U.S. patent application number 14/946526 was filed with the patent office on 2017-05-25 for downhole tool having slips set by stacked rings.
The applicant listed for this patent is WEATHERFORD TECHNOLOGY HOLDINGS, LLC. Invention is credited to Candido Castro, Brian J. Ritchey.
Application Number | 20170145780 14/946526 |
Document ID | / |
Family ID | 56014568 |
Filed Date | 2017-05-25 |
United States Patent
Application |
20170145780 |
Kind Code |
A1 |
Castro; Candido ; et
al. |
May 25, 2017 |
Downhole Tool having Slips Set by Stacked Rings
Abstract
An apparatus installs downhole in a surrounding tubular. A first
shoulder on a mandrel of the apparatus is movable toward a second
shoulder. A plurality of stacked rings are disposed about the
mandrel and are spaced between the first and second shoulders. A
first of the stacked rings decreases in spacing in response to the
movement of the first shoulder toward the second shoulder, and a
second of the stacked rings expands outward from the mandrel in
response to the decrease in spacing. A slip disposed on the stacked
rings is movable away from the mandrel toward the surrounding
tubular in response to the outward expansion. The apparatus can be
a plug, a bridge plug, a fracture plug, a packer, a permanent
packer, a retrievable packer, a sump packer, and a sealbore packer.
Additionally, the apparatus can include a completion assembly with
packer and screen supported on the mandrel.
Inventors: |
Castro; Candido; (Houston,
TX) ; Ritchey; Brian J.; (Hockley, TX) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
WEATHERFORD TECHNOLOGY HOLDINGS, LLC |
Houston |
TX |
US |
|
|
Family ID: |
56014568 |
Appl. No.: |
14/946526 |
Filed: |
November 19, 2015 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/129 20130101;
E21B 33/1291 20130101; E21B 33/128 20130101; E21B 33/1293 20130101;
E21B 23/01 20130101; E21B 33/134 20130101 |
International
Class: |
E21B 33/129 20060101
E21B033/129; E21B 23/01 20060101 E21B023/01 |
Claims
1. An apparatus installing downhole in a surrounding tubular, the
apparatus comprising: a mandrel; first and second shoulders
disposed on the mandrel, at least the first shoulder being movable
toward the second shoulder; a plurality of stacked rings disposed
about the mandrel and spaced between the first and second
shoulders, a first of the stacked rings decreasing in spacing in
response to the movement of the first shoulder toward the second
shoulder, a second of the stacked rings expanding outward from the
mandrel in response to the decrease in spacing; and a slip disposed
on the stacked rings, the slip being movable away from the mandrel
toward the surrounding tubular in response to the outward
expansion.
2. The apparatus of claim 1, wherein the apparatus is selected from
the group consisting of a plug, a bridge plug, a fracture plug, a
packer, a permanent packer, a retrievable packer, a sump packer,
and a sealbore packer.
3. The apparatus of claim 1, wherein the slip comprises an outer
surface having wickers engageable with the surrounding tubular.
4. The apparatus of claim 1, wherein the slip comprises a plurality
of segments being arranged longitudinally relative to the mandrel
and being disposed about the stacked rings.
5. The apparatus of claim 1, wherein the first shoulder comprises a
drive sleeve disposed on the mandrel and movable thereon.
6. The apparatus of claim 5, further comprising a lock disposed
between the drive sleeve and the mandrel, the lock permitting
movement of the drive sleeve toward the second shoulder and
preventing reverse movement of the drive sleeve away from the
second shoulder.
7. The apparatus of claim 1, wherein the second opposing comprises
a sleeve fixed on the mandrel.
8. The apparatus of claim 1, wherein the second of the stacked
rings is spaced in between the first of the stacked rings, the
second of stacked rings expanding outward from the mandrel in
response to the decrease in spacing of the first of the stacked
rings.
9. The apparatus of claim 8, wherein the slip is disposed about at
least the second of the stacked rings, the slip being movable away
from the mandrel toward the surrounding tubular in response to the
outward expansion of the second of the stacked rings.
10. The apparatus of claim 1, wherein the first of the stacked
rings comprises at least one first ramped edge against which the
second of the stacked rings adjacent thereto wedges.
11. The apparatus of claim 10, wherein the second of the stacked
rings comprises at least one second ramped edge wedging against the
at least one first ramped edge of the first of the stacked rings
adjacent thereto.
12. The apparatus of claim 1, wherein the stacked rings comprises
at least one of a split ring element defining a split; a segmented
ring element having a plurality of segments; a full ring element
defining a full circumference; an individual ring element disposed
about the mandrel; a strip coiled about a portion of the mandrel; a
compressible material; and a rigid material.
13. The apparatus of claim 1, wherein the stacked rings comprise
first and second outer rings each having a third shoulder disposed
adjacent one of the first and second shoulders disposed on the
mandrel.
14. The apparatus of claim 1, wherein the slip comprises a central
tab disposed on an inner surface of the slip toward the mandrel,
and wherein the stacked rings comprise first and second inner rings
each having a third shoulder disposed adjacent a side of the
central tab.
15. The apparatus of claim 1, wherein the first shoulder comprises
a catch at least temporarily holding an end of the slip.
16. The apparatus of claim 1, wherein the stacked rings have
different spacings between one another, whereby the second of the
stacked rings at one of the first and second shoulders expands
outward before the second of the stacked rings at the other of the
first and second shoulder.
17. The apparatus of claim 1, wherein the stacked rings have
different contact angles disposed adjacent one another, whereby the
second of the stacked rings expands outward at one of the first and
second shoulders before the second of the stacked rings at the
other of the first and second shoulder.
