U.S. patent application number 17/315251 was filed with the patent office on 2021-08-26 for connector apparatus for subsea blowout preventer.
The applicant listed for this patent is Seaboard International Inc.. Invention is credited to Kenneth Bean, Paul Horton, Jerry Keith Rhodes.
Application Number | 20210262310 17/315251 |
Document ID | / |
Family ID | 1000005567612 |
Filed Date | 2021-08-26 |
United States Patent
Application |
20210262310 |
Kind Code |
A1 |
Rhodes; Jerry Keith ; et
al. |
August 26, 2021 |
Connector Apparatus for Subsea Blowout Preventer
Abstract
According to one aspect, an apparatus is adapted to be operably
coupled to a subsea blowout preventer and includes a first tubular
member defining an internal passage, and a second tubular member
extending within the internal passage. A sealing assembly is
disposed radially between the first and second tubular members, and
includes a sealing element. The second tubular member covers the
sealing element and thus facilitates protecting the sealing element
from any fluid flow through the internal passage. According to
another aspect, a sealing element of a connector is protected
before engaging the connector with a subsea casing. The connector
is engaged with the casing while the sealing element is protected
so that the sealing element is fluidically isolated from any fluid
flow through the connector. The sealing element sealingly engages
the casing.
Inventors: |
Rhodes; Jerry Keith;
(Pearland, TX) ; Bean; Kenneth; (Sugar Land,
TX) ; Horton; Paul; (Lafayette, LA) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Seaboard International Inc. |
Houston |
TX |
US |
|
|
Family ID: |
1000005567612 |
Appl. No.: |
17/315251 |
Filed: |
May 7, 2021 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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16409659 |
May 10, 2019 |
11028662 |
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17315251 |
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15361649 |
Nov 28, 2016 |
10316606 |
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16409659 |
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|
14870501 |
Sep 30, 2015 |
9534467 |
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15361649 |
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14095241 |
Dec 3, 2013 |
9175551 |
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14870501 |
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61733039 |
Dec 4, 2012 |
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Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B 33/038 20130101;
E21B 43/013 20130101; E21B 33/064 20130101; E21B 43/0122
20130101 |
International
Class: |
E21B 33/038 20060101
E21B033/038; E21B 43/01 20060101 E21B043/01; E21B 33/064 20060101
E21B033/064; E21B 43/013 20060101 E21B043/013 |
Claims
1. Apparatus for coupling a blowout preventer to a subsea structure
having an elongated cylindrical casing, comprising: an adapter
defining a first cylindrical internal passageway having an inside
diameter consistent with an outer diameter of the subsea structure
to accommodate the subsea structure; a cylindrical sleeve residing
within the first cylindrical internal passageway and defining a
second cylindrical internal passageway substantially in axial
alignment with the first cylindrical internal passageway; a sealing
assembly having at least one seal disposed in the first cylindrical
internal passageway and radially between the adapter and the
cylindrical sleeve, the cylindrical sleeve configured to isolate
the sealing assembly from wellbore fluids conveyed within the first
cylindrical internal passageway; and a funnel coupled to the
adapter and having a frusto-conical internal passageway in
substantial axial alignment with the first cylindrical internal
passageway and having inside diameters consistent with the outer
diameter of the subsea structure to accommodate the subsea
structure, the funnel being configured to receive and guide the
subsea structure to be accommodated within the first cylindrical
internal passageway of the adapter and urging the cylindrical
sleeve upward within the first cylindrical internal passageway as
the blowout preventer coupled to the apparatus is being lowered
onto the subsea structure.
2. The apparatus of claim 1, further comprising a slip bowl coupled
between the adapter and the funnel and defining a third cylindrical
internal passageway substantially in axial alignment with the first
and second cylindrical internal passageways and having an inside
diameter consistent with the outer diameter of the subsea structure
to accommodate the subsea structure.
3. The apparatus of claim 1, wherein the cylindrical sleeve is
configured to slide within the first cylindrical internal
passageway of the adapter and its movement is maintained to be
between the sealing assembly and the first cylindrical internal
passageway by a shear element, wherein upon urging by the subsea
structure as the apparatus is being lowered onto the subsea
structure, the cylindrical sleeve being urged to slide upward to an
upper end of the first cylindrical internal passageway of the
adapter.
4. The apparatus of claim 1, further comprising a plurality of lock
screws extending radially inward through the adapter to engage the
sealing assembly.
5. The apparatus of claim 2, further comprising a casing slip
device accommodated within the third cylindrical internal
passageway of the slip bowl configured to mechanically grip an
outer surface of the subsea structure.
