US20210262310A1 - Connector Apparatus for Subsea Blowout Preventer - Google Patents
Connector Apparatus for Subsea Blowout Preventer Download PDFInfo
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- US20210262310A1 US20210262310A1 US17/315,251 US202117315251A US2021262310A1 US 20210262310 A1 US20210262310 A1 US 20210262310A1 US 202117315251 A US202117315251 A US 202117315251A US 2021262310 A1 US2021262310 A1 US 2021262310A1
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- internal passageway
- cylindrical internal
- subsea structure
- adapter
- casing
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- 238000007789 sealing Methods 0.000 claims abstract description 121
- 239000012530 fluid Substances 0.000 claims abstract description 32
- 230000001681 protective effect Effects 0.000 claims description 7
- 230000014759 maintenance of location Effects 0.000 claims description 6
- 210000004907 gland Anatomy 0.000 claims description 5
- 238000005553 drilling Methods 0.000 claims description 3
- 230000008878 coupling Effects 0.000 claims 3
- 238000010168 coupling process Methods 0.000 claims 3
- 238000005859 coupling reaction Methods 0.000 claims 3
- 125000006850 spacer group Chemical group 0.000 description 12
- 230000004323 axial length Effects 0.000 description 6
- 238000000034 method Methods 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 4
- 230000002265 prevention Effects 0.000 description 4
- 230000008901 benefit Effects 0.000 description 2
- 238000009434 installation Methods 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000007792 addition Methods 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 238000005755 formation reaction Methods 0.000 description 1
- 238000010348 incorporation Methods 0.000 description 1
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
- E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/0122—Collecting oil or the like from a submerged leakage
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
- E21B33/064—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers specially adapted for underwater well heads
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/013—Connecting a production flow line to an underwater well head
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Gasket Seals (AREA)
- Connector Housings Or Holding Contact Members (AREA)
- Laying Of Electric Cables Or Lines Outside (AREA)
- Quick-Acting Or Multi-Walled Pipe Joints (AREA)
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.
Description
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- In another exemplary embodiment, the first end portion of the first tubular member is adapted to be connected to the subsea blowout preventer.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- 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 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.
- 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.
- 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.
- 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.
- 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.
- 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.
- The accompanying drawings facilitate an understanding of the various embodiments.
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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. -
FIG. 2 is an enlarged view of a portion ofFIG. 1 , according to an exemplary embodiment. -
FIG. 3 is a sectional view of an engagement operation between the connector apparatus ofFIGS. 1 and 2 and a casing, according to an exemplary embodiment. -
FIG. 4 is another sectional view of the engagement operation between the connector apparatus ofFIGS. 1-3 and the casing ofFIG. 3 , according to an exemplary embodiment. -
FIG. 5 is an enlarged view of a portion ofFIG. 4 , according to an exemplary embodiment. -
FIG. 6 is a flow chart illustration of a method of engaging the connector apparatus ofFIGS. 1-5 with the casing ofFIGS. 3-5 , according to an exemplary embodiment. - In an exemplary embodiment, as illustrated in
FIG. 1 , a connector apparatus is generally referred to by thereference numeral 10 and is adapted to be connected to aflanged connection 12. In an exemplary embodiment, theflanged connection 12 may be part of a subsea blowout preventer (BOP), and thus theconnector apparatus 10 may be adapted to be operably coupled to a subsea blowout preventer. In an exemplary embodiment, theflanged 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, theconnector apparatus 10 may be adapted to be operably coupled to that subsea blowout preventer via at least the flangedconnection 12. In several exemplary embodiments, instead of, or in addition to theflanged connection 12, theconnector 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 theadapter 14. In several exemplary embodiments, by being adapted to be coupled to a subsea blowout preventer, theconnector apparatus 10, theflanged 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, theconnector 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. - The