18. The apparatus of claim 1, further comprising: a packing element
disposed on the mandrel adjacent the first shoulder; and a setting
sleeve disposed on the mandrel adjacent the packing element, the
setting sleeve movable on the mandrel toward the first shoulder and
expanding the packing element outward toward the surrounding
tubular.
19. The apparatus of claim 1, further comprising a completion
assembly installing in the surrounding tubular and having a distal
end supported by the mandrel of the apparatus.
20. The apparatus of claim 19, wherein at least one of: the distal
end engages in a throughbore defined in the mandrel; the distal end
comprises a seal sealing in a throughbore of the mandrel; the
distal end comprises a latch latching to the mandrel; and the
distal end comprises a bull plug.
21. The apparatus of claim 19, wherein the completion assembly
comprises: a packer disposed toward a proximal end of the
completion assembly; and a screen disposed on the assembly between
the packer and the distal end.
22. A method of installing an apparatus downhole in a surrounding
tubular, the method comprising: deploying the apparatus in the
surrounding tubular; moving at least a first shoulder disposed on
the apparatus toward a second shoulder disposed on the apparatus;
decreasing spacing of first of a plurality of stacked rings
disposed on the apparatus between the first and second shoulders in
response to the movement; expanding second of the stacked rings
outward from the apparatus in response to the decrease in spacing;
and engaging a slip disposed on the stacked rings toward the
surrounding tubular in response to the outward expansion.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of U.S. Provisional
Appl. 62/081,753, filed 19 Nov. 2014, which is incorporated herein
by reference.
TECHNICAL FIELD
[0002] The present disclosure relates to the field of downhole
tools, and in particular to downhole tools, such as bridge plugs,
frac-plugs, and packers.
BACKGROUND ART
[0003] An oil or gas well includes a wellbore extending into a well
to some depth below the surface. Typically, the wellbore is lined
with tubulars or casing to strengthen the walls of the borehole. To
strengthen the walls of the borehole further, the annular area
formed between the casing and the borehole is typically filled with
cement to set the casing permanently in the wellbore. Perforating
the casing then allows production fluid to enter the wellbore and
flow to the surface of the well.
[0004] Downhole tools with sealing elements, such as plugs or
packers, are placed within the wellbore to isolate the production
fluid or to manage production fluid flow through the well. For
example, a bridge plug or a fracture plug placed within the
wellbore can isolate upper and lower sections of production zones.
Bridge plugs and frac-plugs create a pressure seal in the wellbore
to allow pressurized fluids or solids to treat an isolated
formation.
[0005] For their part, packers are typically used to seal an
annular area formed between two co-axially disposed tubulars within
a wellbore. For example, packers may seal an annulus formed between
production tubing disposed within wellbore casing. Alternatively,
packers may seal an annulus between the outside of a tubular and an
unlined borehole. Routine uses of packers include the protection of
casing from pressure, both well and stimulation pressures, as well
as the protection of the wellbore casing from corrosive fluids.
Other common uses include the isolation of formations or leaks
within a wellbore casing or multiple producing zones, thereby
preventing the migration of fluid between zones. Packers may also
be used to hold kill fluids or treating fluids within the casing
annulus.
[0006] These types of downhole tools are usually constructed of
cast iron, aluminum, or other alloyed metals, but can be made of
non-metallic materials, such as composite materials. A sealing
member is typically made of a composite or synthetic rubber
malleable material that seals off an annulus within the wellbore to
prevent the passage of fluids. When the tool is activated, the
sealing member is compressed or swells, thereby expanding radially
outward from the tool to engage and seal with a surrounding casing
or tubular. Conventional bridge plugs, fracture plugs, and packers
typically comprise a synthetic sealing member located between upper
and lower metallic retaining rings, commonly known as slips, that
prevent the downhole tool from moving up or down in the
wellbore.
[0007] As noted above, one type of downhole tool is a bridge plug,
such as shown in a cutaway view in FIG. 1A. The bridge plug 10 has
a mandrel 12, about which are disposed various elements typically
formed of metal, but can be made of a composite material, such as
is described in U.S. Pat. No. 7,124,831. Even when most of the
bridge plug 10 is made of composite materials, the two slips 20a-b
may be made of metal, such as a ductile cast iron.
[0008] As shown, a sealing member 38 and other related elements
30a-b are disposed about the mandrel 12. Axial force through the
slips 20a-b and the other elements 30a-b compress the sealing
member 38, causing it to expand and to seal with the surrounding
tubular (not shown). The two slips 20a-b, oriented opposite to each
other, expand to engage with the surrounding tubular and help
retain the downhole tool 10 in place. Boost forces from the sealing
member 38 on the slips 20a-b increase their holding ability.
[0009] The sealing elements 30a-b each include a cone 32 and
anti-extrusion rings 34. When pushed by the push ring 18 in the
setting procedures, the first slip 20a rides up the cone 32 to be
wedged out against the surrounding tubular. At the same time, the
slip 20a and cone 32 are pushed along the mandrel 12 against the
anti-extrusion rings 34 and the sealing element 38. On the opposite
end, the second slip 20b similarly rides up its cone 32 as the
elements 30a-b are pushed against the mule shoe 16 on the end of
the mandrel 12.
[0010] Another downhole tool 10, such as a bridge plug, is shown in
a cutaway view in FIG. 1B. This tool 10 uses a single
bi-directional slip 20. Instead of confining a single sealing
member with two slips, this single slip 20 is confined by two
sealing systems 40a-b.
[0011] As before, the downhole tool 10 uses a mandrel 12 having the
remainder of the downhole tool 10 disposed about the mandrel 12.
The single bi-directional slip 20 resists movement in either axial
direction once activated by the sealing systems 40a-b to engage
with the surrounding tubular.
