U.S. patent application number 16/944600 was filed with the patent office on 2021-06-24 for rotary latch device.
This patent application is currently assigned to OIL STATES ENERGY SERVICES, L.L.C.. The applicant listed for this patent is OIL STATES ENERGY SERVICES, L.L.C.. Invention is credited to Jimmy Livingston, Bob McGuire.
Application Number | 20210189821 16/944600 |
Document ID | / |
Family ID | 1000005004512 |
Filed Date | 2021-06-24 |
United States Patent
Application |
20210189821 |
Kind Code |
A1 |
Livingston; Jimmy ; et
al. |
June 24, 2021 |
ROTARY LATCH DEVICE
Abstract
A latching assembly to couple a first mandrel to a second
mandrel is disclosed. The latching assembly includes a plurality of
wedge members disposed circumferentially and a guide plate. Each
wedge member may include a semi-annular wedge body, an upper
engagement lip, a lower engagement lip, and a guide pin. The guide
plate may include a plurality of guide slots to translate and
rotate the plurality of wedge members via the respective guide
pins. Because the plurality of wedge members can be translated and
rotated to lock and release the first mandrel to and from the
second mandrel, the latching assembly can simplify the connection
and disconnection of a first mandrel with the second mandrel.
Inventors: |
Livingston; Jimmy; (Manvel,
TX) ; McGuire; Bob; (Meridian, OK) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
OIL STATES ENERGY SERVICES, L.L.C. |
Houston |
TX |
US |
|
|
Assignee: |
OIL STATES ENERGY SERVICES,
L.L.C.
Houston
TX
|
Family ID: |
1000005004512 |
Appl. No.: |
16/944600 |
Filed: |
July 31, 2020 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
16722146 |
Dec 20, 2019 |
10787876 |
|
|
16944600 |
|
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
F16L 23/12 20130101;
F16L 23/04 20130101; E21B 33/03 20130101 |
International
Class: |
E21B 33/03 20060101
E21B033/03; F16L 23/12 20060101 F16L023/12; F16L 23/04 20060101
F16L023/04 |
Claims
1. A latching assembly to couple a first mandrel to a second
mandrel, the latching assembly comprising: a plurality of wedge
members disposed circumferentially, wherein each wedge member
comprises: a wedge body comprising a semi-annular shape; an upper
engagement lip extending from the wedge body, the upper engagement
lip defining an upper axial engagement surface; a lower engagement
lip extending from the wedge body, the lower engagement lip
defining a lower axial engagement surface, wherein the lower axial
engagement surface is axially spaced apart from the upper axial
engagement surface; and a guide pin extending axially from the
wedge body; and a guide plate comprising a plurality of guide
slots, wherein each guide slot receives each guide pin of a
respective wedge member, wherein the guide plate is configured to
rotate the plurality of guide slots to translate and rotate the
plurality of wedge members.
2. The latching assembly of claim 1, wherein each wedge member
further comprises an inner engagement surface disposed between the
upper engagement lip and the lower engagement lip.
3. The latching assembly of claim 1, wherein the plurality of wedge
members form an annulus around the first mandrel and the second
mandrel in a locked position.
4. The latching assembly of claim 1, the latching assembly further
comprising: an offset guide plate axially spaced apart from the
guide plate, the offset guide plate comprising a plurality of
offset guide slots, wherein each offset guide slot receives an
offset guide pin of the respective wedge member.
5. The latching assembly of claim 1, the latching assembly further
comprising: an actuating gear coupled to the guide plate, wherein
the actuating gear is configured to rotate the guide plate.
6. The latching assembly of claim 5, the latching assembly further
comprising: an actuator assembly in meshed engagement with the
actuating gear, wherein the actuator assembly rotates the actuating
gear.
7. The latching assembly of claim 6, wherein the actuator assembly
comprises: an actuator shaft in meshed engagement with the
actuating gear; and a worm gear coupled to the actuator shaft.
