleeve that is rigidly attached to the upper expander. The
lug sleeve occupies one position on the mandrel during lowering and
cooperates with the channel sytem to prevent setting until such
time as the mandrel is appropriately manipulated to enable such
setting. When it is desired to retrieve the well packer to the
surface, with the slips set the mandrel can be rotated to cause the
lug sleeve to feed upwardly to another position along the mandrel
where outwardly directed shoulders thereon engage downwardly facing
shoulders on the control sleeve. Further rotation causes the
control sleeve and upper expander to move relatively upwardly along
the mandrel to effect a mechanical retraction of the slips. When
mechanical retraction has occurred, it is impossible to set the
slips during upward movement so that the packer is completely
disarmed and can be retrieved to the surface without accidental
setting.
The present invention has other objects and advantages which will
become more clearly apparent in connection with the following
detailed description, taken in conjunction with the accompanying
drawings in which:
FIGS. 1A and 1B are longitudinal sectional views, with portions in
side elevation, of a well packer apparatus in accordance with this
invention, FIG. 1B forming a lower continuation of FIG. 1A;
FIG. 2 is a cross-section on line 2--2 of FIG. 1A;
FIG. 3 is a schematic plan view of a channel configuration which is
used to enable selective control over relative movement between
parts;
FIG. 4 is a cross-section taken on line of FIG. 1A;
FIGS. 5A and 5B are longitudinal sectional views similar to FIGS.
1A and 1B, except with the parts of the packer shown in the
relative positions they occupy when the packer is set in a well
casing; and
FIG. 6 is a view similar to FIG. 1A except showing the slips in
mechanically retracted condition.
Referring initially to FIGS. 1A and 1B, a well packer constructed
in accordance with the principles of the present invention includes
a tubular body member or mandrel 10 having a central passage 11
through which fluid can flow. A threaded collar 12 is provided at
the upper end of the mandrel 10 and is adapted to couple the
mandrel to the lower end of a running-in string of drill pipe or
tubing 13. The mandrel 10 carries, from top to bottom, an upper
drag assembly 15 that is coupled by a control sleeve 16 to an upper
expander 17 which is movable relatively toward a lower expander 18
in order to expand normally retracted slips 19 into gripping
contact with the well casing. The lower expander 18 is secured to
the upper end of a lower drag assembly 20. A packing structure 21
has normally retracted elements 22 which when expanded seal off the
cross-sectional area of the well bore between the mandrel 10 and
the surrounding well casing wall. The slips 19 function to prevent
longitudinal movement in either direction in the well casing, and
the packing 21 prevents fluid flow in either longitudinal direction
past its sealing point, so that the well zone below the packer is
isolated from the well fluids thereabove.
The upper drag assembly 15 includes an annular cage member 24
having a gauge ring 25 secured by bolts or the like to its upper
end. The cage member 24 has a plurality of radially directed,
circumferentially spaced recesses 26, each of which receives a drag
block 27. Each drag block 27 is urged outwardly by springs 28
having one end engaged within a recess 29 in the drag block and the
other end pressing against the back surface of a respective recess.
Stop shoulders 30 at each end of each drag block 27 limit outward
movement thereof with respect to the cage member 24. The control
sleeve 16 is threadedly secured to the lower end of the cage member
24 by an annular cap 32, and the lower end of the control sleeve 16
is threadedly secured to the upper expander 17. Formed through the
wall of the control sleeve 16 at diagonally opposed positions is a
channel configuration 33 shown in plan view in FIG. 3. Each channel
has a transverse pocket 34 in its lower end that is connected by a
short vertical portion 35 to an intermediate transverse portion 36.
The portion 36 connects with a lengthy vertical portion 37. The
generally stepped formation of the channel 33 provides two
circumferentially spaced, axially facing shoulders 38 and 39. Each
channel is adapted to receive a lug 40 formed by an outwardly
directed shoulder on a lug sleeve 41 that is secured to the mandrel
10 by companion jack threads 42 and 43. As shown in FIG. 1A, the
lug sleeve 41 normally occupies a lower position on the mandrel 10
and is made up tightly at the lower end portion of the threads 42.
If desired, a compression coil spring 44 can be positioned between
the lower end of the lug sleeve 41 and an outwardly directed
shoulder 45 on the mandrel 10 in order to provide an axial load on
the threads and thereby inhibit turning motion of the lug sleeve in
response to low torque values. As shown in FIG. 2, two
diametrically opposed lugs 40 are used although it will be
appreciated that at least one is required and that more than two
can be used. An outer barrier sleeve 46 can be positioned over the
control sleeve 16 to prevent entry of particles of foreign matter
that may be in the well fluids into the channels 33.