[0012] To provide sealing with the surrounding tubular, the
downhole tool 10 uses the two sealing systems 40a-b, one axially on
either end of the slip 20. Each sealing system 40a-b, in addition
to sealing the downhole tool 10 with the surrounding tubular, also
provides boost forces to the slip 20, increasing its ability to
engage with the tubular and hold the downhole tool 10 in place
under high pressure.
[0013] Each sealing system 40a-b includes a sealing member 48,
which is a malleable, synthetic element. In addition to the sealing
member 48, each sealing system 40a-b has a cone 42 and two sets of
anti-extrusion rings 44. Axial force is applied to the sealing
systems 40a-b and slip 20 using a setting tool (not shown) in a
manner similar to that discussed above.
[0014] Another type of downhole tool is a sump packer, which is
used to locate the bottom of a screen assembly in a sand control or
gravel pack completion. For example, FIG. 2 shows a typical gravel
pack completion 50 having a sump packer 70 used for this purpose.
Although the sump packer 70 can be used, other packers or plugs
(e.g., bridge plug or cement plug) can be used.
[0015] In the cased hole C, the sump packer 70 is installed as a
base for the gravel pack completion 50. The sump packer 70 can be
run into the well on electric wireline prior to perforating the
casing C. When set, the sump packer 70 positions at a point below
the lowest planned perforation P. Typically, the sump packer 70 is
a permanent seal bore type of packer, such as Weatherford's
UltraPak Sump Packer or the Baker Model "D" or "F" Retainer
Production Packer, although a retrievable sealbore packer could be
used.
[0016] The sump packer 70 provides access to the bottom of the well
C, which can act as a sump for debris left or dropped in the hole.
The sump packer 70 also allows logging tools to be run below the
producing interval.
[0017] The cased-hole gravel pack completion 50 has a retrievable
sealbore packer 56 with a gravel pack extension 52, a crossover
tool 55, and screen(s) 54 extending therefrom. The completion 50 is
deployed into the cased well that has been perforated into the
production zone, and the completion 50 at its distal end has a
snap-latch assembly 60 that seals into the sump packer 70. The
snap-latch assembly 60 provides a surface indication that the
gravel pack completion 50 is properly located in the sump packer
70. With the completion 50 in place, the upper packer 56 is set,
and the crossover tool 55 is manipulated to its various positions
to pump the gravel as well as any other treatments. From that
point, a tubing string T can install in the upper packer 56 to
create a path for production fluid. Then, any of the other desired
completion and production operations can be performed.
[0018] FIG. 2B shows an example of a sump packer 70 according to
the prior art. The sump packer 70 includes a mandrel 72 having a
polished bore 74. Inside the mandrel 72, the top of the bore 74
defines a locating shoulder and square thread 78. At the other end,
lower slips 84a rest against the mandrel 72 between a lower setting
element 85b and the mandrel's distal nose 76. In an opposing
manner, upper slips 84b rest against the mandrel 72 between an
upper setting element 85a and a setting sleeve 80 having a body
lock ring 82. Between the setting elements 85a-b is a packing
element 90 disposed about the mandrel 72 to be compressed
therebetween.
[0019] When the snap-latch assembly 60 as shown in FIG. 2C is
inserted into the sump packer 70 (FIG. 2B), the assembly's end 66
seals inside the polished bore 74, latches 68 engage in the square
thread 78, and the upper ledge engages the locating shoulder. The
latches 68 have threaded fingers that collapse inward as the
assembly 60 contacts the top of the sump packer 70. When the
assembly 60 is fully lowered into the sump packer 70, the threaded
fingers on the latches 68 expand and engage the left-hand square
threads 78 in the top of the sump packer 70. About 2,000 pounds of
set down weight may be required to snap into the packer 70, and
about 8,000 to 12,000 pounds may be required to snap out.
[0020] In the setting process, the setting sleeve 80 on the sump
packer 70 is then activated and moves downhole, while the body lock
ring 82 prevents reverse movement. The setting assembly of the sump
packer 70 is compressed by the slips 84a-b riding up the ramps of
the setting elements' cones 86a-b and by the packing element 90
compressing between the setting elements 85a-b and expanding
outward to the casing. The setting elements 85a-b can include
anti-extrusion elements 88a-b to limit the extrusion of the packing
element 90 in the space between the setting elements 85a-b and the
surrounding casing. This can help assure a good seal in the
annulus.
[0021] As can be seen above, downhole tools, such as packers,
plugs, etc., can use a number of different elements systems having
slips, setting elements (i.e., cones, anti-extrusion rings, etc.),
and packing elements. In one continuing problem associated with
conventional element systems of these types of downhole tools, the
cones of the element systems can collapse. This can occur, for
example, on both permanent and retrievable tools, such as packers.
There is also a continuing desire to increase the contact area
between the slips and cones of the element systems or at least to
further distribute the cone-to-slip load over a larger area.
[0022] Attempts to design a convention downhole tool, such as a
packer, capable of handling 10,000-psi or greater cone collapse
pressure have been made, and testing has proven these attempts to
be unsuccessful. One issue that prevents increased cone collapse
pressures one conventional downhole tools is the limitations in the
contact area between the slips and the cones when set into the
tubular or casing. In some implementations, only a thin annular
area exists between the downhole tool and the surrounding tubular
that limits how much contact the cone can have to the slip.
[0023] Historically, the problem of increasing the cone collapse
pressure has been solved by simply increasing the material strength
of the components. Additionally, different slip configurations have
been used, such as Halliburton's "barrel" slips, Baker Hughes'
tangential slips or wedge slips, or Petrowell's multi-ramp slips.
Some examples of different slip configurations are disclosed in
U.S. Pat. Nos. 4,311,196; 5,884,699; 5,944,102; 6,302,217;
7,614,449; 7,690,424; and 8,567,510.
