US20020100592A1 - Production flow tree cap - Google Patents

Production flow tree cap Download PDF

Info

Publication number
US20020100592A1
US20020100592A1 US09/805,090 US80509001A US2002100592A1 US 20020100592 A1 US20020100592 A1 US 20020100592A1 US 80509001 A US80509001 A US 80509001A US 2002100592 A1 US2002100592 A1 US 2002100592A1
Authority
US
United States
Prior art keywords
tree
christmas tree
tubing hanger
flow port
flow
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US09/805,090
Other languages
English (en)
Inventor
Michael Garrett
Scott Beall
Rogelio Ortiz
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
KAVERNER OILFIELD PRODUCTS Inc
Original Assignee
KAVERNER OILFIELD PRODUCTS Inc
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 KAVERNER OILFIELD PRODUCTS Inc filed Critical KAVERNER OILFIELD PRODUCTS Inc
Priority to US09/805,090 priority Critical patent/US20020100592A1/en
Assigned to KAVERNER OILFIELD PRODUCTS, INC. reassignment KAVERNER OILFIELD PRODUCTS, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: BEALL, SCOTT K., GARRETT, MICHAEL R., ORTIZ, ROGELIO
Priority to GB0323949A priority patent/GB2392692B/en
Priority to AU2002247319A priority patent/AU2002247319A1/en
Priority to PCT/US2002/007507 priority patent/WO2003050384A1/en
Priority to GB0504880A priority patent/GB2410517B/en
Publication of US20020100592A1 publication Critical patent/US20020100592A1/en
Priority to US10/356,463 priority patent/US6810954B2/en
Priority to NO20034060A priority patent/NO20034060L/no
Abandoned legal-status Critical Current

Links

Images

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
    • E21B33/043—Casing heads; Suspending casings or tubings in well heads specially adapted for underwater 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
    • 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
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • 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
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/02—Valve arrangements for boreholes or wells in well heads
    • E21B34/025—Chokes or valves in wellheads and sub-sea wellheads for variably regulating fluid flow
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/02—Valve arrangements for boreholes or wells in well heads
    • E21B34/04—Valve arrangements for boreholes or wells in well heads in underwater well heads