8. A rotary latch device to couple a first mandrel to a second
mandrel, the rotary latch device comprising: a housing; and a
latching assembly disposed within the housing, the latching
assembly comprising: a plurality of wedge members disposed
circumferentially, wherein each wedge member comprises: a wedge
body comprising a semi-annular shape; an upper engagement lip
extending from the wedge body, the upper engagement lip defining an
upper axial engagement surface; a lower engagement lip extending
from the wedge body, the lower engagement lip defining a lower
axial engagement surface, wherein the lower axial engagement
surface is axially spaced apart from the upper axial engagement
surface; and a guide pin extending axially from the wedge body; and
a guide plate comprising a plurality of guide slots, wherein each
guide slot receives each guide pin of a respective wedge member,
wherein the guide plate is configured to rotate the plurality of
guide slots to translate and rotate the plurality of wedge
members.
9. The rotary latch device of claim 8, wherein the housing
comprises: a receiver to direct the first mandrel toward the second
mandrel, the receiver comprising: a receiver mandrel extending from
the latch assembly.
10. The rotary latch device of claim 9, wherein the receiver
includes a flared portion configured to align the first mandrel
into the receiver mandrel.
11. The rotary latch device of claim 9, wherein the receiver
includes a support tab extending along the receiver mandrel.
12. The rotary latch device of claim 8, wherein each wedge member
further comprises an inner engagement surface disposed between the
upper engagement lip and the lower engagement lip.
13. The rotary latch device of claim 8, wherein the plurality of
wedge members form an annulus around the first mandrel and the
second mandrel in a locked position.
14. The rotary latch device of claim 8, the latching assembly
further comprising: an actuating gear coupled to the guide plate,
wherein the actuating gear is configured to rotate the guide
plate.
15. The rotary latch device of claim 14, the latching assembly
further comprising: an actuator assembly in meshed engagement with
the actuating gear, wherein the actuator assembly rotates the
actuating gear.
16. The rotary latch device of claim 15, wherein the housing
comprises an actuator housing enclosing the actuator assembly.
17. The rotary latch device of claim 15, wherein the actuator
assembly comprises: an actuator shaft in meshed engagement with the
actuating gear; and a worm gear coupled to the actuator shaft.
18. A method to couple a first mandrel to a second mandrel, the
method comprising: translating and rotating a plurality of
semi-annular wedge members to form an annulus; and coupling the
first mandrel and the second mandrel within the annulus.
19. The method of claim 18, further comprising: receiving the first
mandrel against the second mandrel with the plurality of
semi-annular wedge members in a released configuration.
20. The method of claim 18, further comprising: rotating a guide
plate to translate and rotate the plurality of semi-annular wedge
members.
Description
TECHNICAL FIELD
[0001] The present disclosure relates generally to wellhead
systems, and, more particularly, to latching devices for use with
wellhead systems.
BACKGROUND
[0002] Tools and equipment can be used for a wide variety of
purposes with oil and gas wells. For example, wireline tools can
lower instruments into a wellbore on the end of a wireline cable to
measure wellbore properties or perform operations within the
wellbore. During operation, tools and equipment can be attached and
removed from an oil and gas well.
[0003] Wellhead systems can provide a surface interface to allow
tools and equipment to be coupled with an oil and gas well. For
example, a wireline tool can be aligned with and coupled to a
wellhead system. However, one drawback of conventional interfaces
is that aligning and coupling a tool to the surface interface often
requires personnel to be exposed to potentially hazardous
conditions. Further, tools may be improperly aligned and/or
incompletely secured to conventional interfaces. Improper alignment
or incomplete coupling can lead to leakage or a risk of blowout.
Therefore, what is needed is an apparatus, system or method that
addresses one or more of the foregoing issues, among one or more
other issues.
SUMMARY OF THE INVENTION
[0004] A latching assembly to couple a first mandrel to a second
mandrel is disclosed. The latching assembly includes a plurality of
wedge members disposed circumferentially and a guide plate. Each
wedge member may include a semi-annular wedge body, an upper
engagement lip, a lower engagement lip, and a guide pin. The guide
plate may include a plurality of guide slots to translate and
rotate the plurality of wedge members via the respective guide
pins. Because the plurality of wedge members can be translated and
rotated to lock and release the first mandrel to and from the
second mandrel, the latching assembly can simplify the connection
and disconnection of a first mandrel with the second mandrel.
BRIEF DESCRIPTION OF THE DRAWINGS
[0005] Various embodiments of the present disclosure will be
understood more fully from the detailed description given below and
from the accompanying drawings of various embodiments of the
disclosure. In the drawings, like reference numbers may indicate
identical or functionally similar elements.