[0024] The subject matter of the present disclosure is directed to
overcoming, or at least reducing the effects of, one or more of the
problems set forth above.
SUMMARY OF THE DISCLOSURE
[0025] According to the present disclosure, an apparatus installs
in a surrounding tubular. The apparatus has a mandrel, first and
second opposing shoulders, a plurality of stacked rings, and a
slip. The first and second opposing shoulders are disposed on the
mandrel. At least the first opposing shoulders is movable toward
the second opposing shoulder. The plurality of stacked rings are
disposed about the mandrel and are spaced between the first and
second opposing shoulders. First of the stacked rings decrease in
spacing in response to the movement of the first opposing shoulder
toward the second opposing shoulder, and second of the stacked
rings expand outward from the mandrel in response to the decrease
in spacing. The slip is disposed about the stacked rings and moves
away from the mandrel toward the surrounding tubular in response to
the outward expansion.
[0026] The slip can have a number of configurations as disclosed
herein. The slip can have an outer surface with wickers for
engaging the surrounding tubular. The slip can include a plurality
of segments longitudinally arranged relative to the mandrel and
disposed about the stacked rings.
[0027] A drive sleeve disposed on the mandrel move the first
shoulder. A lock disposed between the drive sleeve and the mandrel
can permit movement of the drive sleeve toward the second shoulder,
but prevents reverse movement of the drive sleeve. The first
shoulder can have a catch at least temporarily holding an end of
the slip. For its part, the second shoulder can be a sleeve fixed
on the mandrel.
[0028] The second of the stacked rings can be spaced between the
first of the stacked rings. The first of the stacked rings can have
at least one first ramped edge against which the second of the
stacked rings adjacent thereto wedges. The second of the stacked
rings can have at least one second ramped edge wedging against the
at least one first ramped edge of the first of the stacked rings
adjacent thereto.
[0029] The stacked rings can have a number of configurations, as
disclosed herein. The stacked rings can be a full ring element
defining a full circumference, a split ring element defining a
split, a segmented ring element having a plurality of segments, and
the like. Each of the stacked rings can be an individual ring
element disposed about the mandrel. Alternatively, each of the
stacked rings can be a strip coiled about a portion of the
mandrel.
[0030] The stacked rings can include first and second outer rings
each having a shoulder disposed adjacent one of the first and
second shoulders disposed on the mandrel. The slip can have a
central tab on an inner surface disposed toward the mandrel. The
stacked rings in this case can include first and second inner rings
each having a shoulder disposed adjacent a side of the central
tab.
[0031] The spacings in between the stacked rings can expand the
second of the stacked rings outward at one of the opposing
shoulders before the other opposing shoulder. Also, the stacked
rings can have contact angles disposed adjacent one another, and
the contact angles can expand the second of the stacked rings
outward at one of the opposing shoulders before the other opposing
shoulder.
[0032] The apparatus can be a plug, a bridge plug, a fracture plug,
a packer, a permanent packer, a retrievable packer, a sump packer,
and a sealbore packer. According to the present disclosure, a
setting sleeve disposed on the mandrel can compress against a
packing element to expand outward toward the surrounding
tubular.
[0033] According to the present disclosure, the apparatus disclosed
above can further include a completion assembly that installs in
the surrounding tubular. A distal end of the completion assembly is
supported by the mandrel of the apparatus. In one example, the
mandrel defines a throughbore, and the distal end of the completion
assembly engages in the throughbore. A latch tool on the distal end
can seal in the throughbore of the mandrel and can latching to the
mandrel. In another example, the completion assembly can have a
bull plug on the distal end. The completion assembly can include a
packer disposed at a proximal end, an extension extending from the
packer, and a screen disposed on the extension.
[0034] Methods of deploying and setting the apparatus disclosed
above can involve deploying the apparatus in the surrounding
tubular; and moving at least a first opposing shoulders disposed on
the apparatus toward a second opposing shoulder disposed on the
apparatus. The method decreases spacing of first of a plurality of
stacked rings disposed on the apparatus between the first and
second opposing shoulders in response to the movement and expands
second of the stacked rings outward from the apparatus in response
to the decrease in spacing. A slip disposed about the stacked rings
engages toward the surrounding tubular in response to the outward
expansion.
[0035] The foregoing summary is not intended to summarize each
potential embodiment or every aspect of the present disclosure.
BRIEF DESCRIPTION OF DRAWINGS
[0036] The accompanying drawings, which are incorporated in and
constitute a part of this specification, illustrate an
implementation of apparatus and methods consistent with the present
invention and, together with the detailed description, serve to
explain advantages and principles consistent with the disclosed
subject matter. In the drawings,
[0037] FIG. 1A illustrates a partial cross-sectional view of a
bridge plug according to the prior art;
[0038] FIG. 1B illustrates a partial cross-sectional view of
another bridge plug according to the prior art;
[0039] FIG. 2A illustrates a cased-hole gravel pack completion
according to the prior art;
[0040] FIG. 2B illustrates a sump packer according to the prior art
in partial cross-section;
[0041] FIG. 2C illustrates a snap-latch tool according to the prior
art in partial cross-section;
[0042] FIGS. 3A-3B illustrate a downhole tool according to the
present disclosure in partial cross-section in a run-in condition
and a set condition, respectively;
[0043] FIGS. 3C-3D illustrate the downhole tool in partial
cross-section revealing different configurations for stacked
rings;
[0044] FIG. 4A illustrates another embodiment of the disclosed
downhole tool in partial cross-section in the run-in condition;
[0045] FIG. 4B illustrates a more detailed view of the disclosed
tool in the run-in condition;
[0046] FIG. 4C illustrates an isolated view of engagement of a
setting sleeve with a slip segment on the disclosed tool;
[0047] FIG. 5A illustrates the disclosed downhole tool in partial
cross-section in the set condition;
[0048] FIG. 5B illustrates a more detailed view of the disclosed
tool in the set condition;
[0049] FIG. 6A illustrates a perspective view of an outer setting
ring for the disclosed tool;
[0050] FIG. 6B illustrates a perspective view of an inner setting
ring for the disclosed tool;
[0051] FIG. 7A illustrates perspectives view of two types of inner
expansion rings for the disclosed tool;
[0052] FIG. 7B illustrates a perspective view of an outer expansion
ring for the disclosed tool;
[0053] FIG. 8 illustrates a perspective view of a drive sleeve for
the disclosed tool;
[0054] FIG. 9 illustrates a perspective view of a slip segment for
the disclosed tool;
[0055] FIG. 10 illustrates a perspective view of a fixed sleeve for
the disclosed tool;
[0056] FIG. 11A illustrates an embodiment of the disclosed tool
used as a bridge plug to support a cased-hole gravel pack
completion;
[0057] FIG. 11B illustrates an embodiment of the disclosed tool
used as a sump packer to support a cased-hole gravel pack
completion; and
[0058] FIG. 12 illustrates the disclosed tool as a bridge plug in
partial cross-section.