connector apparatus 10 includes a tubular member oradapter 14, asealing assembly 16, a tubular member orspacer 18, a tubular member orsleeve 20, a tubular member orslip bowl 22, a plurality ofcasing slips 24, and afunnel 26. - In an exemplary embodiment, as illustrated in
FIGS. 1 and 2 , theadapter 14 includes axiallyopposing end portions internal passage 14 c, which extends between theend portions adapter 14. Acounterbore 14 d is formed in theend portion 14 b, extending upwardly as viewed inFIG. 1 . Thecounterbore 14 d is coaxial with theinternal passage 14 c. Theadapter 14 further includes aninternal shoulder 14 e, which is defined by thecounterbore 14 d and positioned axially between theend portions internal shoulder 14 f is formed in the inside surface of theadapter 14, and is positioned axially between theend portion 14 a and theinternal shoulder 14 e. An internal threadedconnection 14 g is formed in the inside surface of theadapter 14 at theend portion 14 b. Arecess 14 h is formed in theinternal shoulder 14 e, defining aninternal shoulder 14 i. - The sealing
assembly 16 is disposed in thecounterbore 14 d, and includes sealingelements elements adapter 14, from the outside surface of theadapter 14 and into thecounterbore 14 d, so that the respective distal ends of the lock screws 28 a and 28 b engage the sealingassembly 16. The lock screws 28 a and 28 b extend throughgland nuts elements elements assembly 16 abuts theinternal shoulder 14 e. In several exemplary embodiments, depending upon the type of sealing system selected for the sealingassembly 16, the lock screws 28 a and 28 b and thegland nuts - As shown in
FIGS. 1 and 2 , thespacer 18 is disposed in thecounterbore 14 d so that thespacer 18 abuts the lower end of the sealingassembly 16. Thespacer 18 is connected to theadapter 14. In an exemplary embodiment, thespacer 18 includes an external threadedconnection 18 a, which is threadably engaged with the internal threadedconnection 14 g, thereby connection thespacer 18 to theadapter 14. As a result, the sealingassembly 16 is locked, or captured, between thespacer 18 and theinternal shoulder 14 e of theadapter 14. - The
sleeve 20 defines aninternal passage 20 a, and extends within theinternal passage 14 c of theadapter 14 so that the sealingassembly 16 is disposed radially between theadapter 14 and thesleeve 20. As shown inFIGS. 1 and 2 , thesleeve 20 has an axial position in which thesleeve 20 covers the sealingelements elements internal passage 14 c, as will be discussed in further detail below. The axial length of thesleeve 20 is greater than the axial length of the sealingassembly 16, thereby ensuring that thesleeve 20 covers the sealingelements sleeve 20 is in the axial position shown inFIGS. 1 and 2 . In an exemplary embodiment, the respective axial lengths of thesleeve 20 and the sealingassembly 16 may be equal. Under conditions to be described below, thesleeve 20 is adapted to move or slide within theinternal passage 14 c of theadapter 14. -
Shear elements sleeve 20 and theadapter 14. Theshear elements sleeve 20 and theadapter 14, thereby maintaining the position of thesleeve 20 shown inFIGS. 1 and 2 . In an exemplary embodiment, theshear elements sleeve 20 and into therecess 14 h. As a result, theshear elements internal shoulder 14 i and the upper end of the sealingassembly 16 that abuts theinternal shoulder 14 e. In several exemplary embodiments, theshear elements - As shown in
FIG. 1 , theslip bowl 22 includes anupper flange connection 22 a, which is connected to theend portion 14 b of theadapter 14, thereby connecting theslip bowl 22 to theadapter 14. Aninternal passage 22 b is defined by theslip bowl 22, and is coaxial with theinternal passage 14 c of theadapter 14. A frusto-conical surface 22 c is defined by theinternal passage 22 b. - The casing slips 24 are at least partially disposed in the
internal passage 22 b of theslip bowl 22. As shown inFIG. 1 , at least a portion of the casing slips 24 are positioned axially between theend portion 14 b of theadapter 14 and theupper flange connection 22 a of theslip bowl 22. The position of the casing slips 24 are maintained, at least in part, byretention screws flanged connection 22 a of theslip bowl 22, from the outside surface of the upperflanged connection 22 a and into theinternal passage 22 b, so that the respective distal ends of the retention screws 34 a and 34 b engage the casing slips 24. - The
funnel 26 is connected to theslip bowl 22 at the end portion thereof opposite the upperflanged connection 22 a. In an exemplary embodiment, thefunnel 26 is connected to theslip bowl 22 via fasteners, such aspins pins - In operation, in an exemplary embodiment, as illustrated in