[0006] FIG. 1 is an elevation view of an embodiment of a rotary
latch device.
[0007] FIG. 2 is an isometric view of the rotary latch device of
FIG. 1.
[0008] FIG. 3 is a partial cross-sectional view of the rotary latch
device of FIG. 1 with a latching assembly in a released
position.
[0009] FIG. 4 is an isometric view of the rotary latch device of
FIG. 1 with the device housing shown in hidden lines to show the
latching mechanism in a released position.
[0010] FIG. 5 is an isometric view of the rotary latch device of
FIG. 1 with the device housing shown in hidden lines and with the
latching assembly in a released position.
[0011] FIG. 6 is a partial cross-sectional view of the rotary latch
device of FIG. 1 with a latching assembly in an engaged
position.
[0012] FIG. 7 is an isometric view of the rotary latch device of
FIG. 1 with the device housing shown in hidden lines and with the
latching assembly in an engaged position.
[0013] FIG. 8 is an isometric view of an embodiment of a rotary
latch device.
[0014] FIG. 9 is a partial cross-sectional view of the rotary latch
device of FIG. 8.
DETAILED DESCRIPTION
[0015] FIG. 1 is an elevation view of an embodiment of a rotary
latch device 100. FIG. 2 is an isometric view of the rotary latch
device 100 of FIG. 1. With reference to FIGS. 1 and 2, the rotary
latch device 100 can receive a tool mandrel 110 and latch and/or
engage the tool mandrel 110 to a wellhead connection mandrel
120.
[0016] In the depicted example, the rotary latch device 100 can be
coupled to the wellhead connection mandrel 120. As illustrated, the
wellhead connection mandrel 120 can be coupled to a lower portion
106 of the device housing 102. In some applications, the wellhead
connection mandrel 120 can allow access to a wellbore via a
wellhead in fluid communication with the wellhead connection
mandrel 120. The wellhead connection mandrel 120 can be coupled to
downstream wellbore components with a flange 122. Fasteners 126 can
extend through fastener holes 124 to secure the flange 122 to
downstream wellbore components. As described herein, the rotary
latch device 100 can be coupled to the wellhead connection mandrel
120 to facilitate and simplify remote engagement and latching of
the tool mandrel 110 to the wellhead connection mandrel 120.
[0017] During operation, the rotary latch device 100 can receive
the tool mandrel 110 via a receiver 130. Optionally, the tool
mandrel 110 can be part of a wellbore tool or equipment, such as a
wireline tool, etc., configured for use in the wellbore. In some
embodiments, the tool mandrel 110 can be coupled to other portions
of a wellbore tool or other wellbore components via a flange 112.
Fasteners 116 can extend through fastener holes 114 to secure the
flange 112 to other portions of the wellbore tool or other wellbore
components.
[0018] In the illustrated embodiment, the rotary latch device 100
includes a receiver 130 to align and direct the tool mandrel 110
into engagement with the wellhead connection mandrel 120 within the
device housing 102. As shown, the receiver 130 extends out of the
upper portion 104 of the device housing 102. The receiver 130 can
include a flared portion 134 that tapers into the receiver mandrel
136. Advantageously, by increasing the diameter of the flared
portion 134 relative to the receiver mandrel 136, the tool mandrel
110 can be directed and self-aligned into the receiver mandrel 136,
during a stab-in procedure. Optionally, the receiver 130 can
include support tabs 132 extending from the flared portion 134 of
the receiver 130 to the device housing 102.
[0019] Upon entering the receiver mandrel 136, the receiver mandrel
136 can direct the tool mandrel 110 into alignment and engagement
with the wellhead connection mandrel 120. Upon engagement with the
wellhead connection mandrel 120, the rotary latch device 100 can
latch or lock the tool mandrel 110 to the wellhead connection
mandrel 120. In some embodiments, the latch mechanism of the rotary
latch device 100 can be actuated by an actuation assembly disposed
within an actuation housing 108.
[0020] FIG. 3 is a partial cross-sectional view of the rotary latch
device 100 of FIG. 1 with a latching assembly 140 in a released
position. In the depicted example, the latching assembly 140 is
shown in a released position or configuration to permit engagement
of the tool mandrel 110 with the wellhead connection mandrel 120 or
to permit removal of the tool mandrel 110 from the rotary latch
device 100.