DESCRIPTION OF EMBODIMENTS
[0059] FIGS. 3A-3B illustrate a downhole tool 100 according to the
present disclosure in partial cross-section in a run-in condition.
The downhole tool 100 can be configured as a bridge plug, a frac
plug, a packer, or any other desired downhole packer tool. In a
particular example, the downhole tool 100 can be a permanent sump
packer used as a base for a cased-hole gravel pack completion.
[0060] The downhole tool 100 has a mandrel 102, first and second
opposing shoulders 112a-b, a plurality of stacked rings 130a-b and
140a-b, and a slip 150. The first and second opposing shoulders
112a-b are disposed on the mandrel 110, and at least one of the
opposing shoulders (e.g., the first shoulder 112a) is movable
toward the second opposing shoulder 112b. These opposing shoulders
112a-b can be part of sleeves 110a-b disposed on the mandrel 102.
In this context, the first sleeve 110a can be a drive sleeve
movable along the mandrel 102 toward the second, fixed sleeve 110b.
(FIG. 6 shows an isolated perspective view of a sleeve 110.)
[0061] The slip 150 includes a plurality of segments 152 that are
axially aligned and disposed about the stacked rings 130a-b,
140a-b. The exposed surfaces of the slip segments 152 have wickers,
teeth, or the like for engaging the surrounding tubular, casing, or
the like. The inner surface of the slip segments 152 can have a
central tab 158 for stabilizing the segments 152 on the tool 100.
In particular, the central tab 158 has square shoulders that set
against adjacent rings (e.g., 140a).
[0062] The stacked rings 130a-b, 140a-b are disposed about the
mandrel 102 and are spaced between the first and second opposing
shoulders 112a-b. The stacked rings 130a-b, 140a-b decrease in
spacing in response to the movement of the first opposing shoulder
112a toward the second opposing shoulder 112b, and at least some of
the stacked rings (e.g., 140a-b) expand outward from the mandrel
102 in response to the decrease in spacing.
[0063] In particular, first rings 130a-b are disposed about the
mandrel 102 and are spaced between the first and second opposing
shoulders 112a-b of the sleeves 110a-b. Second rings 140a-b are
also disposed about the mandrel 102 as well, but they are spaced in
between each of the first rings 130a-b. The slip 150 with its
segments 152 is disposed on the first and second rings 130a-b, and
140a-b.
[0064] During activation, the drive sleeve 110a is moved toward the
fixed sleeve 110b. Activation can be achieved in several known
ways--some of which are disclosed herein. The first rings 130a-b
decrease in spacing in response to the movement of the drive sleeve
110a toward the opposing sleeve 110b, and the second rings 140a-b
expand outward from the mandrel 102 in response to the decrease in
spacing of the first rings 130a-b. Finally, the slip segments 152
move away from the mandrel 102 toward the surrounding tubular in
response to the outward expansion of the second rings 140a-b.
[0065] FIG. 3C illustrate the downhole tool 100 in partial
cross-section revealing how the stacked rings can be configured as
individual rings 130a-b, 140a-b alternatingly stacked on the
outside of the mandrel 102. A gap G is present between inner
expansion rings 140a where the central tabs 158 of the segments 152
positions.
[0066] An alternative configuration is shown in FIG. 3D. Here, the
stacked rings can be configured as strips 135 and 145 (wires,
springs, or the like) alternatingly coiled about the mandrel 102 to
form the various rings 130a-b, 140a-b. The lengths of the strips
135 and 145 may not fully encompass the expanse between the
opposition shoulders 112a-b so that space can be provided for at
least some of the ends of these coiled strips 135 and 145 to
accommodate spiraled movement of the strips during activation.
[0067] Again, a gap G is present where the central tabs 158 of the
segments 152 positions. The strips 135, 145 at one end of the slip
150 can be coiled in one direction, and the strips 135, 145 at the
other end can be similarly coiled in the same direction.
Alternatively, the strips 135, 145 can be coiled in opposing
directions to one another.
[0068] Either of these configurations in FIGS. 3C-3D can achieve
the same results during activation. As the opposing shoulders
112a-b are brought closer together, the expansion rings 140a-b
(either as individual rings or parts of a coil) can expand outward
and push the slip segments 152 toward the surrounding tubular.