6. The apparatus of claim 5, further comprising a plurality of
removable retention screws extending radially through the slip bowl
into the third cylindrical internal passageway to engage the casing
slip device.
7. Apparatus for coupling to a subsea structure having a generally
vertically-oriented elongated cylindrical casing, comprising: an
adapter defining a first cylindrical internal passageway having an
inside diameter consistent with an outer diameter of the subsea
structure to accommodate the subsea structure; a protective sleeve
residing within the first cylindrical internal passageway and
defining a second cylindrical internal passageway substantially in
axial alignment with the first cylindrical internal passageway; a
sealing assembly having at least one sealing element disposed in
the first cylindrical internal passageway and radially between the
adapter and the protective sleeve, the protective sleeve configured
to protect the sealing assembly from wellbore fluids conveyed
within the first cylindrical internal passageway; a slip bowl
coupled to the adapter and defining a third cylindrical internal
passageway substantially in axial alignment with the first and
second cylindrical internal passageways and having an inside
diameter consistent with the outer diameter of the subsea structure
to accommodate the subsea structure; and a funnel coupled to the
slip bowl and having a generally conical internal passageway in
substantial axial alignment with the first cylindrical internal
passageway and having inside diameters consistent with the outer
diameter of the subsea structure to accommodate the subsea
structure, the funnel being configured to receive and guide the
subsea structure to be accommodated within the first cylindrical
internal passageway of the adapter and urging the protective sleeve
upward within the first cylindrical internal passageway as the
blowout preventer coupled to the apparatus is being lowered onto
the subsea structure.
8. The apparatus of claim 7, wherein the protective sleeve is
maintained to be between the sealing assembly and the first
cylindrical internal passageway by a plurality of shear pins,
wherein upon urging by the subsea structure as the apparatus is
being lowered onto the subsea structure, the shear pins give way
and the protective sleeve is urged to slide upward to an upper end
of the first cylindrical internal passageway of the adapter.
9. The apparatus of claim 7, further comprising a plurality of lock
screws extending radially inward through the adapter to engage the
sealing assembly.
10. The apparatus of claim 9, further comprising a plurality of
gland nuts through which the lock screws extend.
11. The apparatus of claim 7, further comprising a casing slip
device accommodated within the third cylindrical internal
passageway of the slip bowl configured to mechanically grip an
outer surface of the subsea structure.
12. The apparatus of claim 11, further comprising a plurality of
removable retention screws extending radially through the slip bowl
into the third cylindrical internal passageway to engage the casing
slip device.
13. The apparatus of claim 7, wherein the adapter is configured for
coupling with at least one of a subsea blowout preventer, a blowout
preventer riser, and a marine drilling riser.
Description
RELATED APPLICATIONS
[0001] This application is a continuation of U.S. application Ser.
No. 16/409,659 filed May 10, 2019, which is a continuation of Ser.
No. 15/361,649 filed Nov. 28, 2016, now U.S. Pat. No. 10,316,606,
which is a continuation of U.S. application Ser. No. 14/870,501
filed Sep. 30, 2015, now U.S. Pat. No. 9,534,467, which is a
continuation of U.S. application Ser. No. 14/095,241 filed Dec. 3,
2013, now U.S. Pat. No. 9,175,551, which claims the benefit U.S.
Provisional Application No. 61/733,039 filed Dec. 4, 2012, the
entire disclosures of which are hereby incorporated herein by
reference.
TECHNICAL FIELD
[0002] This disclosure relates in general to subsea oil and gas
exploration and production operations and, in particular, to
improved apparatus and methods for sealingly engaging subsea
casings during emergency situations such as, for example,
situations involving containing wellbore blowouts.
BACKGROUND OF THE DISCLOSURE
[0003] Several systems are used to facilitate subsea oil and gas
exploration and production operations. Examples include certain
types of subsea blowout preventers (BOPs), which can seal off
wellbores to prevent wellbore blowouts, that is, uncontrolled
releases of oil and gas from the wellbores. In some cases, before,
during or after a blowout prevention operation involving a
producing well, an emergency wellhead connector is engaged with a
subsea casing of the producing well in order to sealingly engage
the subsea casing. However, the sealing elements of the connector
used to effect such a sealing engagement may possibly be damaged by
flowing wellbore fluids or produced fluids, decreasing the efficacy
of the sealing engagement. Also, it is sometimes difficult to
monitor or control the complete engagement of the connector with
the subsea casing. Therefore, what is needed is an apparatus or
method that addresses one or more of the foregoing issues, among
others.