[0021] In the depicted example, the tool mandrel 110 is shown
engaged with the wellhead connection mandrel 120. As illustrated,
the mating flange 118 of the tool mandrel 110 engages with the
mating flange 128 of the wellhead connection mandrel 120.
Optionally, the mating flange 118 and the mating flange 128 can
sealingly engage to prevent leaks.
[0022] In some embodiments, the tool mandrel 110 includes a mandrel
extension 117 configured to extend into and engage with the inner
bore of wellhead connection mandrel 120. The mandrel extension 117
can further aid in aligning the tool mandrel 110 with the wellhead
connection mandrel 120 during engagement. Sealing elements may also
be included at the interface between mandrel extension 117 and the
inner bore of wellhead connection mandrel 120. As illustrated, the
wellhead connection mandrel 120 can further be coupled to the
rotary latch device 100 at a coupling flange 129.
[0023] As illustrated, the irising wedges 150 of the latching
assembly 140 can be circumferentially spaced apart in a released
configuration to allow the tool mandrel 110 to engage or disengage
from the wellhead connection mandrel 120. As can be appreciated,
the irising wedges 150 can be sufficiently radially spaced apart to
allow the tool mandrel 110 to move axially relative to the wellhead
connection mandrel 120.
[0024] FIGS. 4 and 5 are isometric views of the rotary latch device
100 of FIG. 1 with the device housing 102 shown in hidden lines to
show the latching assembly 140 in a released position. With
reference to FIGS. 3-5, each of the irising wedges 150 has a
generally semi-annular shape. Each irising wedge 150 can be a
geometric sector of an overall annular shape. In the illustrated
embodiment, the latching assembly 140 includes 8 semi-annular
irising wedges 150 that can be arranged to form an annular shape as
described herein. In some embodiments, the latching assembly 140
can include any suitable number of irising wedges 150.
[0025] As shown, each irising wedge 150 can include an upper
engagement lip 152 and a lower engagement lip 154, each radially
extending from the main body of irising wedge 150. As illustrated,
the lower engagement lip 154 can be axially spaced apart from the
upper engagement lip 152. The axial space between lower engagement
lip 154 and upper engagement lip should be sufficient to
accommodate the combined axial width of mating flange 118 of tool
mandrel 110 and mating flange 128 of wellhead connection mandrel
120. Further, an inner circumferential engagement surface 156 can
be defined opposite to the outer surface 158 and between the upper
engagement lip 152 and the lower engagement lip 154.
[0026] In the depicted example, the irising wedges 150 are disposed
between an upper guide plate 162 and a lower guide plate 166 to
retain and guide the irising wedges 150. During operation, the
irising wedges 150 can be moved into a released configuration by
rotating an upper guide plate 162 and/or a lower guide plate 166.
As the upper guide plate 162 and/or the lower guide plate 166 are
rotated, guide slots 164, 168 can engage with guide pins 159 to
translate and/or rotate the irising wedges 150 into the released
configuration. In some embodiments, as the upper guide plate 162 is
rotated in a counter-clockwise direction, the guide slots 164 can
engage with the guide pins 159 to radially move the irising wedges
150 away from the wellhead connection mandrel 120.
[0027] As illustrated, the upper guide plate 162 includes a
plurality of angularly disposed guide slots 164. The upper guide
plate 162 can include a corresponding number of guide slots 164 to
receive a respective guide pin 159 from each irising wedge 150. As
can be appreciated, the guide slots 164 can be formed with a
desired angle having a radial and/or tangential component to
provide a desired actuation behavior of the irising wedges 150 when
the upper guide plate 162 is rotated. It should be understood that
the guide pins 159 of irising wedges 150 may engage only with guide
slots 164 in upper guide plate 162, only with guide slots 168 in
lower guide plate 166, or with a combination of both. Further, in
some embodiments, guide slots may only be present on one of upper
guide plate 162 or lower guide plate 166.
[0028] In some embodiments, the lower guide plate 166 can include a
plurality of angularly disposed guide slots 168. Optionally, the
guide slots 168 can be offset in position and/or angle from the
guide slots 164. Further, the guide pins 159 extending into the
guide slots 168 can be offset from the guide pins 159 extending
into the guide slots 164. As can be appreciated, the guide slots
168 can be formed with a desired angle having a radial and/or
tangential component and offset to provide a desired actuation
behavior of the irising wedges 150 when the upper guide plate 162
and/or the lower guide plate 166 is rotated.