[0069] During activation, a lock 114, such as a body lock ring or
other mechanism, disposed between the drive sleeve 110a and the
mandrel 102 permits the movement of the drive sleeve 110a toward
the fixed sleeve 110b, but the lock 114 prevents reverse movement
of the drive sleeve 110a. In this way, the tool 100 will not unset
once setting forces cease. Once the tool 100 is activated (i.e.,
the second rings 140a-b are expanded, the slip segments 152 are
engaged, etc.), the tool 100 can seal the annulus between the
mandrel 102 and the surrounding tubular or casing.
[0070] The downhole tool 100 can be installed in the wellbore with
any desired non-rigid system, such as electric wireline or coiled
tubing. A setting tool (not shown), such as a Baker E-4 Wireline
Setting Assembly commercially available from Baker Hughes, Inc.,
can connect to an upper portion of the mandrel 102. Specifically,
an outer movable portion of the setting tool is disposed about the
outer diameter of the mandrel 102, abutting the end of the drive
sleeve 110a. An inner portion of the setting tool can affix to the
mandrel 102. The setting tool and the downhole tool 100 are then
run into the well casing to the desired depth where the downhole
tool 100 is to be installed.
[0071] To set or activate the downhole tool 100, the mandrel 102 is
held by the wireline, through the inner portion of the setting
tool, as an axial force is applied through the outer movable
portion of the setting tool to the drive sleeve 110a, which
transfers axial force from the setting tool to the element system.
In particular, the axial force causes the outer portions of the
downhole tool 100 to move axially relative to the mandrel 102. The
force asserted against the drive sleeve 110a is transmitted by the
shoulder 112a. An equal and opposite force is asserted by the fixed
sleeve 110b on the other end of the downhole tool 100. The force
from both ends is transmitted to the element system, which causes
the slip 150 and second rings 140a-b to expand and set against the
surrounding tubular.
[0072] The segments 152 of the slip 150 can be initially
interconnected together and may fracture under radial stress. The
slip 150 can have a plurality of recessed grooves, allowing the
slip segments 152 to fracture along the grooves. Alternatively, the
segments 152 may already be independent.
[0073] An outer surface of the slip 150 can include outwardly,
extending wickers, comprising serrations or edge teeth. The wickers
can be arranged with a first set oriented toward the drive sleeve
110a, to resist uphole axial movement, and the wickers can be
arranged with a second set oriented toward the fixed sleeve 110b,
to resist downhole axial movement. Any number, shape, and
configuration of wicker can be used as desired.
[0074] When set, the downhole tool 100 can acts as a packer with
the slip 150 fixing the tool 100 in place. The stacked contact
between the rings 130a-b, 140a-b and the radial forces they place
on the outside of the mandrel 102 and the inside of the slip 150
can also act as a fluid seal in the annular space between the
mandrel 102 and the surrounding casing, although the fluid seal for
the downhole tool 100 can be provided by a separate packing element
(not shown) on the mandrel 102.
[0075] Any fluid sealing provided at the rings 130a-b, 140a-b and
slip 150 can be achieved by encasing the components in an
elastomer. Alternatively, the sealing can be achieved in part by
the stacked fit between the rings 130a-b, 140a-b. If the rings
130a-b, 140a-b are metallic, then the sealing can be a
metal-to-metal seal between the interfacing surfaces. If one or the
other of the rings 130a-b, 140a-b are composed of another malleable
or low yield material (e.g., plastic, elastomer, 4140 stainless
steel, etc.), then sealing between the stacked rings 130a-b, 140a-b
can be comparably made between the interfacing surfaces. In fact,
the splits 144 if present in the expansion rings 140a-b can be
misaligned, creating a tortuous path capable of sealing. Similarly,
if the expansion rings 140a-b are composed of a compressible
material, then the splits 144 if present in these rings 140a-b can
close to create the desired sealing. Finally, other forms of
sealing, such as an independent packing element or seal, could be
used elsewhere on the tool 100 in relation to the slip 150 and
stacked rings 130a-b, 140a-b depending on the implementation.
[0076] Turning now to Figurers 4A through 10, details of another
embodiment of the disclosed tool 100 are discussed. FIG. 4A
illustrates the disclosed downhole tool 100 along with a setting
tool in partial cross-section in the run-in condition, and FIG. 4B
illustrates a more detailed view of the disclosed downhole tool 100
in the run-in condition.
[0077] Similar components have the same reference numbers as in the
previous embodiment. Again, the downhole tool 100 has a mandrel
102, first and second opposing shoulders 112a-b, a plurality of
stacked rings (i.e., first setting rings 130a-b and second
expansion rings 140a-b), and a slip 150. At least the first
shoulder 112a on the drive sleeve 110 is movable toward the second
opposing shoulder 112b on the fixed sleeve 110b.
[0078] As shown, the mandrel 102 can define a throughbore 104,
although this is not strictly necessary depending on the purpose of
the tool 100. In the present context, the tool 100 is shown as a
sump packer. Therefore, the mandrel 102 defines a wide cylinder
close to the inner dimension of the surrounding casing.
Additionally, the mandrel's throughbore 104 can define a wide inner
dimension and can be a polished bore, such as used for a sump
packer for sealing with a latch assembly.
[0079] The setting rings 130a-b are disposed about the mandrel 102
and are spaced between the opposing shoulders 112a-b of the sleeves
110a-b. The expansion rings 140a-b are also disposed about the
mandrel 102 as well, but they are spaced in between each of the
setting rings 130a-b. The slip 150 with its segments 150 is
disposed on the rings 130a-b, and 140a-b.
[0080] The slip 150 includes a plurality of segments 152 that are
axially aligned and disposed about the rings 130a-b, 140a-b. (FIG.
9 shows an isolated perspective view of a segment 152 of the slip
150). The exposed surfaces of the slip segments 152 have wickers,
teeth, or the like for engaging the surrounding tubular. The inner
surface of the slip segments 152 can have a central tab 158 for
stabilizing the segments 152 on the tool 100, as will be described
below.