SUMMARY
[0004] In a first aspect, there is provided an apparatus adapted to
be operably coupled to a subsea blowout preventer, the apparatus
including a first tubular member defining a first internal passage
adapted to receive a casing, the first tubular member including
axially opposing first and second end portions, and a first
internal shoulder positioned axially between the first and second
end portions; a counterbore formed in the second end portion of the
first tubular member and coaxial with the first internal passage,
wherein the first internal shoulder of the first tubular member is
defined by the counterbore; a sealing assembly disposed in the
counterbore, the sealing assembly including a sealing element; and
a second tubular member defining a second internal passage, the
second tubular member extending within the first internal passage.
The second tubular member has a first axial position, relative to
the first tubular member, in which the second tubular member covers
the sealing element and thus facilitates protecting the sealing
element from any fluid flow through the first internal passage. The
second tubular member has a second axial position, relative to the
first tubular member, in which the second tubular member does not
cover the sealing element.
[0005] In certain exemplary embodiments, the second tubular member
moves, relative to the first tubular member, from the first axial
position to the second axial position as the casing is received by
the first internal passage.
[0006] In another exemplary embodiment, the first tubular member
includes a second internal shoulder positioned axially between the
first end portion and the first internal shoulder; and wherein,
when the second tubular member is in the second axial position, the
second tubular member abuts the second internal shoulder of the
first tubular member.
[0007] In certain exemplary embodiments, the sealing assembly
defines a first axial length; and wherein the second tubular member
defines a second axial length that is equal to, or greater than,
the first axial length.
[0008] In an exemplary embodiment, the apparatus includes a shear
element engaged with each of the first and second tubular members;
wherein, when the second tubular member is in the first axial
position, the shear element resists relative movement between the
first and second tubular members.
[0009] In another exemplary embodiment, the first end portion of
the first tubular member is adapted to be connected to the subsea
blowout preventer.
[0010] In an exemplary embodiment, the apparatus includes a third
tubular member connected to the first tubular member at the second
end portion thereof, the third tubular member defining a third
internal passage that is coaxial with the first internal passage;
and one or more casing slips at least partially disposed in the
third internal passage.
[0011] In another exemplary embodiment, the sealing assembly abuts
the first internal shoulder of the first tubular member; and
wherein the sealing element is adapted to sealingly engage the
casing after the casing has been received by the first internal
passage.
[0012] In yet another exemplary embodiment, the apparatus includes
a spacer disposed in the counterbore and abutting the sealing
assembly; wherein the sealing assembly is positioned axially
between the spacer and the first internal shoulder of the first
tubular member.
[0013] In a second aspect, there is provided an apparatus adapted
to be operably coupled to a subsea blowout preventer, the apparatus
including a first tubular member defining a first internal passage,
the first tubular member including axially opposing first and
second end portions; a second tubular member defining a second
internal passage, the second tubular member extending within the
first internal passage; and a sealing assembly disposed radially
between the first and second tubular members, the sealing assembly
including a sealing element. The second tubular member covers the
sealing element and thus facilitates protecting the sealing element
from any fluid flow through the first internal passage. The second
tubular member is slidable, within the first internal passage and
relative to the first tubular member, so that the second tubular
member does not cover the sealing element.
[0014] In an exemplary embodiment, the first internal passage is
adapted to receive a casing; and wherein the first end portion of
the first tubular member is adapted to be connected to the subsea
blowout preventer.
[0015] In another exemplary embodiment, the first tubular member
further includes a first internal shoulder positioned axially
between the first and second end portions; wherein the apparatus
further includes a counterbore formed in the second end portion of
the first tubular member and coaxial with the first internal
passage, wherein the first internal shoulder of the first tubular
member is defined by the counterbore; and wherein the sealing
assembly is disposed in the counterbore.
[0016] In yet another exemplary embodiment, the apparatus includes
a spacer disposed in the counterbore and abutting the sealing
assembly, wherein the sealing assembly is positioned axially
between the spacer and the first internal shoulder of the first
tubular member.
[0017] In an exemplary embodiment, the apparatus includes a shear
element engaged with each of the first and second tubular members,
wherein the shear element resists relative movement between the
first and second tubular members.
[0018] In another exemplary embodiment, the apparatus includes a
third tubular member connected to the first tubular member at the
second end portion thereof, the third tubular member defining a
third internal passage that is coaxial with the first internal
passage; and one or more casing slips at least partially disposed
in the third internal passage.
