WO2014028365A2 - Système et procédé permettant une production, au moyen d'une suspension de tubes de production à alésages multiples, vers un collecteur sous-marin sans modifications du bop - Google Patents

Système et procédé permettant une production, au moyen d'une suspension de tubes de production à alésages multiples, vers un collecteur sous-marin sans modifications du bop Download PDF

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Publication number
WO2014028365A2
WO2014028365A2 PCT/US2013/054483 US2013054483W WO2014028365A2 WO 2014028365 A2 WO2014028365 A2 WO 2014028365A2 US 2013054483 W US2013054483 W US 2013054483W WO 2014028365 A2 WO2014028365 A2 WO 2014028365A2
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WO
WIPO (PCT)
Prior art keywords
spool
production
connector
bore
alignment
Prior art date
Application number
PCT/US2013/054483
Other languages
English (en)
Other versions
WO2014028365A3 (fr
WO2014028365A9 (fr
Inventor
Donald Graham ALLAN
David John Parker
Gregory Richard BLOME
Original Assignee
Bp Corporation North America, Inc.
Bp Exploration Operating Company Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Bp Corporation North America, Inc., Bp Exploration Operating Company Limited filed Critical Bp Corporation North America, Inc.
Publication of WO2014028365A2 publication Critical patent/WO2014028365A2/fr
Publication of WO2014028365A9 publication Critical patent/WO2014028365A9/fr
Publication of WO2014028365A3 publication Critical patent/WO2014028365A3/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • E21B33/047—Casing heads; Suspending casings or tubings in well heads for plural tubing strings
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/04—Manipulators for underwater operations, e.g. temporarily connected to well heads
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK 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