Definitions

  • This invention relates generally to subsea oil and gas production methods and apparatus and, more particularly, to a split tree cap christmas tree.
  • the horizontal tree contains a plug or tree cap that provides a first barrier to production fluids above the tubing hanger and the production tubing in the horizontal christmas tree.
  • a second barrier to the environment is typically provided by a second plug located within the production tubing hanger when the tubing hanger is run or retrieved.
  • the system includes a tree body having a first flow port and a tree cap; a tubing hanger landed within the tree body; an actuation mandrel landed within the tree body, the actuation mandrel having a flow port; and a flow diverter disposed within the tree cap to divert flow through the flow port.
  • the system may further include a backup flow diverter disposed within the tree cap, the flow diverters including plugs. In some embodiments the plugs are set by wireline.
  • the first flow port is a production flow port.
  • This first flow port may be a radial bore extending through the tree body.
  • the christmas tree includes a second flow port.
  • This second flow port may be an annulus flow port.
  • the annulus flow port may include a first partial bore, a second partial bore, and a channel extending therebetween.
  • the channel may extend substantially longitudinally along the tree body.
  • the first and second partial bores are arranged opposite one another.
  • the christmas tree further includes an integral production valve.
  • the christmas tree includes a first countersunk area receptive of a production valve assembly.
  • the christmas tree further includes a second countersunk area receptive of an annulus flow assembly.
  • the annulus flow assembly may attach to external fluid circulation lines.
  • the external fluid circulation lines may include choke or kill lines.
  • the christmas tree further includes a third flow port.
  • the third flow port provides fluid communication to a downhole safety valve.
  • the third flow port may be receptive of a hydraulic penetrator to establish fluid communication to the downhole safety valve.
  • the christmas tree further includes a fourth flow port.
  • the fourth flow port may provide for chemical injection into the well.
  • a method of controlling production from a subsea oil or gas well including the steps of: installing a side valve tree onto a wellhead, the side valve tree including a tree cap; running a tubing hanger into the wellbore; landing the tubing hanger in the tree body; installing an actuation mandrel with a plurality of plugs set therein; wherein the plurality of plugs are disposed within the tree cap and there are no plugs set in the tubing hanger.
  • the step of installing a side valve tree onto a wellhead may further include providing a tree bore protector.
  • the tubing hanger may include a production tubing suspended therefrom.
  • the tubing hanger may include an orientation key mating with an orientation sleeve. Therefore, the method may further include the step of orienting the tubing hanger within the tree body.
  • the method may include the step of locking the tubing hanger within the tree body.
  • the step of installing an actuation mandrel with a plurality of plugs set therein includes orienting the actuation mandrel.
  • the actuation mandrel may include a plurality of reduced-diameter shoulders and pack-off seals.
  • the step of installing an actuation mandrel with a plurality of plugs set therein further comprises landing the shoulders and seals within the tree body.
  • a method of servicing a subsea oil or gas well with a side-valve christmas tree including the steps of: running an actuation mandrel retrieval tool into the christmas tree; engaging the actuation mandrel retrieval tool with the actuation mandrel; retrieving the actuation mandrel; and retrieving a tubing hanger; wherein there is no step of retrieving any plugs from within the tubing hanger.
  • FIG. 1A depicts a split tree cap christmas tree design in accordance with one aspect of the invention.
  • FIG. 1B depicts a detail of the split tree cap christmas tree design of FIG. 1A.
  • FIG. 1C depicts a split tree cap christmas tree design in accordance with another aspect of the invention.
  • FIG. 1D depicts a split tree cap christmas tree design according to FIG. 1C in the run-in position.
  • FIG. 2 depicts a split tree cap christmas tree in diagramatic form.
  • FIG. 3 is a schematic drawing of the christmas tree design of FIG. 1.
  • FIG. 4 diagrammatically depicts a split tree cap christmas tree with a tree bore protector installed.
  • FIGS. 5A and 5B diagrammatically depict a split tree cap christmas tree during the installation of a tubing hanger.
  • FIG. 6 depicts a split tree cap christmas tree during installation of a tubing hanger with alternate locked and unlocked positions indicated.
  • FIGS. 7A and 7B diagrammatically depict a split tree cap christmas tree with a tubing hanger installed, landed and locked.