[0019] According to a third aspect, there is provided a method
including providing a connector adapted to be operably coupled to a
subsea blowout preventer; protecting a sealing element of the
connector before engaging the connector with a subsea casing;
engaging the connector with the subsea casing while continuing to
protect the sealing element so that the sealing element is
fluidically isolated from any fluid flow through the connector;
continuing to engage the connector with the subsea casing while
continuing to protect the sealing element until a positive stop for
the subsea casing is achieved; and sealingly engaging the outside
surface of the subsea casing with the sealing element.
[0020] In an exemplary embodiment, the subsea casing is part of a
producing well and thus the sealing element is fluidically isolated
from any flow of wellbore fluids or produced fluids through the
connector during the engagement of the connector with the subsea
casing.
[0021] In another exemplary embodiment, the connector includes a
first tubular member that defines a first internal passage; and
wherein protecting the sealing element before engaging the
connector with the subsea casing includes positioning a second
tubular member at a first position within the first internal
passage so that the second tubular member covers the sealing
element.
[0022] In yet another exemplary embodiment, engaging the connector
with the subsea casing while continuing to protect the sealing
element includes effecting relative movement between the connector
and the subsea casing so that the first internal passage receives
the subsea casing while the first position of the second tubular
member is maintained.
[0023] In an exemplary embodiment, continuing to engage the
connector with the subsea casing while continuing to protect the
sealing element until the positive stop for the subsea casing is
achieved includes continuing to receive the subsea casing within
the first internal passage so that the subsea casing engages the
second tubular member and forces the second tubular member to move,
relative to the first tubular member, within the first internal
passage and away from the sealing element so that the second
tubular member does not cover the sealing element; wherein, during
the relative movement between the first and second tubular members,
the sealing element is covered by the second tubular member, the
first tubular member, or both of the second and first tubular
movements, to continue to protect the sealing element.
[0024] In another exemplary embodiment, the first internal passage
continues to receive the subsea casing, while the sealing element
continues to be protected, until a positive stop for the subsea
casing is achieved.
[0025] In yet another exemplary embodiment, the connector includes
a plurality of casing slips; and wherein the method further
includes mechanically gripping the casing using the plurality of
casing slips.
[0026] Other aspects, features, and advantages will become apparent
from the following detailed description when taken in conjunction
with the accompanying drawings, which are a part of this disclosure
and which illustrate, by way of example, principles of the
inventions disclosed.
BRIEF DESCRIPTION OF DRAWINGS
[0027] The accompanying drawings facilitate an understanding of the
various embodiments.
[0028] FIG. 1 is a sectional view of a connector apparatus adapted
to be operably coupled to a subsea blowout preventer, according to
an exemplary embodiment.
[0029] FIG. 2 is an enlarged view of a portion of FIG. 1, according
to an exemplary embodiment.
[0030] FIG. 3 is a sectional view of an engagement operation
between the connector apparatus of FIGS. 1 and 2 and a casing,
according to an exemplary embodiment.
[0031] FIG. 4 is another sectional view of the engagement operation
between the connector apparatus of FIGS. 1-3 and the casing of FIG.
3, according to an exemplary embodiment.
[0032] FIG. 5 is an enlarged view of a portion of FIG. 4, according
to an exemplary embodiment.
[0033] FIG. 6 is a flow chart illustration of a method of engaging
the connector apparatus of FIGS. 1-5 with the casing of FIGS. 3-5,
according to an exemplary embodiment.
DETAILED DESCRIPTION
[0034] In an exemplary embodiment, as illustrated in FIG. 1, a
connector apparatus is generally referred to by the reference
numeral 10 and is adapted to be connected to a flanged connection
12. In an exemplary embodiment, the flanged connection 12 may be
part of a subsea blowout preventer (BOP), and thus the connector
apparatus 10 may be adapted to be operably coupled to a subsea
blowout preventer. In an exemplary embodiment, the flanged
connection 12 may be part of a BOP riser or marine drilling riser,
which, in turn, may be operably coupled to a subsea blowout
preventer; thus, the connector apparatus 10 may be adapted to be
operably coupled to that subsea blowout preventer via at least the
flanged connection 12. In several exemplary embodiments, instead
of, or in addition to the flanged connection 12, the connector
apparatus 10 may be operably coupled to a subsea blowout preventer
via one or more other connections, such as one or more connections
that extend radially from the adapter 14. In several exemplary
embodiments, by being adapted to be coupled to a subsea blowout
preventer, the connector apparatus 10, the flanged connection 12,
or both, may be considered to be part of that subsea blowout
preventer. In several exemplary embodiments, as will be described
in further detail below, the connector apparatus 10 may be an
emergency wellhead connector that is capable of engaging a subsea
casing, and sealingly engaging same, before, during or after a
blowout prevention operation involving a producing well.