Definitions

  • the invention relates generally to systems and methods for producing hydrocarbon fluids through a multi bore tubing hanger to a subsea manifold. More particularly, the invention relates to systems and methods that reduce and/or eliminate conventional BOP modifications necessary to align the multi bore tubing hanger during installation.
  • a production guide base is typically mounted to and run with the conductor during the well spud.
  • the PGB usually includes a radially extending arm that supports a jumper spool having a production inlet connector and a production outlet connector.
  • a production tubing string is run through the BOP stack, and a tubing hanger at the upper end of the production tubing string is landed in a mating profile inside the wellhead. Thereafter, bores in the tubing hanger are temporarily closed, and the drilling BOP stack is removed. Next, a production tree having a production bore and associated valves is lowered subsea and mounted to the wellhead, effectively replacing the BOP stack.
  • the production tree includes a production spool with an outlet that connects to the production inlet of the PGB jumper spool.
  • the production spool is in fluid communication with the production bore in the tree, which in turn, is in fluid communication with the production bore of the tubing hanger.
  • a rigid preconfigured jumper is lowered subsea and coupled to the production outlet of the PGB jumper spool and an inlet of a subsea manifold, thereby providing fluid communication between the PGB jumper spool and the manifold. Accordingly, hydrocarbon fluids produced from the wellbore flow through the production tubing and production bore of the tubing hanger, through the production bore and production spool of the tree, and through the PGB jumper spool and jumper to the subsea manifold.
  • the jumper connecting the PGB jumper spool and the manifold is rigid and preconfigured based on metro logical data obtained after permanent installation of the PGB and subsea manifold. Thus, once deployed, the distance between the inlet and outlet of the jumper, as well as the relative heights of the inlet and outlet of the jumper are fixed.
  • the PGB is rotationally oriented about the primary conductor such that the production outlet of the jumper spool is located within a specific, pre-determined position to allow the rigid jumper to simultaneously connect to the outlet of the jumper spool and the corresponding inlet of the manifold while avoiding interference with neighboring wells, and associated plumbing, tied into the same subsea manifold.
  • the tree must be rotationally oriented in a specific position such that the production spool of the tree is circumferentially aligned with the production inlet of the jumper spool for mating connection therebetween.
  • the rotational orientation of the tree relative to the tubing hanger is generally irrelevant for mono bore and concentric tubing hangers as the centered production bore in the tubing hanger will always be coaxially aligned with the production bore of the production tree regardless of the rotational orientation of the tree relative to the tubing hanger.
  • this is not the case with conventional dual bore tubing hangers, and thus, the installation and rotational orientation of the PGB, the tubing hanger, and the production tree must be carefully controlled and monitored.
  • the PGB must be oriented in a specific rotational orientation when run in with the primary conductor, and further, the multi bore tubing hanger must be installed in a specific rotational orientation to enable alignment and connection with the tubing hanger bores (i.e., alignment and mating engagement between stabbing members on the lower end of the tree and the bores in the tubing hanger) and the inlet of the PGB jumper spool (i.e., alignment and mating engagement between the production spool of the tree and the inlet of the PGB jumper spool).
  • the tubing hanger bores i.e., alignment and mating engagement between stabbing members on the lower end of the tree and the bores in the tubing hanger
  • the inlet of the PGB jumper spool i.e., alignment and mating engagement between the production spool of the tree and the inlet of the PGB jumper spool.
  • the PGB and the tubing hanger must be rotationally oriented to allow the production tree to simultaneously mate and engage the tubing hanger bores and the inlet of the properly positioned jumper spool.
  • the BOP stack, production tree, tubing hanger, or combinations thereof include alignment mechanisms (e.g., mating pins and guides) that facilitate the proper rotational alignment of such components to enable the specific positioning of the PGB jumper spool outlet for connection to the rigid jumper.
  • alignment mechanisms e.g., mating pins and guides
  • complex running, retrieval, installation, and testing tools may be necessary to achieve and assure proper alignment of these components.
  • Such alignment mechanisms often necessitate time consuming, expensive, and complex custom modifications to the BOP stack, production tree, tubing hanger, or combinations thereof.