[0081] As shown in the detailed view of FIG. 4C, each end of the
opposing shoulders (e.g., 112b) can have a catch 113, tooth, or the
like to engage an end of a slip segment 152. Other ways of fixing
the segment 152 can be used, including shear pins, shear screws,
frangible bands, etc. The catches 113 on the ends of the segments
152 hold the slip 150 and other elements together during run-in, as
shown in FIGS. 4A-4B. This can help prevent premature setting and
can retain the slip segments 152 during tripping downhole.
[0082] As noted above, activation of the tool 100 can be achieved
in several ways. In the current embodiment as best shown in FIGS.
4A and 5A, the mandrel 102 of the tool 100 has a setting sleeve 160
moveably disposed toward the uphole end near the drive sleeve 110a.
The setting sleeve 160 includes a body lock ring 162 or other
mechanism that allows movement of the sleeve 160 toward the drive
sleeve 110a, but prevents the reverse. A packing element 165 on the
setting sleeve 160 can be expanded to seal with the surrounding
tubular or casing C. Any of the various types of packing elements
can be used, and only a schematic arrangement is shown here. In
general, the packing element 165 can include an elastomer for
sealing, a cone and wedge ring arrangement, or any other acceptable
arrangement.
[0083] As the setting sleeve 160 is freed with downhole movement
(by shearing pins or the like), the setting sleeve 160 moves along
the mandrel 102 with the sleeve's body lock 162 preventing reverse
movement. The packing element 165 expands outward against the
casing C, and the setting sleeve 160 moving along the mandrel 102
eventually pushes the drive sleeve 110a, which then activates the
slip 150, setting rings 130a-b, and expansion rings 140a-b to set
the slip 150 outward against the casing C.
[0084] In particular and as discussed previously, the drive sleeve
110a during activation is moved toward the fixed sleeve 110b. (FIG.
8 illustrates a perspective view of the drive sleeve 110a for the
disclosed tool 100). Once the drive sleeve 110a is moved, the catch
113 near the sleeve's shoulder 112a can disengage from the slip
segments (152), and the shoulder 112a can push against the rings
(130a-b, 140a-b). Meanwhile, the body lock ring 114 on the inside
of the drive sleeve 110a can engage a threaded surface on the
tool's mandrel (102) to lock forward progress of the sleeve
110a.
[0085] At the opposite end of the tool 100, the fixed sleeve 110b,
which is shown in an isolated view in FIG. 10, allows the rings
(130a-b, 140a-b) to press against its shoulder 112b. Likewise,
shifting of the slip segments (152) disengages their ends from the
catch 113 near this second shoulder 112b. Pockets 115 disposed
around the outside of the fixed sleeve 110b can accommodate
anti-rotation lugs (117; FIGS. 4B, 5B) that engage in outer slots
on the mandrel 102 and are covered by a cover (119; FIGS. 4B, 5B)
on the fixed sleeve 110b.
[0086] During activation as best shown in FIG. 5B, the setting
rings 130a-b decreases in spacing in response to the movement of
the drive sleeve 110a toward the opposing sleeve 110b, and the
expansion rings 140a-b expand outward from the mandrel 102 in
response to the decrease in spacing of the setting rings 130a-b.
Finally, pushed outward with the expansion rings 140a-b, the slip
segments 152 move away from the mandrel 102 toward the surrounding
casing in response to the outward expansion of the expansion rings
140a-b.
[0087] Thus, during activation, the setting and expansion rings
130a-b, 140a-b begin to make contact, and the setting rings 130a-b
force the expansion rings 140a-b outward due to the incline ramp
faces on each setting ring 130a-b. In turn, as the expansion rings
140a-b are forced outward, the outer dimension of the rings 140a-b
makes contact on the slip's inside surfaces to force the slip
segments 152 outward to bite into the surrounding casing C.
[0088] Being stacked along the outside of the mandrel 120, the
setting and expansion rings 130a-b, 140a-b increase the contact
area between the rings 130a-b, 140a-b and slip 150. The stacking of
the rings 130a-b, 140a-b also distributes load over a larger area
outside the mandrel 102 and inside the slip 150. Additional rings
can be stacked to increase the contact area if the slip 150 needs
to be qualified for a higher pressure or load.
[0089] Each ring 130a-b, 140a-b transfers the applied axial force
to radial expansion toward the inner surface of the surrounding
casing. The expansion rings 140a-b flow and expand across the
ramped surfaces of the setting rings 130a-b, applying a collapse
load through the setting rings 130a-b on the mandrel 102, which
helps prevent slippage of the system one activated. The collapse
load also prevents the rings 130a-b, 140a-b from rotating on the
mandrel 102.
[0090] As shown in isolated detail in FIGS. 6A-6B, the setting
rings 130a-b can be solid rings 132 that slide onto the outer
surface of the mandrel (102), although split or even segmented
rings could be used. These setting rings 130a-b can be composed of
a rigid material, such as a metal, plastic, etc. The outer ones of
these setting rings (i.e., 130a in FIG. 6A) can have shouldered
edges 138 for engaging against the opposing shoulders (112a-b) of
the sleeves (110a-b). However, the remaining interior edges 136 of
the rest of the setting rings 130a-b are ramped or sloped
outward.
[0091] As shown in isolated detail in FIGS. 7A-7B, the second
expansion rings 140a-b can be split rings 142 having splits 144.
These expansion rings 140a-b can be composed of a rigid material,
such as a metal, plastic, etc. Alternatively, the expansion rings
140a-b can be composed of compressible/expandable material, such as
an elastomer, plastic, etc., and the expansion rings 140a-b may not
include a split.
[0092] The inner ones of these expansion rings (i.e., 140a in FIG.