[0035] The connector apparatus 10 includes a tubular member or
adapter 14, a sealing assembly 16, a tubular member or spacer 18, a
tubular member or sleeve 20, a tubular member or slip bowl 22, a
plurality of casing slips 24, and a funnel 26.
[0036] In an exemplary embodiment, as illustrated in FIGS. 1 and 2,
the adapter 14 includes axially opposing end portions 14a and 14b,
and defines an internal passage 14c, which extends between the end
portions 14a and 14b and through the adapter 14. A counterbore 14d
is formed in the end portion 14b, extending upwardly as viewed in
FIG. 1. The counterbore 14d is coaxial with the internal passage
14c. The adapter 14 further includes an internal shoulder 14e,
which is defined by the counterbore 14d and positioned axially
between the end portions 14a and 14b. An internal shoulder 14f is
formed in the inside surface of the adapter 14, and is positioned
axially between the end portion 14a and the internal shoulder 14e.
An internal threaded connection 14g is formed in the inside surface
of the adapter 14 at the end portion 14b. A recess 14h is formed in
the internal shoulder 14e, defining an internal shoulder 14i.
[0037] The sealing assembly 16 is disposed in the counterbore 14d,
and includes sealing elements 16a and 16b. In an exemplary
embodiment, each of the sealing elements 16a and 16b includes one
or more elastomer seals. Lock screws 28a and 28b extend radially
inward through the adapter 14, from the outside surface of the
adapter 14 and into the counterbore 14d, so that the respective
distal ends of the lock screws 28a and 28b engage the sealing
assembly 16. The lock screws 28a and 28b extend through gland nuts
30a and 30b, respectively. In an exemplary embodiment, under
conditions to be described below, the sealing elements 16a and 16b
are adapted to be pressure set, as well as mechanically set. In
several exemplary embodiments, instead of, or in addition to being
adapted to be both pressure and mechanically set, the sealing
elements 16a and 16b may be adapted to be pressure set,
mechanically set, interference set, or to be set using any
combination of the foregoing. The upper end of the sealing assembly
16 abuts the internal shoulder 14e. In several exemplary
embodiments, depending upon the type of sealing system selected for
the sealing assembly 16, the lock screws 28a and 28b and the gland
nuts 30a and 30b may be omitted.
[0038] As shown in FIGS. 1 and 2, the spacer 18 is disposed in the
counterbore 14d so that the spacer 18 abuts the lower end of the
sealing assembly 16. The spacer 18 is connected to the adapter 14.
In an exemplary embodiment, the spacer 18 includes an external
threaded connection 18a, which is threadably engaged with the
internal threaded connection 14g, thereby connection the spacer 18
to the adapter 14. As a result, the sealing assembly 16 is locked,
or captured, between the spacer 18 and the internal shoulder 14e of
the adapter 14.
[0039] The sleeve 20 defines an internal passage 20a, and extends
within the internal passage 14c of the adapter 14 so that the
sealing assembly 16 is disposed radially between the adapter 14 and
the sleeve 20. As shown in FIGS. 1 and 2, the sleeve 20 has an
axial position in which the sleeve 20 covers the sealing elements
16a and 16b, thereby facilitating the protection of the sealing
elements 16a and 16b from any fluid flow through the internal
passage 14c, as will be discussed in further detail below. The
axial length of the sleeve 20 is greater than the axial length of
the sealing assembly 16, thereby ensuring that the sleeve 20 covers
the sealing elements 16a and 16b when the sleeve 20 is in the axial
position shown in FIGS. 1 and 2. In an exemplary embodiment, the
respective axial lengths of the sleeve 20 and the sealing assembly
16 may be equal. Under conditions to be described below, the sleeve
20 is adapted to move or slide within the internal passage 14c of
the adapter 14.
[0040] Shear elements 32a and 32b engage each of the sleeve 20 and
the adapter 14. The shear elements 32a and 32b resist relative
movement between the sleeve 20 and the adapter 14, thereby
maintaining the position of the sleeve 20 shown in FIGS. 1 and 2.
In an exemplary embodiment, the shear elements 32a and 32b extend
radially through the sleeve 20 and into the recess 14h. As a
result, the shear elements 32a and 32b are captured between the
internal shoulder 14i and the upper end of the sealing assembly 16
that abuts the internal shoulder 14e. In several exemplary
embodiments, the shear elements 32a and 32b may be shear pins,
shear fasteners, or any combination thereof.