  • implementation of select alignment mechanisms and tools may dictate the type of rig that must be employed, thereby limiting the number of available rigs that can be used for a particular job.
  • the system comprises a primary conductor extending into the seabed.
  • the system comprises a wellhead disposed at an upper end of the primary conductor.
  • the system comprises a multi bore tubing hanger seated in the wellhead. The tubing hanger including a first bore and a second bore.
  • the system comprises a production tree mounted to the wellhead.
  • the production tree includes a spool body, a first stabbing member extending from the spool body and disposed in the first bore, a second stabbing member extending from the spool body and disposed in the second bore, and a production spool extending radially from the spool body, wherein the production spool has an end comprising a connector.
  • the system comprises a rotatable production guide base coupled to the primary conductor.
  • the production guide base is configured to rotate about the wellhead and releasably lock on to the upper end of the conductor.
  • the production guide base includes an annular connector disposed about the primary conductor, a support frame extending radially from the annular connector, and a rigid alignment spool mounted to the support frame.
  • the alignment spool has a first end comprising a first connector releasably coupled to the connector of the production spool, a second end comprising a second connector, and non-linear deviation positioned between the first end and the second end.
  • the method comprises (a) running a multi bore tubing hanger into a wellhead, the tubing hanger including a first bore and a second bore.
  • the method comprises (b) determining the rotational orientation of the tubing hanger after (a).
  • the method comprises (c) constructing an alignment spool based on the rotational position of the tubing hanger.
  • the method comprises (d) coupling the alignment spool to a rotatable production guide base.
  • the production guide base is configured to rotate about the wellhead.
  • the method comprises (a) running a multi bore tubing hanger into a wellhead, the tubing hanger including a first bore and a second bore.
  • the method comprises (b) constructing a rigid alignment spool after (a).
  • the alignment spool has a first end comprising a first connector, a second end comprising a second connector.
  • the method comprises (c) mounting the alignment spool to a support frame of a rotatable production guide base after (b).
  • the production guide base is configured to rotate about the wellhead.
  • Embodiments described herein comprise a combination of features and advantages intended to address various shortcomings associated with certain prior devices, systems, and methods.
  • the foregoing has outlined rather broadly the features and technical advantages of the invention in order that the detailed description of the invention that follows may be better understood.
  • the various characteristics described above, as well as other features, will be readily apparent to those skilled in the art upon reading the following detailed description, and by referring to the accompanying drawings. It should be appreciated by those skilled in the art that the specific embodiments disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same purposes of the invention. It should also be realized by those skilled in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims.
  • Figure 1 is a schematic top view of a dual bore tubing hanger
  • Figure 2 is a schematic cross-sectional side view of the dual bore tubing hanger of Figure 1;
  • Figure 3 is a schematic cross-sectional side view of a production tree
  • Figure 4A is a schematic top view of a conventional production guide base
  • Figure 4B is a schematic cross-sectional side view of the production guide base of
  • Figure 5A is a schematic top view of a jumper
  • Figure 5B is a schematic cross-sectional side view of the jumper of Figure 5 A;
  • Figure 6 is a schematic top view of a subsea template illustrating the connection of the jumper of Figure 5 A to the jumper spool of Figure 4A;
  • Figures 7A-7D are sequential schematic illustrations of the completion of a well in the subsea template of Figure 6 utilizing the dual bore tubing hanger of Figure I, the production tree of Figure 3, the production guide base of Figure 4A, and the jumper of Figure 5A;
  • Figure 8 is a schematic top view of an embodiment of a rotatable production guide base including a modified jumper spool.
  • Figures 9A-9D are sequential schematic illustrations of an embodiment of a method for completing a well in the subsea template of Figure 6 utilizing the dual bore tubing hanger of Figure 1, the production tree of Figure 3, the rotatable production guide base of Figure 8, and the jumper of Figure 5 A; and
  • Figures 10A-10D are schematic illustrations of an embodiment of a method for completing a well in the subsea template of Figure 6 utilizing the dual bore tubing hanger of Figure 1, the production tree of Figure 3, the rotatable production guide base of Figure 8, and the jumper of Figure 5A at four different, exemplary rotational orientations of the dual bore tubing hanger within the wellhead.