  • FIGS. 8A and 8B diagrammatically depict a split tree cap christmas tree with a tubing hanger installed, landed and locked during retrieval of the tubing hanger running tool.
  • FIG. 9 diagrammatically depicts a split tree cap christmas tree with a tubing hanger installed and without running tools.
  • FIGS. 10A and 10B diagrammatically depict a split tree cap christmas tree during the installation of a split tree cap and plugs.
  • FIGS. 11A and 11B diagrammatically depict a split tree cap christmas tree with a split tree cap installed, landed and locked.
  • FIGS. 12A and 12B diagrammatically depict a split tree cap christmas tree with a split tree cap installed, landed and locked during retrieval of a tree cap running tool.
  • FIG. 13 diagrammatically depicts an embodiment of the split tree cap christmas tree with the tubing hanger and split tree cap installed.
  • Christmas tree system 2 includes a generally cylindrical side valve tree body 4 .
  • Side valve tree body 4 defines an internal throughbore 6 extending longitudinally therethrough.
  • the upper end of side valve tree body 4 contains a radial profile 8 adapted to engage an external connector.
  • Profile 8 is intended to allow the connection of the christmas tree body 4 to other subsea equipment such as running tools, blowout preventers, and intervention packages by way of example.
  • Other means of connection known in the art are easily applicable to connect the side valve tree body 4 to other equipment as needed.
  • Profile 10 provides a means to connect the side valve tree body 4 to a tree running tool.
  • profile 10 is adapted to receive a lock down ring 92 , retained by an associated lock down sleeve 93 , as discussed below.
  • side valve tree body 4 is adapted for installation on a wellhead 100 .
  • Tree body 4 may be adapted for installation on any standard size wellhead typically known in the art, for example an 183 ⁇ 4 inch wellhead.
  • a connector secures the side valve tree body 4 to the wellhead 100 and resists the separation forces resulting from the pressure developed in a live well.
  • a seal 102 disposed between the wellhead 100 and the side valve tree body 4 typically a gasket seal such as an AX gasket, prevents the passage of hydrocarbons to the environment at this connection.
  • a flow port 12 constitutes a first bore through side valve tree body 4 .
  • side valve tree body 4 includes an integral valve 104 .
  • Production flow port 12 is cut radially through side valve tree body 4 .
  • the side valve tree body 4 contains a countersunk area 14 circumscribing the flow port 12 to facilitate attachment of a production valve assembly 110 , as shown schematically in FIG. 3.
  • the production valve assembly 110 (or in the embodiments of FIGS. 1C and 1D, integral production valve 104 ) is generally controlled hydraulically, e.g. from the surface through a control module, to regulate or stop the flow of hydrocarbons from the well.
  • Hydraulic control lines 112 and 114 are indicated in FIG. 3. Electronically controlled valves are an option to hydraulically controlled valves.
  • the valve assembly 110 generally contains at least one valve, however, two are common as indicated in FIG. 3 by production master valve 116 (PMV) and production wing valve 118 (PWV).
  • PMV production master valve
  • PWV production wing valve 118
  • a flanged connection fixes the valve assembly 110 to the side valve tree body 4 .
  • the countersunk area 14 may contain studs to facilitate the attachment of the first valve 116 or the valve assembly 110 by bolting.
  • one of the valves or the entire valve assembly may be integral to side valve tree body 4 .
  • At least one seal 16 is disposed between the side valve tree body 4 and the valve assembly 110 in the area of the flow port 12 .
  • Seal 16 may be located within a groove 18 , and may be an o-ring or other resilient-type seal. Other embodiments may include metal-to-metal seals, or other seals known in the art. Redundant seals may also be disposed between the flow port 12 and the side valve tree body 4 .
  • FIGS. 1A and 1B also show a tubing annulus flow port 20 disposed within the wall of side valve tree body 4 . Similar ports may be included in the side valve tree body 4 shown in FIGS. 1C and 1D, although they are not shown.
  • Tubing annulus flow port 20 enters the external wall of the tree body 4 at a suitable location to avoid the body of a connector, when such a connector is installed. In one embodiment, flow port 20 enters the throughbore 6 above the uppermost barrier, annulus mandrel 74 in the embodiment shown as FIGS. 1A, 1B and 2 .
  • the annulus flow port 20 enters the throughbore 6 at other locations relative to the internal barriers.
  • the annulus flow port 20 may comprise a first partial bore 21 , a second partial bore 23 , and a channel 25 extending therebetween. Channel 25 extends substantially longitudinally along the tree body 4 .
  • a tubing annulus flow assembly 120 shown schematically in FIG. 3, contains external piping 122 and at least one valve. Three annulus valves are shown in FIG. 3, annulus master valve 124 (AMV), annulus wing valve 126 (AWV), and annulus circulation valve 128 (ACV).