[0041] As shown in FIG. 1, the slip bowl 22 includes an upper
flange connection 22a, which is connected to the end portion 14b of
the adapter 14, thereby connecting the slip bowl 22 to the adapter
14. An internal passage 22b is defined by the slip bowl 22, and is
coaxial with the internal passage 14c of the adapter 14. A
frusto-conical surface 22c is defined by the internal passage
22b.
[0042] The casing slips 24 are at least partially disposed in the
internal passage 22b of the slip bowl 22. As shown in FIG. 1, at
least a portion of the casing slips 24 are positioned axially
between the end portion 14b of the adapter 14 and the upper flange
connection 22a of the slip bowl 22. The position of the casing
slips 24 are maintained, at least in part, by retention screws 34a
and 34b. The retention screws 34a and 34b extend radially through
the upper flanged connection 22a of the slip bowl 22, from the
outside surface of the upper flanged connection 22a and into the
internal passage 22b, so that the respective distal ends of the
retention screws 34a and 34b engage the casing slips 24.
[0043] The funnel 26 is connected to the slip bowl 22 at the end
portion thereof opposite the upper flanged connection 22a. In an
exemplary embodiment, the funnel 26 is connected to the slip bowl
22 via fasteners, such as pins 36a and 36b. In an exemplary
embodiment, the pins 36a and 36b are quick-release pins.
[0044] In operation, in an exemplary embodiment, as illustrated in
FIG. 3 with continuing reference to FIGS. 1 and 2, the connector
apparatus 10 is lowered in an ocean or sea 38 and towards a subsea
casing 40, which extends from the seabed and past a mudline (not
shown). Below the mudline, the casing 40 extends within a wellbore
(not shown), which traverses one or more subterranean formations
below the seabed. The casing 40 is used in oil and gas exploration
and production operations, and may be part of a producing well. The
connector apparatus 10 is lowered in a direction indicated by an
arrow 42 in FIG. 3. In an exemplary embodiment, the flanged
connection 12 may be lowered along with the connector apparatus 10.
In an exemplary embodiment, the flanged connection 12 is part of a
BOP riser or marine drilling riser, which is lowered along with the
connector apparatus 10.
[0045] Before, and during at least a portion of, the lowering of
the connector apparatus 10 in the ocean or sea 38, the position of
the sleeve 20 shown in FIGS. 1-3 continues to be maintained by the
shear elements 32a and 32b. Thus, the sealing elements 16a and 16b
continue to be disposed radially between adapter 14 and the sleeve
20, with the sleeve 20 continuing to cover the sealing elements 16a
and 16b. As a result, the sleeve 20 facilitates protecting the
sealing elements 16a and 16b from any fluid flow through the
internal passage 14c, including any flow of wellbore fluids or
produced fluids through the internal passage 14c, which flow may
occur during the engagement of the connector apparatus 10 with the
casing 40. The sleeve 20 operates as a protective sleeve,
facilitating the fluidic isolation of the sealing assembly 16 from
any fluid flow through the internal passage 14c, including any flow
of wellbore fluids or produced fluids through the internal passage
14c, thereby protecting the sealing assembly 16 from being damaged
by any wellbore fluids or produced fluids. The sleeve 20 reduces
the risk of, or potential for, damage to the sealing assembly 16,
including any damage to the sealing elements 16a and 16b. By
facilitating the fluidic isolation of the sealing assembly 16 from
the internal passage 14c, the sleeve 20 allows the connector
apparatus 10 to be installed over a producing well without
appreciably damaging the sealing elements 16a and 16b.
[0046] The connector apparatus 10 continues to be lowered in the
ocean or sea 38 and towards the casing 40 for engagement therewith.
The casing 40 is received by the funnel 26, which guides the casing
40 towards the passage 22b of the slip bowl 22, and/or guides the
lowering of the connector apparatus 10. The frusto-conical surface
22c further guides the casing 40, and/or the lowering of the
connector apparatus 10, so that the casing 40, the passage 22b, and
the internal passage 14c are all coaxial. As the connector
apparatus 10 is lowered, the internal passage 14c receives the
casing 40, with the upper end of the casing 40 passing the casing
slips 24, extending within the spacer 18, and engaging the lower
end of the sleeve 20.