  • the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to... .”
  • the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection, or through an indirect connection via other devices, components, and connections.
  • the terms “axial” and “axially” generally mean along or parallel to a central axis (e.g., central axis of a body or a port), while the terms “radial” and “radially” generally mean perpendicular to the central axis. For instance, an axial distance refers to a distance measured along or parallel to the central axis, and a radial distance means a distance measured perpendicular to the central axis.
  • Hanger 10 has a central or longitudinal axis 15 and includes a hanger body 11, a production tubing string 12 extending axially downward from body 11, and a secondary or annulus tubing string 13 extending axially downward from body 11.
  • Strings 12, 13 are oriented parallel to each other, but radially offset from axis 15.
  • a production bore 14 extends through body 11 and production tubing string 12, and a secondary or annulus bore 16 extends though body 11 and annulus tubing string 13.
  • production tubing string 12 extends downward and provides fluid communication with a production zone in the well
  • secondary tubing string 13 extends downward and provides fluid communication with the "A" annulus disposed below tubing hanger 10 between the production casing string and tubing packed off at a deeper location to isolate the production reservoir from the annulus.
  • Counterbores or recesses 17, 18 extend axially from the upper end of body 11 to bores 14, 16.
  • Counterbores 17, 18 are coaxially aligned with bores 14, 16, respectively, and strings 12, 13, respectively, and thus, are also radially offset from axis 15.
  • the radially outer surface of hanger body 11 includes an annular shoulder 19 configured to engage a mating annular seat provided on the inside of the wellhead.
  • hanger body 11 When hanger body 11 is seated within the annular seat on the inside of the wellhead, strings 12, 13 are suspended or hung into the wellbore from hanger body 11, which in turn is supported by the wellhead.
  • dual bore hangers such as hanger 10 can also include hydraulic and electrical connections to provide control or monitoring of completion installed valves and gauges.
  • Tree 20 includes a spool body 21 having a central axis 25 and a downward facing female connector 22, a production spool 30 extending radially outward from body 21, a production bore stabbing member 24, and an annulus bore stabbing member 26.
  • a production flow bore 27 extends axially through body 21 and stabbing member 24, and an annulus flow bore 28 extends axially through body 21 and stabbing member 26.
  • Valves 27a, 28a control the flow of fluids through bores 27, 28, respectively.
  • Connector 22 is configured to releasably engage a mating upward facing male connector or hub on the wellhead.
  • connector 22 may comprise any suitable hydraulically actuated releasable wellhead-type mechanical connector that is compatible with the corresponding wellhead hub.
  • suitable connectors include, without limitation, the H-4® profile subsea connector available from VetcoGray Inc. of Houston, Texas or the DWHC profile subsea connector available from Cameron International Corporation of Houston, Texas.
  • Stabbing members 24, 26 are sized and positioned to simultaneously engage mating counterbores 17, 18, respectively, upon connection of tree 20 to the wellhead, thereby placing bores 27, 28 in fluid communication with strings 12, 13, respectively.
  • Production spool 30 extends radially outward and axially downward from spool body 21 and includes a production flow bore 31 in selective fluid communication with bore 27 and a downward facing female connector 32 at its end distal body 21 for connection to the inlet of the PGB jumper spool.
  • connector 32 may comprise any suitable hydraulically actuated releasable mechanical connector that is compatible with the corresponding connector or hub on the jumper spool.
  • connector 32 is a single bore vertical connector in this embodiment, in general, the production spool (e.g., spool 30) can utilize vertical or horizontal connectors and/or be single or multi-bore.
  • PBG 40 includes an annular downward facing female connector 41, a support frame or arm 42 extending radially outward from connector 41, and a jumper spool 43 mounted to support arm 42.
  • Connector 41 is configured to be disposed about the wellhead and releasably engage the upper end of the primary conductor or low pressure housing extending into the seabed and to which the wellhead is secured.
  • connector 41 may comprise any suitable hydraulically actuated releasable wellhead-type mechanical connector that is compatible with the corresponding wellhead hub.
  • PGB 40 once connector 41 is locked onto the conductor and wellhead, PGB 40 is prohibited from being rotated about the wellhead.
  • Jumper spool 43 is a rigid fluid conduit including a radially inner inlet end 43 a and a radially outer outlet end 43b. Each end 43 a, 43b comprises an upward facing male connector or hub 46, 47, respectively. Hub 46 is configured to releasably engage mating female connector 32 of production spool 30.