The slip assembly 19 is constituted by a plurality of
circumferentially spaced individual slip elements 50 that are
slidably coupled to the upper expander 17 and are mounted on the
mandrel 10 for both longitudinal and lateral movement relative
thereto. Each slip element 50 has peripheral wickers or teeth 51
which can bite into and grip the well casing in order to prevent
movement in either direction therein, and also has upper and lower
inclined surfaces 52 and 53 that are adpated to slidably engage
companion inclined surfaces 54 and 55 on the upper and lower
expanders 17 and 18, respectively. The slip elements 50 are mounted
on a ring member 54 which is relatively slidable on the mandrel 10
below an annular stop shoulder 55. The ring member 54 can be an
integral piece as shown in cross-section in FIG. 4, or can be
formed in segments secured together by threaded studs. In any
event, the ring member 54 has circumferentially spaced, radially
directed recesses 56, each of which receives a central portion 57
of a respective slip element to provide a lateral guide therefor.
As previously noted, the ring member 54 can slide downwardly
relative to the mandrel 10, however upward movement is limited by
the downwardly facing stop shoulder 55. Each slip element 50 is
coupled to the upper expander 17 through a "dove tail" sliding
connection that can be formed, for example, by keys 58 that are
suitably secured to the upper expander 17 by studs, each key
slidably fitting within a slot 59 in a respective one of the slip
elements.
The lower drag assembly 20 is formed by a cage member 61 having a
plurality of circumferentially disposed, radially extending
recesses 62, each of which receives a drag block 63. The drag
blocks are urged outwardly by coil springs 64 in the same manner as
discussed above with respect to the upper drag assembly 15. Upward
movement of the lower drag assembly 20 is limited by engagement
between an upwardly facing shoulder 65 on a gauge ring 66 that is
attached to the lower end of the cage member with a downwardly
facing shoulder 67 formed by an annular enlargement on the mandrel
10.
The packing structure 21 includes an annular compression sleeve 70
which is threaded to the upper end of a bottom sub 71 which is in
turn threadedly fixed to the lower end of the mandrel 10. The
compression sleeve 70 carries the annular packing elements 22
constructed of a suitable elastomeric material. The lower packing
ring is engaged by an upwardly facing lower abutment 72, whereas
the upper ring is engaged by a downwardly facing upper abutment 73
which is slidable relatively along the compression sleeve 70. The
upper abutment 73 is secured to a spline collar 74 having an
inwardly thickened piston section 75 at its upper end which is
sealed with respect to the mandrel 10 by an O-ring 76 or the like.
The upper abutment 73 is also sealed with respect to the
compression sleeve 70 through use of an O-ring 77. The inner wall
surface of the compression sleeve 70 is spaced laterally with
respect to the outer wall surface of the mandrel 10 to provide a
fluid passage space 78 in communication with the well annulus below
the packing by one or more ports 79 through the wall of the bottom
sub 71. Thus, it will be appreciated that the pressure of fluids in
the well bore below the packing is communicated by the ports 79 and
the annular passage space 78 into a chamber 80 located interiorly
of the spline collar 74 for purposes to be more fully described
hereafter.
To prevent relative rotation between various parts of the packer,
the upper end portion of the compression sleeve 70 has splines 82
which slidably engage in companion spline grooves 83 formed in the
collar 74. Moreover, the upper end of the spline collar 74 is
provided with a plurality of upwardly extending clutch pins 84
which engage like clutch pins 85 on the lower end of the gauge ring
66 when the parts are slidably disposed in engagement with each
other. In engaged condition, the spline collar 74 cannot rotate
with respect to the compression sleeve 70, nor can the lower drag
assembly 20 rotate with respect to the spline collar 74.
In operation of the structure described above, it will be apparent
that the assembled tool can be connected to the lower end of the
pipe string 13 and pushed downwardly along the well casing to
setting depth as additional joints of pipe string are added in
end-to-end relation. The lower drag blocks 63 slide along the well
casing, and the coengaged shoulders 65 and 67 on the mandrel 10 and
the cage member 61 maintain the lower expander 18 in spaced
relation to the slip elements 50. The upper drag blocks 27 are also
sliding along the casing wall as the downward movement of the
mandrel 10 is being transmitted thereto by engagement of the lugs
40 in the lower transverse pockets 34 of the channels 33. The slip
elements 50 are being held in retracted positions by their sliding
connection with the upper expander 17, together with engagement of
the mounting ring 54 underneath the mandrel shoulder 55. Of course,
the packing rings 22 are in their inherently retracted positions so
that well fluids can pass between the rings in the well casing
wall.