[0047] As the connector apparatus 10 continues to be lowered, and
thus installed over, the casing 40, the internal passage 14c
continues to receive the casing 40. As a result, the upper end of
the casing 40 unseats the sleeve 20, causing the shear elements 32a
and 32b to shear, and the sleeve 20 to slide or move upwards in the
internal passage 14c and relative to the adapter 14. As the sleeve
20 slides or moves upwards in the internal passage 14c, relative to
the adapter 14, the casing 40 follows the sleeve 20 so that the
sleeve 20, and/or the casing 40, cover(s) the sealing assembly 16
throughout the relative movement between the sleeve 20 and the
adapter 14, continuously protecting the sealing assembly 16 from
any fluid flow through the internal passage 14c. The casing 40
forces the sleeve 20 to move, relative to the adapter 14, within
the internal passage 14c and away from the sealing elements 16a and
16b so that, eventually, the sleeve 20 does not cover the sealing
elements 16a and 16b.
[0048] In an exemplary embodiment, as illustrated in FIGS. 4 and 5
with continuing reference to FIGS. 1-3, the sleeve 20 continues to
undergo upward displacement relative to the adapter 14, sliding or
moving upwards in the internal passage 14c until the upper end of
the sleeve 20 contacts the internal shoulder 14f of the adapter 14,
at which point the sleeve 20 and the casing 40 stop moving,
relative to the adapter 14. As a result, the sleeve 20 provides a
positive stop for the casing 40, and the achievement of the
positive stop indicates that the connector apparatus 10 is
completely engaged with the casing 40.
[0049] In an exemplary embodiment, after the sleeve 20 and the
casing 40 have stopped moving relative to the adapter 14, the
sealing assembly 16 is disposed radially between the adapter 14 and
the casing 40. Before, or after, the sleeve 20 and the casing 40
have stopped moving relative to the adapter 14, the sealing
assembly 16 is energized or set so that the sealing elements 16a
and 16b sealingly engage the outside surface of the casing 40. In
an exemplary embodiment, the sealing elements 16a and 16b are
pressure set, as well as mechanically set, so that the sealing
elements 16a and 16b sealingly engage the outside surface of the
casing 40. In an exemplary embodiment, to energize or set the
sealing elements 16a and 16b, and/or to ensure the energizing or
setting of the sealing elements 16a and 16b, the lock screws 28a
and 28b are torqued to a predetermined torque level or range, and
the gland nuts 30a and 30b are torqued to a predetermined torque
level or range. In several exemplary embodiments, instead of, or in
addition to being both pressure and mechanically set, the sealing
elements 16a and 16b may be pressure set, mechanically set,
interference set, or set using any combination of the foregoing. In
several exemplary embodiments, as noted above, depending upon the
type of sealing system selected for the sealing assembly 16, the
lock screws 28a and 28b and the gland nuts 30a and 30b may be
omitted.
[0050] In several exemplary embodiments, the sealing engagement
between the sealing elements 16a and 16b and the casing 40 prevent,
or at least reduce, the flow of fluid (including, e.g., production
fluid, produced fluids, or wellbore fluid) along the outside of the
sleeve 20 and/or the casing 40 and across the sealing assembly 16.
In several exemplary embodiments, the sealing elements 16a and 16b
may prevent, or at least reduce, such fluid flow across the sealing
assembly 16 and along the outside surface of the casing 40 in a
downward direction, as viewed in FIGS. 4 and 5. In several
exemplary embodiments, such fluid flow may occur as a result of the
operation of the subsea blowout preventer, to which the connector
apparatus 10 is operably coupled.
[0051] In several exemplary embodiments, the above-described
protection of the sealing elements 16a and 16b, using the sleeve
20, results in little or no damage to the sealing elements 16a and
16b during the above-described installation of the connector 10.
Since the sealing elements 16a and 16b have minimal or no damage,
the protection afforded by the sleeve 20 facilitates the efficacy
of the sealing engagement between the sealing elements 16a and 16b
and the outside surface of the casing 40.
[0052] In an exemplary embodiment, before, during or after the
setting of the sealing elements 16a and 16b, the casing slips 24
engage the outside surface of the casing 40. In an exemplary
embodiment, the casing slips 24 engage the outside surface of the
casing 40 by mechanically gripping the outside surface of the
casing 40. In an exemplary embodiment, to engage the casing slips
24 with the outside surface of the casing 40, the retention screws
34a and 34b are removed from the slip bowl 22, causing the casing
slips 24 to fall down and wedge between the slip bowl 22 and the
casing 40. In an exemplary embodiment, each of the casing slips 24
include teeth, which mechanically grip the outside surface of the
casing 40 after the wedging of the casing slips 24 between the slip
bowl 22 and the casing 40.
[0053] In an exemplary embodiment, before, during or after the
setting of the sealing elements 16a and 16b, the funnel 26 may be
removed from the connector apparatus 10 by removing the pins 36a
and 36b. In an exemplary embodiment, the funnel 26 may include two
or more sections, which together form the funnel 26, and the funnel
26 may be removed from the connector apparatus 10 by removing the
sections.