  • connector 46 may comprise any suitable hydraulically actuated releasable mechanical connector that is compatible with connector 32 on production spool 30. Examples of suitable connectors include, without limitation, mini CVC connectors made by Cameron International Corporation of Houston, Texas, OptimaTM subsea connectors made by Vector Technology Group of Drammen, Norway, or other connectors of the like known in the art.
  • hub 47 at outlet end 43b is configured to releasably engage a mating female connector on an inlet end of a rigid jumper.
  • jumper spool 43 is a rigid linear conduit having ends 43a, 43b comprising upturned connectors 46, 47. Further, jumper spool 43 is radially oriented relative to connector 41, namely, jumper spool 43 extends along a horizontal axis 43 a that intersects a vertical central axis 41a of connector 41.
  • Jumper 50 is an elongate conduit having a central or longitudinal axis 55, a first or inlet end 50a, a second or outlet end 50b, and a production bore or passage 51 extending between ends 50a, 50b.
  • Each end 50a, 50b comprises a downward facing female connector 52, 53, respectively.
  • Connector 52 is configured to releasably engage mating male hub 47 of jumper spool 43 (shown in phantom in Figure 5)
  • connector 53 is configured to releasably engage a mating male hub 61 of a subsea manifold 60 (shown in phantom in Figure 5B).
  • each connector 52, 53 may comprise any suitable hydraulically actuated releasable mechanical connector that is compatible with connector 47, 61, respectively.
  • suitable connectors include, without limitation, mini CVC connectors made by Cameron International Corporation of Houston, Texas, OptimaTM subsea connectors made by Vector Technology Group of Drammen, Norway, or other connectors of the like known in the art.
  • connectors 52, 53 of jumper 50 are designed for vertical connections, in other embodiments, one or both of the connectors on the jumper (e.g., connectors 52, 53 on the ends of jumper 50) may be designed for horizontal connections.
  • jumper 50 is a rigid conduit specifically designed and constructed to extend between hubs 47, 61. Based on the pre-determined layout of the subsea template (i.e., relative locations of a cluster of wells around a manifold) and final metrology, jumper 50 is dimensioned such that ends 50a, 50b are vertically spaced relative to each other to account for the vertical distance D between hubs 47, 61, and such that ends 50a, 50b are horizontally spaced apart a length L measured between hubs 47, 61.
  • length L is the horizontal distance between hubs 47, 61 after installation with hub 47 disposed at the desired predetermined position "A” and hub 61 disposed at predetermined position "B.” If hub 47 is not disposed at, or sufficiently proximal, the specific position "A", jumper 50 could be custom built to connect to both hubs 47, 61, but may interfere with neighboring wells or other subsea plumbing connected to manifold 60. As a result, the positioning of hub 47 at position "A" is vital during installation of conventional PGB 40. As will be described in more detail below, the proper positioning of hub 47 of conventional PGB 40 is achieved by carefully aligning and orienting various components during completion of the wellbore
  • FIGS 7A-7D the completion of a subsea wellbore is schematically illustrated.
  • a primary conductor 91 extends downward into the seabed.
  • PGB 40 is run in and installed with conductor 91, and thus, PGB 40 is mounted to the upper end of conductor 91 with hub 47 in position "A".
  • Wellhead 95 is secured within conductor 91 and comprises an upward facing male connector or hub 96 at its upper end.
  • a BOP stack 100 is mounted to wellhead 95.
  • BOP stack 100 includes a downward facing female connector 101 that releasably engages hub 96.
  • connector 101 may comprise any suitable hydraulically actuated releasable wellhead-type mechanical connector that is compatible with wellhead hub 96.
  • suitable connectors include, without limitation, the H-4® profile subsea connector available from VetcoGray Inc. of Houston, Texas or the DWHC profile subsea connector available from Cameron International Corporation of Houston, Texas.
  • BOP stack 100 has been modified and is rotationally oriented in a specific position relative to PBG 40 to enable proper alignment of tubing hanger 10 and production tree 20 relative to PGB 40.
  • dual bore tubing hanger 10 is run through BOP stack 100 and set in wellhead 95.
  • annular shoulder 19 on the outside of tubing hanger body 11 is seated against a mating annular seat 97 provided on the inside of wellhead 95.
  • Strings 12, 13 extend downhole from hanger body 11.
  • BOP stack 100 is removed from wellhead 95 by hydraulically actuating connector 101 to unlock and release hub 96.
  • bores 14, 16 are temporarily closed (e.g., closed with valves in tubing strings 12, 13 or plugs run with wireline) to isolate the flow of hydrocarbons from the well.
  • production tree 20 is lowered subsea and mounted to wellhead 95 via engagement of connector 22 and hub 96.
  • Tree 20 is rotationally oriented such that stabbing members 24, 26 are aligned with and engage mating counterbores 17, 18, respectively, and simultaneously, connector 32 is aligned with and engages mating hub 46 of jumper spool 43 as tree 20 is connected to wellhead 95.