FIG. 3 with continuing reference toFIGS. 1 and 2 , theconnector apparatus 10 is lowered in an ocean or sea 38 and towards asubsea casing 40, which extends from the seabed and past a mudline (not shown). Below the mudline, thecasing 40 extends within a wellbore (not shown), which traverses one or more subterranean formations below the seabed. Thecasing 40 is used in oil and gas exploration and production operations, and may be part of a producing well. Theconnector apparatus 10 is lowered in a direction indicated by anarrow 42 inFIG. 3 . In an exemplary embodiment, theflanged connection 12 may be lowered along with theconnector apparatus 10. In an exemplary embodiment, theflanged connection 12 is part of a BOP riser or marine drilling riser, which is lowered along with theconnector apparatus 10. - Before, and during at least a portion of, the lowering of the
connector apparatus 10 in the ocean or sea 38, the position of thesleeve 20 shown inFIGS. 1-3 continues to be maintained by theshear elements elements adapter 14 and thesleeve 20, with thesleeve 20 continuing to cover thesealing elements sleeve 20 facilitates protecting the sealingelements internal passage 14 c, including any flow of wellbore fluids or produced fluids through theinternal passage 14 c, which flow may occur during the engagement of theconnector apparatus 10 with thecasing 40. Thesleeve 20 operates as a protective sleeve, facilitating the fluidic isolation of the sealingassembly 16 from any fluid flow through theinternal passage 14 c, including any flow of wellbore fluids or produced fluids through theinternal passage 14 c, thereby protecting the sealingassembly 16 from being damaged by any wellbore fluids or produced fluids. Thesleeve 20 reduces the risk of, or potential for, damage to the sealingassembly 16, including any damage to the sealingelements assembly 16 from theinternal passage 14 c, thesleeve 20 allows theconnector apparatus 10 to be installed over a producing well without appreciably damaging thesealing elements - The
connector apparatus 10 continues to be lowered in the ocean or sea 38 and towards thecasing 40 for engagement therewith. Thecasing 40 is received by thefunnel 26, which guides thecasing 40 towards thepassage 22 b of theslip bowl 22, and/or guides the lowering of theconnector apparatus 10. The frusto-conical surface 22 c further guides thecasing 40, and/or the lowering of theconnector apparatus 10, so that thecasing 40, thepassage 22 b, and theinternal passage 14 c are all coaxial. As theconnector apparatus 10 is lowered, theinternal passage 14 c receives thecasing 40, with the upper end of thecasing 40 passing the casing slips 24, extending within thespacer 18, and engaging the lower end of thesleeve 20. - As the
connector apparatus 10 continues to be lowered, and thus installed over, thecasing 40, theinternal passage 14 c continues to receive thecasing 40. As a result, the upper end of thecasing 40 unseats thesleeve 20, causing theshear elements sleeve 20 to slide or move upwards in theinternal passage 14 c and relative to theadapter 14. As thesleeve 20 slides or moves upwards in theinternal passage 14 c, relative to theadapter 14, thecasing 40 follows thesleeve 20 so that thesleeve 20, and/or thecasing 40, cover(s) the sealingassembly 16 throughout the relative movement between thesleeve 20 and theadapter 14, continuously protecting the sealingassembly 16 from any fluid flow through theinternal passage 14 c. Thecasing 40 forces thesleeve 20 to move, relative to theadapter 14, within theinternal passage 14 c and away from the sealingelements sleeve 20 does not cover thesealing elements - In an exemplary embodiment, as illustrated in
FIGS. 4 and 5 with continuing reference toFIGS. 1-3 , thesleeve 20 continues to undergo upward displacement relative to theadapter 14, sliding or moving upwards in theinternal passage 14 c until the upper end of thesleeve 20 contacts theinternal shoulder 14 f of theadapter 14, at which point thesleeve 20 and thecasing 40 stop moving, relative to theadapter 14. As a result, thesleeve 20 provides a positive stop for thecasing 40, and the achievement of the positive stop indicates that theconnector apparatus 10 is completely engaged with thecasing 40. - In an exemplary embodiment, after the
sleeve 20 and thecasing 40 have stopped moving relative to theadapter 14, the sealingassembly 16 is disposed radially between theadapter 14 and thecasing 40. Before, or after, thesleeve 20 and thecasing 40 have stopped moving relative to theadapter 14, the sealingassembly 16 is energized or set so that the sealingelements casing 40. In an exemplary embodiment, the sealingelements elements casing 40. In an exemplary embodiment, to energize or set the sealingelements elements gland nuts elements assembly 16, the lock screws 28 a and 28 b and thegland nuts - In several exemplary embodiments, the sealing engagement between the sealing
elements 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 thesleeve 20 and/or thecasing 40 and across the sealingassembly 16. In several exemplary embodiments, the sealingelements assembly 16 and along the outside surface of thecasing 40 in a downward direction, as viewed inFIGS. 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 theconnector apparatus 10 is operably coupled. - In several exemplary embodiments, the above-described protection of the sealing