  • AMV annulus master valve
  • AMV annulus wing valve 126
  • ACV annulus circulation valve 128
  • the annulus valves 124 , 126 , 128 in tubing annulus flow assembly 120 are generally controlled hydraulically, e.g. from the surface through a control module. Hydraulic control lines 125 and 127 are indicated in FIG. 3. Electronically controlled valves are an option to hydraulically controlled valves.
  • a countersunk area 22 is provided to facilitate a flanged connection between annulus flow assembly 120 and the side valve tree body 4 at the external entry of tubing annulus flow port 20 , however, other connectors known in the art may be used.
  • At least one seal 24 is disposed in a groove 26 between the side valve tree body 4 and the tubing annulus flow assembly 120 to prevent the flow of hydrocarbons to the environment at this connection. Similar to the production porting, other types and numbers of seals may be provided.
  • tubing annulus flow assembly 120 may attach to external fluid circulation lines, such as choke and kill lines, instead of reentering the tree body 4 .
  • FIG. 2 depicts a tubing annulus access port 30 .
  • Port 30 passes through tree body 4 from the through bore 6 below the tubing hanger 42 , which when the tree 4 is completed forms an annular space or tubing annulus between the production tubing 50 and the production casing 101 .
  • tubing annulus flow assembly 120 provides a means of fluid communication between the tubing-by-casing annulus and the throughbore 6 above the tubing hanger 42 .
  • Annulus valves 124 , 126 , and 128 provide one apparatus for controlling flow from the tubing annulus.
  • crossover valve 130 and associated piping 132 provide a means for controlling flow between the tubing annulus and the production line.
  • An electrical penetrator 120 as shown in FIGS. 1C and 1D may enable the access to the tubing annulus.
  • the embodiments shown provide a well-designed apparatus for controlling flows during circulation, bullheading, injections, and other operations as may be required, those skilled in the art will appreciate that various other arrangements of valves and piping can be provided to achieve the same functions.
  • Additional ports or bores through the side valve tree body 4 may be included as required for hydraulic and/or electrical connections downhole.
  • a port 32 allows a hydraulic penetrator 140 (as shown in FIGS. 1C, 1D, and 2 ) to establish fluid communication to the hydraulic control line 53 for the downhole safety valve 48 (as shown in FIG. 3).
  • additional ports may be included for chemical injection lines, additional hydraulic and/or electric connections downhole, or various other purposes as required by a specific service.
  • Tree bore protector 34 contains seal 36 that seals between the bore protector and the wellhead 100 .
  • the bore protector 34 also contains a seal assembly 38 that provides a seal between the bore protector and the throughbore 6 above the production flow port 12 .
  • Tree running tool 40 is shown connected to the internal running profile 10 of tree body 4 , and provides the mechanism to lock and unlock the tree bore protector 34 .
  • FIGS. 1D, 5A, 5 B, and 6 show the tubing hanger 42 and associated components being run into the tree body 4 on a tubing hanger running tool 44 .
  • FIG. 6 shows the tubing hanger 42 landed in the tree body 4 , in the locked position to the left of the centerline and in the unlocked position to the right of the centerline.
  • the tubing hanger 42 provides the means for suspending tubing into the wellbore for production of hydrocarbons.
  • the tubing hanger defines a longitudinal throughbore of substantially similar inside diameter to that of the tubing, and may have any desired inside diameter known in the industry, including standard sizes such as 5 or 7 inches.
  • the tubing hanger 42 is landed and suspended in side valve tree body 4 .
  • tubing hanger seal assembly 43 disposed between the tubing hanger 42 and the throughbore 6 of the tree body 4 , the vertical load of tubing hanger 42 and its associated components are carried and transferred at shoulder 28 within the tree body 4 .
  • Tubing hanger seal asembly 43 may comprise metal-to-metal seals or resilient seals.
  • Production tubing 50 is disposed at the lower end of tubing hanger 42 , and may be attached by a threaded connection as shown in FIGS. 1C and 6, or by other means known in the art such as bolts, pins or compression fittings.
  • the tubing 50 extends into the well for as great or as short a length as required by the characteristics of the well.
  • a downhole safety valve 52 is located significantly below the tubing hanger 42 . Downhole safety valve 52 may be hydraulically controlled by hydraulic line 53 , as shown in FIG. 3, or may be electrically controlled.