  • jumper 50 is lowered subsea and connected to jumper spool 43 and manifold 60.
  • connector 52 is releasably coupled to hub 47 and connector 53 is releasably coupled to hub 61.
  • BOP stacks are modified to include alignment mechanism(s) to facilitate the orientation of the BOP stack relative to the PGB and the orientation of the tubing hanger (as the tubing hanger is run through the BOP stack set within the wellhead) to enable the production tree to engage both the tubing hanger counterbores and the inlet connector of the PGB jumper spool.
  • BOP stack 100 has been modified to include an external orientation funnel (not shown) at its lower end and an inner orientation pin (not shown) extending radially inward about one inch into the main bore of BOP stack 100. The orientation pin is designed to engage a helical orientation recess on the outer surface of the completion landing string that runs in tubing hanger 10.
  • the orientation funnel is configured to rotationally orient BOP stack 100, and hence the orientation pin, to a specific position that allows sliding engagement of the orientation pin and helical recess to rotate tubing hanger 10 into near perfect (i.e., within 1°) rotational orientation relative to PGB 40 as tubing hanger 10 is lowered with the completion landing string.
  • the orientation funnel orients the pin in BOP stack 100 such that it can properly orient tubing hanger 10 relative to PGB 40 to enable simultaneous engagement of (a) production spool connector 32 of production tree 20 and jumper spool hub 46 of PGB 40, and (b) stabbing members 24, 26 of production tree 20 and counterbores 17, 18, respectively, of tubing hanger 10.
  • embodiments described herein offer the potential to eliminate the need for such alignment mechanisms by employing a rotatable PGB in conjunction with a modified jumper spool and/or jumper.
  • embodiments described herein offer the potential to eliminate the need for complex running, retrieval, installation, and testing tools such as completion landing strings.
  • PGB 40' may comprise any PGB known in the art capable of and configured to be rotated about the conductor and wellhead. Examples of known rotatable PGBs are disclosed in U.S. Patent No. 6,968,902, which is hereby incorporated herein by reference in its entirety for all purposes.
  • rotatable PGB 40' includes a annular downward facing female connector 4 , a support frame 42' disposed about and extending radially from connector 4 , and an alignment spool 43' mounted to support frame 42'.
  • Connector 41 ' is configured to be disposed about the wellhead and the upper end of the primary conductor, rotated about wellhead 95 and conductor 91, and releasably locked to the primary conductor at the desired rotational position.
  • connector 41 ' may be configured similarly to ring 125 disclosed in U.S. Patent No. 6,968,902.
  • Alignment spool 43' is a rigid fluid conduit including a radially inner inlet end 43 a' and a radially outer outlet end 43b'. Each end 43a', 43b' comprises an upward facing male connector or hub 46, 47, respectively, each as previously described.
  • Hub 46 is configured to releasably engage mating female connector 32 of production spool 30, and hub 47 is configured to releasably engage mating female connector 52 of jumper 50.
  • connectors 46, 47 are designed for vertical connections in this embodiment, in other embodiments, one or both of the connectors on the alignment spools (e.g., connectors 46, 47 on the ends of alignment spool 43') may be designed for horizontal connections.
  • jumper spool 43 of conventional PGB 40 is a rigid linear conduit fixed in a radial orientation relative to corresponding connector 41.
  • alignment spool 43 ' is custom built and includes a non-linear deviation or bend 44' between ends 43a', 43b'.
  • alignment spool 43' mounted to frame 42' includes a first portion 44a' extending from end 43a' to deviation 44' and a second portion 44b' extending from end 43b' to deviation 44'.
  • First portion 44a' is oriented at an angle a relative to second portion 44b'.
  • angle a can be varied as necessary to enable simultaneous connection between hub 46 and connector 32, hub 47 and connector 52, and connector 53 and hub 61.
  • the alignment spool e.g., spool 43'
  • the alignment spool may include more than one deviation (e.g., deviation 44').
  • deviation 44' is shown as a discrete bend, in general, the deviation (e.g., deviation 44') may have any non-linear geometry such as an elbow, a smooth curve, an arcuate shape, etc.
  • FIGs 9A-9D sequential schematic illustrations of an embodiment of a completion operation employing rotatable PGB 40' in accordance with the principles described herein is shown.
  • FIG 9A the installation and landing of tubing hanger 10 in wellhead 95 secured to primary conductor 91 is shown.
  • the BOP stack is not shown in Figure 9A, although it should be appreciated that tubing hanger 10 is run through the BOP stack.
  • Figure 9B the installation of rotatable PGB 40' is shown.