elements sleeve 20, results in little or no damage to the sealingelements connector 10. Since the sealingelements sleeve 20 facilitates the efficacy of the sealing engagement between the sealingelements casing 40. - In an exemplary embodiment, before, during or after the setting of the sealing
elements casing 40. In an exemplary embodiment, the casing slips 24 engage the outside surface of thecasing 40 by mechanically gripping the outside surface of thecasing 40. In an exemplary embodiment, to engage the casing slips 24 with the outside surface of thecasing 40, the retention screws 34 a and 34 b are removed from theslip bowl 22, causing the casing slips 24 to fall down and wedge between theslip bowl 22 and thecasing 40. In an exemplary embodiment, each of the casing slips 24 include teeth, which mechanically grip the outside surface of thecasing 40 after the wedging of the casing slips 24 between theslip bowl 22 and thecasing 40. - In an exemplary embodiment, before, during or after the setting of the sealing
elements funnel 26 may be removed from theconnector apparatus 10 by removing thepins funnel 26 may include two or more sections, which together form thefunnel 26, and thefunnel 26 may be removed from theconnector apparatus 10 by removing the sections. - In an exemplary embodiment, as shown in
FIGS. 4 and 5 , the inside diameter of thesleeve 20 is substantially equal to the inside diameter of thecasing 40. As a result, thesleeve 20 does not create a choke point for, or does not obstruct, any fluid flow through thecasing 40. In an exemplary embodiment, the inside diameter of thesleeve 20 is greater than the inside diameter of thecasing 40 so that thesleeve 20 does not obstruct any fluid flow through thecasing 40. - In several exemplary embodiments, as noted above, the incorporation of the
sleeve 20 into theconnector apparatus 10, with thesleeve 20 fluidically isolating the sealingassembly 16 during the above-described installation of theconnector apparatus 10, allows the system to be installed over a producing well. - 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 thesubsea 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). - In an exemplary embodiment, as illustrated in
FIG. 6 , a method is generally referred to by thereference numeral 44 and includes atstep 46 providing a connector adapted to be operably coupled to a subsea blowout preventer; atstep 48 protecting a sealing element of the connector before engaging the connector with a subsea casing; atstep 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; atstep 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 atstep 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 thestep 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, thestep 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, thestep 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. - 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.
- 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.
- 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.
- 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.
Claims (13)
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.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US17/315,251 US20210262310A1 (en) | 2012-12-04 | 2021-05-07 | Connector Apparatus for Subsea Blowout Preventer |
Applications Claiming Priority (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201261733039P | 2012-12-04 | 2012-12-04 | |
US14/095,241 US9175551B2 (en) | 2012-12-04 | 2013-12-03 | Connector apparatus for subsea blowout preventer |
US14/870,501 US9534467B2 (en) | 2012-12-04 | 2015-09-30 | Connector apparatus for subsea blowout preventer |
US15/361,649 US10316606B2 (en) | 2012-12-04 | 2016-11-28 | Connector apparatus for subsea blowout preventer |
US16/409,659 US11028662B2 (en) | 2012-12-04 | 2019-05-10 | Connector apparatus for subsea blowout preventer |
US17/315,251 US20210262310A1 (en) | 2012-12-04 | 2021-05-07 | Connector Apparatus for Subsea Blowout Preventer |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US16/409,659 Continuation US11028662B2 (en) | 2012-12-04 | 2019-05-10 | Connector apparatus for subsea blowout preventer |
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US20210262310A1 true US20210262310A1 (en) | 2021-08-26 |
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Family Applications (5)
Application Number | Title | Priority Date | Filing Date |
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US14/095,241 Active US9175551B2 (en) | 2012-12-04 | 2013-12-03 | Connector apparatus for subsea blowout preventer |
US14/870,501 Active US9534467B2 (en) | 2012-12-04 | 2015-09-30 | Connector apparatus for subsea blowout preventer |