When it is desired to set the packer, the tool is halted and
right-hand torque coupled with an upward strain applied to the pipe
string 13 will position the lugs 40 within the elongated vertical
portions 37 of the channels 33. As previously described, the drag
blocks 27 function to prevent movement of the upper cage member 24,
the control sleeve 16 and the upper expander 17. As the mandrel 10
is pulled upwardly, the packing structure 21 is elevated until the
upper end of the spline collar 74 engages the lower end of the
lower drag assembly 20, whereupon the packing structure and the
lower expander 18 are jointly elevated toward the slip elements 50.
This results in outward shifting of the slip elements 50 until
their teeth 51 bite into and grip the well casing wall. Then the
upper abutment 73 cannot move any further upwardly, whereby
continued upward movement of the mandrel 10 telescopes the
compression sleeve 70 upwardly within the upper abutment 73 and
effects compression and lateral expansion of the packing rings 22
until their outer peripheries seal against the well casing wall. A
predetermined amount of upward strain is maintained on the pipe
string 13 at the earth's surface in order to maintain the tool in
set condition within the casing 88 as shown in FIGS. 5A and 5B.
It should be specifically noted at this point that both of the
expander members 17 and 18 are engaging the slip elements 50. This
engaged relation will be maintained during the operation of the
packer and until it is desired to release the tool for retrieval
from the well. With the slip elements 50 set and the packing
elements 22 expanded, the well bore below the tool can be
pressurized as desired and the slip elements will prevent upward
movement while the packing rings seal off the well annulus.
Should a sufficiently high pressure exist in the annulus above the
packer, the packing structure 21 and the mandrel 10 can shift
downwardly to a limited extent in the casing, such limited shifting
being accompanied by stretching of the pipe string. However, the
slip elements 50 remain in anchoring position and engaged by both
expander members 17 and 18. Downward movement of the mandrel 10
will bring the lugs 40 against the shoulder surfaces 38, whereupon
downward force on the mandrel 10 is imposed by the upper expander
member 17 on the slip elements 50 which prevent further downward
movement.
During this movement, the packing rings 22 merely slide downwardly
along the casing 88 in expanded condition and remain sealed there
against. This will occur because the lesser fluid pressure is
acting on the lower face 89 of the piston section 75, while the
greater pressure is acting on the upper face 90 thereof, the
pressure differential acts on the piston area as downward force
which is applied to the upper end of the packing rings 22 by the
upper abutment 73. It will be remembered that upward strain is
still being exerted on the pipe string 13 so that compressive force
is being applied continuously to the lower end of the packing rings
by the lower abutment 72. Accordingly, since compressive force is
being exerted on both ends of the packing rings 22, they will not
retract but will slide downwardly along the casing wall in expanded
and sealing condition. The actual extent of downward shifting of
the mandrel 10 and the packing assembly 21 is actually quite short
compared to prior art devices of this general type, and may be only
two or three inches.
If the pressure in the annulus above the packer is reduced, of
course tension is still being held on the pipe string 13 and the
string can contract and shift the packing assembly 21 and the
mandrel 10 back upwardly to their original position with the upper
and lower expanders 17 and 18 cooperating with the slip elements 50
to prevent further upward movement. In fact as long as tension is
held on the pipe string 13, the packing structure 21 and the
mandrel 10 can shift back and forth and it will be appreciated that
the well bore remain sealed off to prevent any fluild movement past
the tool. Moreover, the slip elements 50 remain anchored against
the well casing wall and remain supported in anchored position by
both the upper and lower expander members in simultaneous
engagement therewith.
To unset the tool, pressures above and below the packer are
equalized by operation of a suitable bypass valve (not shown) as
upward strain on the pipe string 13 is relieved and as the mandrel
10 is moved downwardly by lowering the pipe string. This relieves
the compressive force on the packing rings 22 so that they can
inherently retract. The mandrel shoulder 67 will engage the cage
shoulder 65 to push the lower expander 18 out from behind the slip
elements 50. The lugs 40 are manipulated back into the lower
transverse pockets 34 of the channels 33 to lock the upper expander
17 and the upper drag assembly 15 in their upper positions on the
mandrel 10. Then an upward pull on the pipe string 13 will lift the
upper expander 17 and cause the slips 50 to shift inwardly along
the inclined surfaces of the expander to their retracted positions,
whereupon the tool is free to be moved upwardly or downwardly
within the casing 88.