[0029] During operation, the upper guide plate 162 and/or the lower
guide plate 166 can be rotated by an actuation assembly 170 engaged
with an actuating gear 160 coupled to the upper guide plate 162
and/or the lower guide plate 166. In the depicted example, the
actuation assembly 170 can rotate one or both of the upper guide
plate 162 and the lower guide plate 166 to move the irising wedges
150. Optionally, portions of the device housing 102 can rotate as
the irising wedges 150 are moved to provide a visual signal of
engagement or disengagement of the tool mandrel 110.
[0030] In some embodiments, the actuation assembly 170 can include
a worm gear 174 that is in meshed engagement with gear teeth 161 of
the actuating gear 160. By rotating an actuator shaft 172 of the
actuation assembly 170, the worm gear 174 coupled to the actuator
shaft 172 can rotate the actuating gear 160 and therefore rotate
the upper guide plate 162 and/or the lower guide plate 166 to
actuate the irising wedges 150.
[0031] Optionally, the actuator shaft 172 and the worm gear 174 can
be driven by a motor, such as an electric motor and/or a hydraulic
motor. In some embodiments, the motor can rotate the actuator shaft
172 via a shaft input 176 coupled to the actuator shaft 172.
Advantageously, by actuating the irising wedges 150 with a motor,
the tool mandrel 110 can be engaged and/or disengaged from the
wellhead connection mandrel 120 remotely.
[0032] FIG. 6 is a partial cross-sectional view of the rotary latch
device 100 of FIG. 1 with a latching assembly 140 in an engaged
position. In the depicted example, the latching assembly 140 is
shown in a latched or locked position to secure the tool mandrel
110 to the wellhead connection mandrel 120 during operation.
[0033] As described herein, the irising wedges 150 can radially
converge or constrict to engage and retain the tool mandrel 110
with the wellhead connection mandrel 120. In some embodiments, the
irising wedges 150 cooperatively form an annular shape as the
irising wedges 150 converge around the tool mandrel 110 and the
wellhead connection mandrel 120. As illustrated, the irising wedges
150 are both axially and radially aligned to engage with the mating
flanges 118, 128.
[0034] FIG. 7 is an isometric view of the rotary latch device 100
of FIG. 1 with the device housing 102 shown in hidden lines and
with the latching assembly 140 in an engaged position. With
reference to FIGS. 6 and 7, upon converging to a locked position,
each of the irising wedges 150 can at least partially enclose the
mating flanges 118, 128. For example, an upper axial engagement
surface defined by the upper engagement lip 152 can engage against
the upper surface of the mating flange 118. A lower axial
engagement surface defined by the lower engagement lip 154 can
engage against the lower surface of the mating flange 128. As
illustrated, the lower axial engagement surface is axially spaced
apart from the upper axial engagement surface. Advantageously, the
upper axial engagement surface and the lower axial engagement
surface can cooperatively constrain the mating flanges 118, 128 to
prevent axial movement of the tool mandrel 110 and the wellhead
connection mandrel 120 relative to each other.
[0035] In some embodiments, the inner circumferential engagement
surface 156 between the upper engagement lip 152 and the lower
engagement lip 154 can engage against the edges of the mating
flanges 118, 128. In some embodiments, the inner circumferential
engagement surface 156 can limit radial movement of the mating
flanges 118, 128 and can improve stability of the coupling between
the tool mandrel 110 and the wellhead connection mandrel 120.
[0036] Optionally, the inner edges of the upper engagement lip 152
and the lower engagement lip 154 can define mandrel engagement
surface 157 configured to engage against portions of the tool
mandrel 110 and the wellhead connection mandrel 120. In some
applications, the mandrel engagement surface 157 can limit radial
movement of the tool mandrel 110 and the wellhead connection
mandrel 120.
[0037] During operation, the irising wedges 150 can be moved into a
locking configuration by rotating an upper guide plate 162 and/or a
lower guide plate 166. As the upper guide plate 162 and/or the
lower guide plate 166 are rotated, guide slots 164, 168 can engage
with the guide pins 159 of the irising wedges 150 to translate
and/or rotate the irising wedges 150 into the locking
configuration. In some embodiments, as the upper guide plate 162 is
rotated in a clockwise direction, the guide slots 164 can engage
with the guide pins 159 to radially move the irising wedges 150
toward the mating flanges 118, 128 to retain the tool mandrel 110
with the wellhead connection mandrel 120.