  • FIG 9C production tree 20 is shown being installed following removal of the BOP stack, and PGB 40' is shown being rotated during installation of tree 20 to align hub 46 with connector 32 of production spool 20.
  • FIG 9D the connection of jumper 50 to alignment spool 43' and manifold 60 is shown.
  • rotatable PGB 40' is not run and installed with primary conductor 91. Rather, in this embodiment, PGB 40' is installed during completion after running dual bore tubing hanger 10.
  • dual bore tubing hanger 10 is run through the BOP stack mounted to wellhead 95 and set in wellhead 95 as previously described. Due to the use of rotatable PGB 40' and custom built alignment spool 43' described in more detail below, tubing hanger 10 can be disposed in any rotational orientation.
  • tubing hanger 10 can be installed without concern for its rotational orientation. Accordingly, the BOP stack need not be modified to enable a specific orientation of tubing hanger 10. Thus, the alignment mechanism in the BOP stack (e.g., orientation funnel, orientation pin, etc.) can be eliminated.
  • the alignment mechanism in the BOP stack e.g., orientation funnel, orientation pin, etc.
  • the number and type of deviations 44' in alignment spool 43' are selected to enable (a) positioning of hub 46 such that production tree 20 can simultaneously mate and engage tubing hanger 10 and hub 46, and (b) positioning hub 47 in position "A" such that jumper 50 can connect to both hubs 47, 61 while being located in a desirable position (e.g., so as not to interfere with neighboring wells).
  • alignment spool 43' is custom designed and constructed based on the final positions of tubing hanger 20 and the desired position "A" for hub 47.
  • FIG. 9C With PGB 40' aligned with tubing hanger 10, production tree 20 is lowered subsea and installed.
  • tree 20 is rotationally oriented such that stabbing members 24, 26 are aligned with mating counterbores 17, 18, respectively, and connector 32 is aligned with hub 46.
  • angle a between sections 44a', 44b' of alignment spool 43' is selected such that hub 47 is located in position "A" when hub 46 is aligned with connector 32, even though connector 32 is circumferentially offset from hub 47.
  • embodiments described herein eliminate the need for modification of a BOP stack to include alignment mechanisms to rotationally orient a multi bore tubing hanger within a wellhead in a particular orientation.
  • variations in the rotational orientation of the tubing hanger within the wellhead are accommodated by employing a modified/customized alignment spool (based on the final installed positions of the tubing hanger and the subsea manifold) mounted to a rotatable production guide base.
  • modifications to the jumper spool as described herein are simpler, less time consuming, and less expensive that the conventional modification of the BOP to include alignment mechanisms to orient the tubing hanger.
  • rotational orientation of the tubing hanger is generally irrelevant, complex running, retrieval, installation, and testing tools such as completion landing strings can be eliminated, thereby expanding the appropriate choices for the rig to perform the job.
  • alignment spool 43' included a single deviation 44' to account for the slight circumferential misalignment of tubing hanger 10 and production tree 20 relative to manifold hub 61 and the desired position "A" of hub 47.
  • the custom built alignment spool e.g., spool 43'
  • FIGS 10A-10D embodiments of rotatable PGBs 40-1, 40-2, 40-3, 40-4, respectively, that include a connector 41 ' and support frame 42' as previously described.
  • PGBs 40-1, 40-2, 40-3, 40-4 include alignment spools 43-1, 43-2, 43-3, 43-4, respectively, that accommodate a variety of different, exemplary misalignment scenarios.
  • alignment spool 43-1 extends across frame 42' and includes one deviations 44' to account for about a 45° misalignment between outlet hub 47 of alignment spool 43-1 and the desired position "A".
  • alignment spool 43-2 extends across frame 42' and includes two deviations 44' to account for about a 125° misalignment between outlet hub 47 of alignment spool 43-2 and the desired position "A".
  • alignment spool 43-3 extends across frame 42' and includes three deviations 44' to account for about a 180° misalignment between outlet hub 47 of alignment spool 43-3 and the desired position "A”.
  • alignment spool 43-4 extends across frame 42' and includes one deviation 44' to account for about a -120° misalignment between outlet hub 47 of alignment spool 43-4 and the desired position "A".
  • Each rotatable PGB 40-1, 40-2, 40-3, 40-4 is installed in the same manner as rotatable PGB 40' previously described. Since frame 42' extends around and radially outward from connector 41 ', frame 42' and provide sufficient support to the alignment spool (e.g., alignment spool 43-1, 43-2, 43-3, 43-4) regardless of the specific positions of connectors 46, 47.
  • alignment spools 43-1, 43-2, 43-3, 43-4 are custom built to accommodate specific, exemplary misalignment scenarios. However, in general, customization of the alignment spool can be made to suit any desired position of the outlet hub (e.g., hub 47) regardless of the rotational orientation of the dual bore tubing hanger (e.g., tubing hanger 10).