As previously discussed, it is often times desirable to be able to
"safety" the tool during removal thereof from the well. In other
words, some operators may desire to completely disarm the tool
immediately before retrieving it so that it is impossible to again
set the slips and the packing in the well bore. One typical
circumstance where this is particularly desirable is where the pipe
string is "rotated" out of the hole. This is a procedure wherein
the rotary table is used to break and back off pipe joints at the
surface. Since the pipe is being rotated a substantial number of
turns to the right (the direction that is normally used to
condition the tool for setting) there would normally be a
substantial risk to accidental setting. To prevent accidental
setting in accordance with the principles of the present invention
the structure previously described can be operated as follows. With
the slips 50 set against the casing, a certain amount of weight,
for example, 3,000-5,000 lbs., is slacked off onto the tool and the
pipe string 13 is rotated to the right. With the tool set the lugs
40 are in the elongated portions 37 of the channels 33 shown in
FIG. 3. Since the upper drag assembly 15 and the temporarily set
condition of the slips 50 prevents rotation of the control sleeve
16 within the casing, rotation of the mandrel 10 will cause the
lugs sleeve 41 to feed relatively upwardly along the mandrel 10
until the upper end surface 92 thereof comes against the downwardly
facing shoulder 93 provided by the lower end of the cage member 24.
When this has occurred, further rotation moves the lugs sleeve 41
upwardly and the mandrel 10 downwardly with corresponding movement
of expander 17 and the slips 50. Since the slips can move upwardly
only as limited by the shoulder 55, the "dove tail" connections 58,
59 effect a retraction of the slips as shown in FIG. 6. Actually
the ships 50 are only set for a brief period of time for the
purpose of preventing rotation of the upper expander 17 (since
these two members have a spline connection), during which time a
fairly high torque may be applied to the threaded connection 42, 43
between the lug sleeve 40 and the mandrel 10 to initiate upward
feeding of the lug sleeve along the mandrel. Once the lug sleeve 40
starts its upward travel along the mandrel 10 however, the torque
requirements are substantially lessened and the lug sleeve will
feed freely along the mandrel until it comes into engagement with
the shoulder 93 and causes the control sleeve 16 to move upwardly,
drawing the upper expander 17 upwardly therewith. With the slips 50
mechanically retracted as discussed above, the tool cannot again be
set on this trip into the well and the operator can pull the tool
from the well as fast as he desires, and can rotate the pipe string
13 freely, without fear that the tool will, by some fortuitous
circumstance, accidentally hang up and set in the casing.
In accordance with an additional safety feature, the thread 95
which joins the bottom sub 71 to the lower end of the mandrel 10
can be formed on a left-hand helix. It is thus possible to
manipulate the packer as previously discussed in order to effect a
setting thereof with the pipe string in tension, and then rotate
the pipe string to the right. Since the compression sleeve 70 and
the spline collar 74 are corotatively coupled, as are the spline
collar 74 and the lower drag assembly 20, the slips 50 serve to
frictionally hold the various members against rotation in the
casing 88, and the right-hand rotation will effect unthreading of
the thread 95 between the mandrel and the bottom sub. When such
unthreading has occurred, it is possible to remove the mandrel 10
and all parts of the well packer above the lower expander member 18
from the well, leaving the balance of the parts behind for
subsequent retrieval by a fishing operation with typical
equipment.
It will be appreciated that the entire tool shown in the drawings
could be inverted or turned upside down and then run into the well
bore, in which case the tool could be set in compression by pipe
weight if desired. Also, of course the rotational directions for
setting and unsetting movement applied to the pipe string at the
suface are a function of the configuration of the slot system,
which can be arranged for right-hand or left-hand torque as
desired.
It will now be apparent that the present invention provides a new
and improved retrievable well packer apparatus which can be set in
packed off condition against longitudinal movement in a well bore,
and includes structure for disarming the slips so that it is
impossible to set the slips and the packing during retrieval of the
packer from the well bore. Since certain changes or modifications
may be made by those skilled in the art without departing from the
inventive concepts involved, it is the aim of the appended claims
to cover all such changes or modifications falling within the true
spirit and scope of the present invention.
* * * * *