[0038] As can be appreciated, the guide slots 164, 168 of the upper
guide plate 162 and the lower guide plate 166 can be configured to
rotate and/or translate the irising wedges 150 into an annular
shape upon rotation of the upper guide plate 162 and/or the lower
guide plate 166.
[0039] During operation, the actuation assembly 170 can rotate one
or both of the upper guide plate 162 and the lower guide plate 166
to move the irising wedges 150 between a released position and an
engaged or locked position.
[0040] FIG. 8 is an isometric view of an embodiment of a rotary
latch device 200. FIG. 9 is a partial cross-sectional view of the
rotary latch device 200 of FIG. 8. With reference to FIGS. 8 and 9,
the rotary latch device 200 can be inverted or flipped in
comparison to the rotary latch device 100, such that the rotary
latch device 200 can receive a wellhead connection mandrel 220 and
latch and/or engage the wellhead connection mandrel 220 to a tool
mandrel 210. As can be appreciated, the rotary latch device 200 can
include features that are similar to those of rotary latch device
100. Accordingly, similar features may be referred to with similar
reference numerals.
[0041] In the depicted example, the rotary latch device 200 can be
coupled to the tool mandrel 210. As illustrated, the tool mandrel
210 can be coupled to an upper portion 204 of the device housing
202. Optionally, the tool mandrel 210 can be part of a wellbore
tool or equipment, such as a wireline tool, etc., configured for
use in the wellbore. In some embodiments, the tool mandrel 210 can
be coupled to other portions of a wellbore tool or other wellbore
components via a threaded portion 211. As described herein, the
rotary latch device 200 can be coupled to the tool mandrel 210 to
facilitate and simplify remote engagement and latching of the
wellhead connection mandrel 220 to the tool mandrel 210.
[0042] During operation, the rotary latch device 200 can receive
the wellhead connection mandrel 220 via a receiver 230. In some
applications, the wellhead connection mandrel 220 can allow access
to a wellbore via a wellhead in fluid communication with the
wellhead connection mandrel 220. The wellhead connection mandrel
220 can be coupled to downstream wellbore components with a
threaded connection 222. Optionally, the threaded connection 222
can be outfitted with a variety of connection types and/or sizes.
Advantageously, the rotary latch device 200 can allow rapid
connection and disconnection of the tool mandrel 210 from the
wellhead connection mandrel 220.
[0043] In the illustrated embodiment, the rotary latch device 200
includes a receiver 230 to align and direct the wellhead connection
mandrel 220 into engagement with the tool mandrel 210 within the
device housing 202. As shown, the receiver 230 extends out of the
lower portion 206 of the device housing 202. The receiver 230 can
include a flared portion 234 that tapers into the receiver mandrel
236. Advantageously, by increasing the diameter of the flared
portion 234 relative to the receiver mandrel 236, the wellhead
connection mandrel 220 can be directed and self-aligned into the
receiver mandrel 236 during a stab-in procedure. Optionally, the
receiver 230 can include support tabs 232 extending from the flared
portion 234 of the receiver 230 to the device housing 202.
[0044] Upon entering the receiver mandrel 236, the receiver mandrel
236 can direct the wellhead connection mandrel 220 into alignment
and engagement with the tool mandrel 210. Upon engagement with the
tool mandrel 210, the rotary latch device 200 can latch or lock the
wellhead connection mandrel 220 to the tool mandrel 210, similar to
as described with respect to rotary latch device 100.
[0045] In the depicted example, the latching assembly 240 is shown
in a released position or configuration to permit engagement of the
wellhead connection mandrel 220 with the tool mandrel 210 or to
permit removal of the wellhead connection mandrel 220 from the
rotary latch device 200.
[0046] In the depicted example, the wellhead connection mandrel 220
is shown engaged with the tool mandrel 210. As illustrated, the
mating flange 228 of the wellhead connection mandrel 220 engages
with the mating flange 218 of the tool mandrel 210. Optionally, the
mating flange 228 and the mating flange 218 can sealingly engage to
prevent leaks.