[0054] In an exemplary embodiment, as shown in FIGS. 4 and 5, the
inside diameter of the sleeve 20 is substantially equal to the
inside diameter of the casing 40. As a result, the sleeve 20 does
not create a choke point for, or does not obstruct, any fluid flow
through the casing 40. In an exemplary embodiment, the inside
diameter of the sleeve 20 is greater than the inside diameter of
the casing 40 so that the sleeve 20 does not obstruct any fluid
flow through the casing 40.
[0055] In several exemplary embodiments, as noted above, the
incorporation of the sleeve 20 into the connector apparatus 10,
with the sleeve 20 fluidically isolating the sealing assembly 16
during the above-described installation of the connector apparatus
10, allows the system to be installed over a producing well.
[0056] In several exemplary embodiments, as noted above, the
connector apparatus 10 may be an emergency wellhead connector that
is capable of engaging a subsea casing, and sealingly engaging
same, before, during or after a blowout prevention operation
involving a producing well. Therefore, in several exemplary
embodiments, the above-described operation may be carried out
before, during, or after a blowout prevention operation involved a
producing well of which the subsea casing 40 may be a part.
Moreover, in several exemplary embodiments, the above-described
operation may be carried out in whole or in part using a
remotely-operated vehicle (ROV).
[0057] In an exemplary embodiment, as illustrated in FIG. 6, a
method is generally referred to by the reference numeral 44 and
includes at step 46 providing a connector adapted to be operably
coupled to a subsea blowout preventer; at step 48 protecting a
sealing element of the connector before engaging the connector with
a subsea casing; at step 50 engaging the connector with the subsea
casing while continuing to protect the sealing element so that the
sealing element is fluidically isolated from any fluid flow through
the connector; at step 52 continuing to engage the connector with
the subsea casing while continuing to protect the sealing element
until a positive stop for the subsea casing is achieved; and at
step 54 sealingly engaging the outside surface of the subsea casing
with the sealing element. In an exemplary embodiment, the subsea
casing is part of a producing well and thus the sealing element is
fluidically isolated from any flow of wellbore fluids or produced
fluids through the connector during the engagement of the connector
with the subsea casing. In an exemplary embodiment, the connector
apparatus includes a first tubular member that defines a first
internal passage, and the step 48 includes positioning a second
tubular member at a first position within the first internal
passage so that the second tubular member covers the sealing
element. In an exemplary embodiment, the step 50 includes effecting
relative movement between the connector and the subsea casing so
that the first internal passage receives the subsea casing while
the first position of the second tubular member is maintained. In
an exemplary embodiment, the step 52 includes continuing to receive
the subsea casing within the first internal passage so that the
subsea casing engages the second tubular member and forces the
second tubular member to move, relative to the first tubular
member, within the first internal passage and away from the sealing
element so that the second tubular member does not cover the
sealing element; during the relative movement between the first and
second tubular members, the sealing element is covered by the
second tubular member, the first tubular member, or both of the
second and first tubular movements, to continue to protect the
sealing element.
[0058] In the foregoing description of certain embodiments,
specific terminology has been resorted to for the sake of clarity.
However, the disclosure is not intended to be limited to the
specific terms so selected, and it is to be understood that each
specific term includes other technical equivalents which operate in
a similar manner to accomplish a similar technical purpose. Terms
such as "left" and right", "front" and "rear", "above" and "below"
and the like are used as words of convenience to provide reference
points and are not to be construed as limiting terms.
[0059] In this specification, the word "comprising" is to be
understood in its "open" sense, that is, in the sense of
"including", and thus not limited to its "closed" sense, that is
the sense of "consisting only of". A corresponding meaning is to be
attributed to the corresponding words "comprise", "comprised" and
"comprises" where they appear.
[0060] In addition, the foregoing describes only some embodiments
of the invention(s), and alterations, modifications, additions
and/or changes can be made thereto without departing from the scope
and spirit of the disclosed embodiments, the embodiments being
illustrative and not restrictive.
[0061] Furthermore, invention(s) have described in connection with
what are presently considered to be the most practical and
preferred embodiments, it is to be understood that the invention is
not to be limited to the disclosed embodiments, but on the
contrary, is intended to cover various modifications and equivalent
arrangements included within the spirit and scope of the
invention(s). Also, the various embodiments described above may be
implemented in conjunction with other embodiments, e.g., aspects of
one embodiment may be combined with aspects of another embodiment
to realize yet other embodiments. Further, each independent feature
or component of any given assembly may constitute an additional
embodiment.
* * * * *