  • tubing hanger running tool 44 is detachably connected at a first end to the completion riser or drill pipe with a standard riser joint connection. At a second end, running tool 44 is detachably connected to the tubing hanger 42 . In between, a series of slidable members 45 are sealingly disposed between the body of tubing hanger running tool 44 and the tree body 4 . Hydraulic passages 46 allow the flow of fluid to areas between the seals, forcing the slidable members 45 to up or down positions.
  • FIG. 6 The left side of the centerline in FIG. 6 shows the tubing hanger 42 fixedly connected to running tool 44 , as during the running procedure.
  • Tubing hanger attachment ring 47 is engaged in a profile in the exterior of tubing hanger 42 , and is prevented from disengaging by the slidable member 45 located adjacent.
  • the slidable members 45 can be raised allowing the tubing hanger attachment ring 47 to disengage from the profile, and thus allow retrieval of the running tool 44 .
  • tubing hanger seal assembly 43 held in a locked position by tubing hanger seal lock down ring 48 engaged in a profile in the interior wall of tree body 4 , and held in place by tubing hanger seal lock down sleeve 49 .
  • tubing hanger lock down sleeve 49 is raised, allowing the lock down ring 48 to disengage.
  • hydraulic penetrator connection assembly 60 fixed to tubing hanger 42 .
  • the hydraulic penetrator connection assembly 60 provides for a sealing interface along the inner surface of the tree body 4 around the hydraulic penetrator port 32 .
  • Penetrator connection assembly 60 contains a biased cam element 62 that moves a coupler 64 into position to form a sealed contact with the penetrator 140 .
  • the tubing hanger 42 shown is oriented to align the hydraulic penetrator 140 connect to the downhole safety valve's hydraulic control line 53 .
  • the hydraulic penetrator 140 shown is not essential to the invention. Non-oriented tubing hangers are an acceptable option where another method of communication downhole is chosen. Hydraulic control line 53 may be coiled as shown to absorb movement during installation and during use.
  • tubing hanger 42 is oriented by depending sleeve 54 coupled to the lower portion of the tubing hanger 42 .
  • An orientation key 56 is mounted on the depending sleeve 54 .
  • the orientation key 56 (not shown) on depending sleeve 54 contacts a cam surface on an orientation sleeve 58 .
  • the orientation sleeve 58 is mounted within an isolation sleeve 59 .
  • Isolation sleeve 59 provides seals to the production casing 101 in wellhead 100 and to the tree body 4 , and provides a recess to carry the orientation sleeve 58 .
  • Other means of orienting the tubing hanger such as using a pin and groove system either in a blowout preventer or in the tree, are easily adaptable to the system as shown.
  • FIGS. 7A and 7B like the left side of FIG. 6, show the tubing hanger 42 landed and locked within the side valve tree body 4 .
  • FIGS. 7A and 7B the tubing hanger running tool 44 is shown still attached to the tubing hanger 42 .
  • FIGS. 8A and 8B show the tubing hanger running tool 44 released from the tubing hanger 42 .
  • a latch ring in running tool 44 is released from the tubing hanger seal lock down ring 48 by hydraulic pressure which moves the slidable members 45 generally outward and upward.
  • tubing hanger attachment ring 47 disengages from its profile on the upper mandrel of tubing hanger 42 . Accordingly, the tubing hanger running tool 44 can be removed, leaving the tubing hanger 42 installed in the tree body 4 as shown in FIG. 9.
  • the tubing hanger 42 contains a cam profile 70 .
  • the cam profile 70 may be contained on a cylindrical insert 72 journalled within the tubing hanger 42 , or alternatively may be machined into the internal throughbore of tubing hanger 42 .
  • an internal tree cap flow divertor for example an actuation mandrel 74 and plug 94 .
  • Actuation mandrel 74 is substantially coaxial with side valve tree body 4 and exhibits a longitudinal throughbore of substantially similar diameter to that of the production tubing.
  • Actuation mandrel 74 lands above the tubing hanger 42 , and its longitudinal throughbore is coextensive with the longitudinal throughbore of the tubing hanger 42 .
  • the actuation mandrel 74 contains a radially drilled bore 76 that allows produced hydrocarbons to be diverted from the longitudinal throughbore.
  • bore 76 of actuation mandrel 74 is relatively aligned vertically and radially with flow port 12 through side valve tree body 4 . In the embodiment shown this alignment is achieved through a cam system.
  • actuation mandrel 74 Disposed at the lower end of actuation mandrel 74 is a depending cylinder 78 which extends into the tubing hanger 42 .
  • Depending cylinder 78 also called a sleeve, is separate from the actuation mandrel 74 , and may be bolted as shown, or attached by other means commonly known in the art such as threaded connections, split ring connections, etc.
  • Seals 79 and 80 restrict or prevent the passage of fluid between the interfaces of cylinder 78 and the tubing hanger 42 , and between the cylinder 78 and the actuation mandrel 74 respectively.
  • a key 82 fixed to the depending cylinder 78 interacts with the cam surface 70 , causing the actuation mandrel 74 to rotate for orientation.