7B) can have shouldered edges 148 for engaging against the opposing
sides of the central tab (158) on the slip segments (152). However,
the remaining interior edges 146 of the rest of the expansion rings
140a-b are ramped or sloped inward to wedge against the ramped
edges 136 on adjacent first rings 130a-b.
[0093] As an alternative to the split ring, any of the expansion
rings 140b' can be a segmented ring having a number of segments
143. This configuration can also be used for any of the other rings
130a-b, 140a disclosed herein.
[0094] The contact angles of the ramped edges 136, 146 for the
rings 130a-b, 140a-b can be configured as desired to achieve
desired wedging. The contact angles of the edges 136, 146 can be
comparable for both types of rings 130a-b, 140a-b, or the angles
for the different rings 130a-b, 140a-b can be differently
configured. Likewise, the angles for the edges 136, 146 of each
ring 130a-b, 140a-b can all be similarly configured along the
length of the element system from the uphole end of the slip 150 to
the downhole end of the slip 150.
[0095] Alternatively, the contact angles of the edges 136, 146 can
be configured along the length of the elements so that the slip
segments 152 initially set outward at their uphole end first and
then set toward their downhole end. The reverse configuration could
also be used. As an alternative or in addition to the changing
angles along the length of the element system, the geometry of the
rings 130a-b, 140a-b can be different from one end of the element
system to the other to create a setting sequence from one end of
the slip 150 to the other. In other variations to achieve a desired
setting sequence, slots can be added, the materials can differ,
thinner cross-sections can be provided, and the like to some of the
rings 130a-b, 140a-b.
[0096] The disclosed tool 100 can be used in any packer application
that requires holding high loads in thin cross-section designs. As
noted herein, the disclosed tool 100 can be a plug. To that end,
the tool 100 can be used with a completion assembly having a distal
end supported by the tool 100. As depicted in FIG. 11A, for
example, a gravel pack completion 250 can have a retrievable
sealbore packer 256 with a gravel pack extension 252, crossover
tool 255, and screen(s) 254 extending therefrom. At its distal end,
the gravel pack completion 250 can have a bull plug 258 disposed at
the bottom of the screen(s) 254.
[0097] Before the completion 250 is deployed, the disclosed tool
100 configured as a bridge plug 100 is set in the casing C at a
suitable location using any of the various setting techniques. The
completion 50 is then deployed into the cased well, and the bull
plug 258 can be supported on the disclosed tool 100 configured as
the bridge plug. In this arrangement, the mandrel 102 of the tool
100 may or may not have a flow passage therethrough.
[0098] In another implementation for supporting the gravel pack
completion 250, the disclosed tool 100 can be used as a sump
packer. As depicted in FIG. 11B, the mandrel 102 of the disclosed
tool 100 as a sump packer defines a throughbore. As before, the
completion 250 can have a retrievable sealbore packer 256 with a
gravel pack extension 252, a crossover tool 255, and screen(s) 254
extending therefrom. At its distal end, the gravel pack completion
250 can have a snap-latch tool 260 installing in the throughbore
104 of the mandrel 102. The snap-latch tool 260 has seals sealing
in the throughbore 104 of the mandrel 102 and has a latch latching
to the mandrel 102. Although not shown, it will be appreciated that
the disclosed tool 100 can have a setting sleeve (e.g., 160) and
other features similar to those discussed above with reference to
FIGS. 4A and 5A.
[0099] The snap-latch tool 260 provides a surface indication that
the gravel pack completion 250 is properly located in the sump
packer 100. With the completion 250 in place, the upper packer 256
is set, and the crossover tool 255 is manipulated to its various
positions to pump gravel as well as any other treatments into the
annulus and through the perforations. From that point, a tubing
string T can install in the upper packer 256 to create a path for
production fluid. Then, any of the other desired completion and
production operations can be performed.
[0100] Finally, as noted previously, the disclosed tool 100 can be
used as a number of downhole packer tools or the like. As an
example, FIG. 12 illustrates the disclosed tool 100 as a bridge
plug in partial cross-section. The bridge plug 100 has a mandrel
102 having a packing element 109 and setting elements 110-150. The
packing element 109 can be disposed on the mandrel 102 near the
shoe 106 and can include some conventional components, such as
anti-extrusion elements 30a-b and a packer 38. The anti-extrusion
elements 30a-b can have various backup rings 34 and the like. The
setting elements 110-150 are similar to those disclosed herein and
can be disposed about the mandrel 102 between the packing element
109 and a push ring 108. Setting of the packing element 109 and the
setting elements 110-150 can be achieved by axial force applied
against the push ring 108 and compressing the components against
the shoe 106 on the held mandrel 102.
[0101] The foregoing description of preferred and other embodiments
is not intended to limit or restrict the scope or applicability of
the inventive concepts conceived of by the Applicants. More or less
rings 130a-b, 140a-b can be used. The rings 130a-b, 140a-b can be
disposed along a length of the mandrel 102 greater or shorter than
the extent of the slip 150. All of the rings 130a-b, 140a-b
preferably have ramped surfaces, although this is not strictly
necessary if the alternating expansion rings 140a-b even with a
different cross-section can ride up on the setting rings 130a-b
with a different cross-section.
[0102] It will be appreciated with the benefit of the present
disclosure that features described above in accordance with any
embodiment or aspect of the disclosed subject matter can be
utilized, either alone or in combination, with any other described
feature, in any other embodiment or aspect of the disclosed subject
matter.
[0103] In exchange for disclosing the inventive concepts contained
herein, the Applicants desire all patent rights afforded by the
appended claims. Therefore, it is intended that the appended claims
include all modifications and alterations to the full extent that
they come within the scope of the following claims or the
equivalents thereof.
* * * * *