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

La présente invention concerne un système permettant de produire des hydrocarbures à partir d'un puits de forage sous-marin et comprenant un conducteur primaire s'étendant dans le plancher océanique. En outre, le système comprend une tête de puits disposée au niveau d'une extrémité supérieure du conducteur primaire. En outre, le système comprend une suspension de tubes de production à alésages multiples installée dans la tête de puits. En outre, le système comprend un arbre de production monté dans la tête de puits. L'arbre de production comprend un corps de manchette et une manchette de production s'étendant radialement à partir du corps de manchette. La manchette de production possède une extrémité comprenant un connecteur. En outre, le système comprend une base de guidage de production rotative accouplée au conducteur primaire et conçue pour tourner autour de la tête de puits. La base de guidage de production comprend une manchette d'alignement rigide. La manchette d'alignement possède une première extrémité accouplée de façon libérable à la manchette de production, une seconde extrémité comprenant un second connecteur, et une déviation non linéaire positionnée entre la première extrémité et la seconde extrémité.
PCT/US2013/054483 2012-08-16 2013-08-12 Système et procédé permettant une production, au moyen d'une suspension de tubes de production à alésages multiples, vers un collecteur sous-marin sans modifications du bop WO2014028365A2 (fr)

Applications Claiming Priority (2)

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US201261684057P 2012-08-16 2012-08-16
US61/684,057 2012-08-16

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WO2014028365A2 true WO2014028365A2 (fr) 2014-02-20
WO2014028365A9 WO2014028365A9 (fr) 2014-09-18
WO2014028365A3 WO2014028365A3 (fr) 2014-11-06

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018208744A1 (fr) * 2017-05-10 2018-11-15 Baker Hughes, A Ge Company, Llc Garniture d'étanchéité à double alésage avec filetage de mandrin à décalage axial

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9765593B2 (en) 2014-12-03 2017-09-19 Ge Oil & Gas Uk Limited Configurable subsea tree master valve block

Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6968902B2 (en) 2002-11-12 2005-11-29 Vetco Gray Inc. Drilling and producing deep water subsea wells

Family Cites Families (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3353595A (en) * 1964-05-22 1967-11-21 Cameron Iron Works Inc Underwater well completions

Patent Citations (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6968902B2 (en) 2002-11-12 2005-11-29 Vetco Gray Inc. Drilling and producing deep water subsea wells

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2018208744A1 (fr) * 2017-05-10 2018-11-15 Baker Hughes, A Ge Company, Llc Garniture d'étanchéité à double alésage avec filetage de mandrin à décalage axial

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US20140076575A1 (en) 2014-03-20
WO2014028365A3 (fr) 2014-11-06
WO2014028365A9 (fr) 2014-09-18

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