US15/361,649 Active US10316606B2 (en) | 2012-12-04 | 2016-11-28 | Connector apparatus for subsea blowout preventer |
US16/409,659 Active US11028662B2 (en) | 2012-12-04 | 2019-05-10 | Connector apparatus for subsea blowout preventer |
US17/315,251 Abandoned US20210262310A1 (en) | 2012-12-04 | 2021-05-07 | Connector Apparatus for Subsea Blowout Preventer |
Family Applications Before (4)
Application Number | Title | Priority Date | Filing Date |
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US14/095,241 Active US9175551B2 (en) | 2012-12-04 | 2013-12-03 | Connector apparatus for subsea blowout preventer |
US14/870,501 Active US9534467B2 (en) | 2012-12-04 | 2015-09-30 | Connector apparatus for subsea blowout preventer |
US15/361,649 Active US10316606B2 (en) | 2012-12-04 | 2016-11-28 | Connector apparatus for subsea blowout preventer |
US16/409,659 Active US11028662B2 (en) | 2012-12-04 | 2019-05-10 | Connector apparatus for subsea blowout preventer |
Country Status (6)
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US (5) | US9175551B2 (en) |
EP (1) | EP2929126A4 (en) |
BR (1) | BR112015012867A2 (en) |
CA (1) | CA2915455C (en) |
SG (1) | SG11201504206QA (en) |
WO (1) | WO2014089039A1 (en) |
Families Citing this family (10)
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US11353117B1 (en) | 2020-01-17 | 2022-06-07 | Vulcan Industrial Holdings, LLC | Valve seat insert system and method |
US11421679B1 (en) | 2020-06-30 | 2022-08-23 | Vulcan Industrial Holdings, LLC | Packing assembly with threaded sleeve for interaction with an installation tool |
US11421680B1 (en) | 2020-06-30 | 2022-08-23 | Vulcan Industrial Holdings, LLC | Packing bore wear sleeve retainer system |
US11384756B1 (en) | 2020-08-19 | 2022-07-12 | Vulcan Industrial Holdings, LLC | Composite valve seat system and method |
USD980876S1 (en) | 2020-08-21 | 2023-03-14 | Vulcan Industrial Holdings, LLC | Fluid end for a pumping system |
USD997992S1 (en) | 2020-08-21 | 2023-09-05 | Vulcan Industrial Holdings, LLC | Fluid end for a pumping system |
USD986928S1 (en) | 2020-08-21 | 2023-05-23 | Vulcan Industrial Holdings, LLC | Fluid end for a pumping system |
US11391374B1 (en) | 2021-01-14 | 2022-07-19 | Vulcan Industrial Holdings, LLC | Dual ring stuffing box |
US11434900B1 (en) | 2022-04-25 | 2022-09-06 | Vulcan Industrial Holdings, LLC | Spring controlling valve |
US11920684B1 (en) | 2022-05-17 | 2024-03-05 | Vulcan Industrial Holdings, LLC | Mechanically or hybrid mounted valve seat |
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US3290063A (en) | 1963-09-12 | 1966-12-06 | Shell Oil Co | Power-operated pipe coupling |
US4084842A (en) * | 1976-07-12 | 1978-04-18 | Lawrence Stonitsch | Conduit system with expansion coupling |
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US5860478A (en) * | 1991-07-30 | 1999-01-19 | Exploration & Production Services (North Sea) Ltd. | Sub-sea test tree apparatus |
US6070669A (en) | 1997-02-15 | 2000-06-06 | Abb Vetco Gray Inc. | Adjustable wellhead connector |
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US6336508B1 (en) | 2000-01-21 | 2002-01-08 | Shell Oil Company | Subsea, releasable bop funnel |
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US7240735B2 (en) | 2003-12-10 | 2007-07-10 | Vetco Gray Inc. | Subsea wellhead assembly |
GB2440940B (en) | 2006-08-18 | 2009-12-16 | Cameron Internat Corp Us | Wellhead assembly |
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-
2013
- 2013-12-03 SG SG11201504206QA patent/SG11201504206QA/en unknown
- 2013-12-03 WO PCT/US2013/072807 patent/WO2014089039A1/en active Application Filing
- 2013-12-03 US US14/095,241 patent/US9175551B2/en active Active
- 2013-12-03 EP EP13861377.3A patent/EP2929126A4/en not_active Withdrawn
- 2013-12-03 BR BR112015012867A patent/BR112015012867A2/en not_active Application Discontinuation
- 2013-12-03 CA CA2915455A patent/CA2915455C/en active Active
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2015
- 2015-09-30 US US14/870,501 patent/US9534467B2/en active Active
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2016
- 2016-11-28 US US15/361,649 patent/US10316606B2/en active Active
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2019
- 2019-05-10 US US16/409,659 patent/US11028662B2/en active Active
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2021
- 2021-05-07 US US17/315,251 patent/US20210262310A1/en not_active Abandoned
Also Published As
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EP2929126A4 (en) | 2016-11-16 |
US20140151059A1 (en) | 2014-06-05 |
CA2915455C (en) | 2020-10-27 |
BR112015012867A2 (en) | 2017-07-11 |
WO2014089039A1 (en) | 2014-06-12 |
CA2915455A1 (en) | 2014-06-12 |
US11028662B2 (en) | 2021-06-08 |
SG11201504206QA (en) | 2015-06-29 |
US20170074064A1 (en) | 2017-03-16 |
US9175551B2 (en) | 2015-11-03 |
US20190264523A1 (en) | 2019-08-29 |
US9534467B2 (en) | 2017-01-03 |
US10316606B2 (en) | 2019-06-11 |
US20160017682A1 (en) | 2016-01-21 |
EP2929126A1 (en) | 2015-10-14 |
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