[0047] In some embodiments, the wellhead connection mandrel 220
includes a mandrel extension 227 configured to extend into and
engage with the inner bore of tool mandrel 210. The mandrel
extension 227 can further aid in aligning the wellhead connection
mandrel 220 with the tool mandrel 210 during engagement. Sealing
elements may also be included at the interface between mandrel
extension 227 and the inner bore of tool mandrel 210. As
illustrated, the tool mandrel 210 can further be coupled to the
rotary latch device 200 at a coupling flange 219.
[0048] Similar to rotary latch device 100, the rotary latch device
200 can include a latching assembly 240 with a plurality of irising
wedges 250 to allow the wellhead connection mandrel 220 to engage
or disengage from the tool mandrel 210. As can be appreciated, the
latching assembly 240 can operate in a similar manner as described
with respect to latching assembly 140. For example, the irising
wedges 250 can radially converge or constrict to engage and retain
the tool mandrel 210 with the wellhead connection mandrel 220. In
some embodiments, the irising wedges 250 cooperatively form an
annular shape as the irising wedges 250 converge around the tool
mandrel 210 and the wellhead connection mandrel 220. In an
engagement position, the irising wedges 250 can be both axially and
radially aligned to engage with the mating flanges 218, 228.
[0049] In some embodiments, the latching assembly 240 can be
actuated by an actuation assembly 270. Optionally, the actuation
assembly 270 can include a motor or actuator that is operatively
coupled to a drive mechanism, such as a worm gear to rotate the
upper guide plate 262 and/or the lower guide plate 266 to actuate
the irising wedges 250. In some embodiments, the actuation assembly
270 can include a motor that is coupled to a worm gear by a belt or
other drive mechanism. Further, the actuation assembly 270 or the
rotary latch device 200 generally can be controlled by hardware
disposed within the control boxes 280a and 280b. The control boxes
280a and 280b can include control hardware, wireless transceivers,
and/or power supplies. The actuation assembly 270 and the control
boxes 280a and 280b can be coupled or otherwise attached to the
device housing 202.
[0050] It is understood that variations may be made in the
foregoing without departing from the scope of the present
disclosure. In several exemplary embodiments, the elements and
teachings of the various illustrative exemplary embodiments may be
combined in whole or in part in some or all of the illustrative
exemplary embodiments. In addition, one or more of the elements and
teachings of the various illustrative exemplary embodiments may be
omitted, at least in part, and/or combined, at least in part, with
one or more of the other elements and teachings of the various
illustrative embodiments.
[0051] Any spatial references, such as, for example, "upper,"
"lower," "above," "below," "between," "bottom," "vertical,"
"horizontal," "angular," "upwards," "downwards," "side-to-side,"
"left-to-right," "right-to-left," "top-to-bottom," "bottom-to-top,"
"top," "bottom," "bottom-up," "top-down," etc., are for the purpose
of illustration only and do not limit the specific orientation or
location of the structure described above.
[0052] In several exemplary embodiments, while different steps,
processes, and procedures are described as appearing as distinct
acts, one or more of the steps, one or more of the processes,
and/or one or more of the procedures may also be performed in
different orders, simultaneously and/or sequentially. In several
exemplary embodiments, the steps, processes, and/or procedures may
be merged into one or more steps, processes and/or procedures.
[0053] In several exemplary embodiments, one or more of the
operational steps in each embodiment may be omitted. Moreover, in
some instances, some features of the present disclosure may be
employed without a corresponding use of the other features.
Moreover, one or more of the above-described embodiments and/or
variations may be combined in whole or in part with any one or more
of the other above-described embodiments and/or variations.
[0054] Although several exemplary embodiments have been described
in detail above, the embodiments described are exemplary only and
are not limiting, and those skilled in the art will readily
appreciate that many other modifications, changes and/or
substitutions are possible in the exemplary embodiments without
materially departing from the novel teachings and advantages of the
present disclosure. Accordingly, all such modifications, changes,
and/or substitutions are intended to be included within the scope
of this disclosure as defined in the following claims. In the
claims, any means-plus-function clauses are intended to cover the
structures described herein as performing the recited function and
not only structural equivalents, but also equivalent structures.
Moreover, it is the express intention of the applicant not to
invoke 35 U.S.C. .sctn. 112, paragraph 6 for any limitations of any
of the claims herein, except for those in which the claim expressly
uses the word "means" together with an associated function.
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