  • the degree of precision in the rotation and orientation is a matter of design choice, and can be as rough or precise as operating conditions require.
  • actuation mandrel 74 is non-oriented.
  • produced fluids would be routed through an annular recess similar to that shown by reference numeral 13 but sized to permit annular flow without overly restricting flow velocity.
  • Gallery seals similar to seal 77 below the bore 76 ) would be installed above and below the bore 76 forcing flow to remain in the annular groove until exiting at the bore 76 .
  • Additional bores similar to 76 could be added to reduce the restriction in flow caused by radial misalignment.
  • the outer wall of actuation mandrel 74 contains a series of reduced diameter steps or shoulders 83 that allow for the proper positioning, installation and landing of pack-off seals.
  • the upper portion of actuation mandrel 74 contains an external profile 84 that allows the tree cap to be latched to a running tool using tree cap attachment ring 85 , as shown in FIGS. 10A and 10B.
  • Running tool profile 84 may match the profile at the top of the tubing hanger 42 , as shown more clearly in FIG. 1, to allow the use of the tubing hanger running tool 44 for installation and removal of the actuation mandrel 74 .
  • pack-off seal 86 comprises seal element 87 , shown as resilient seals, to restrict and prevent the passage of produced fluids above the production bores 76 and 12 in throughbore 6 .
  • Pack-off seal 86 is shown coupled to actuation mandrel 74 such that the two may be run into the tree as one unit. Referring to FIGS. 10A and 10B, before the lower pack-off seal assembly 86 is landed, lower seal lock down ring 88 is not engaged in the mating profile in the throughbore of tree body 4 .
  • Lower seal lock down sleeve 89 also contains a latching profile at its upper edge to couple to the running tool for removal of the lower seal assembly 86 as may be required.
  • upper pack-off seal assembly 90 is shown landed and locked above the lower pack-off seal 86 .
  • Seal element 91 is shown having metal-to-metal sealing.
  • the sealing elements 86 and 91 of pack-off seals 86 and 90 can be resilient, metal-to-metal, or any combination of both.
  • upper pack-off seal 90 is not coupled to the actuation mandrel 74 , but it is run into the tree separate from the actuation mandrel 74 and lower pack-off seal 86 .
  • pack-off seal 90 may be coupled to actuation mandrel 74 such that the two seal assemblies 86 and 90 and the actuation mandrel 74 may be run into the tree in one trip as a combined unit. Further, both seal assemblies 86 and 90 and the actuation mandrel 74 could be run individually in separate trips.
  • upper seal lock down ring 92 is not engaged in the mating profile in the throughbore of tree body 4 .
  • upper seal assembly 90 is in place and the upper seal lock down ring 92 is engaged in profile 10 .
  • the lock down ring 92 is prevented from moving out of the profile 10 by upper seal lock down sleeve 93 .
  • Upper lock down sleeve 93 also contains a latching profile at its upper edge to couple to the running tool for removal of the upper seal assembly 90 .
  • the actuation mandrel 74 and the seal assemblies 86 and 90 are coupled to run in one trip. However, the coupling mechanism allows the independent removal of one or both seal assemblies, such as by coupling with shear pins.
  • the throughbore of actuation mandrel 74 contains two plugs 94 and 96 .
  • the plugs 94 and 96 serve as redundant barriers to prevent the flow of hydrocarbons up the longitudinal throughbore, and to divert the flow into the bore 76 .
  • Each plug is locked and landed in an internal profile 95 and 97 .
  • the plugs 94 and 96 may be wireline retrievable plugs, coiled tubing plugs, valves, or other closures, and may be mechanically or hydraulically actuated. At least the lower plug may contain hard facing to resist damage from the production stream, and be located so as to minimize turbulence in the production flow stream. As shown in FIG.
  • the plugs 94 and 96 may be run with the actuation mandrel 74 , however, each plug is independently retrievable. With both of plugs 94 and 96 located in the tree cap 74 , an operator may advantageously run or retrieve a tubing hanger without setting a plug in the tubing hanger, thereby eliminating a plug-setting trip.
  • FIGS. 12A and 12B show the tree cap attachment ring 85 released from the profile 84 in actuation mandrel 74 to allow the retrieval of the running tool.
  • FIGS. 1A, 1C, 2 and 13 show the christmas tree system 2 in the production mode, with the tubing hanger 42 and the actuation mandrel 74 installed.

Landscapes

  • 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)
  • Valve Housings (AREA)
US09/805,090 2000-01-27 2001-03-13 Production flow tree cap Abandoned US20020100592A1 (en)

Priority Applications (7)

Application Number Priority Date Filing Date Title
US09/805,090 US20020100592A1 (en) 2001-01-26 2001-03-13 Production flow tree cap
GB0323949A GB2392692B (en) 2001-03-13 2002-03-13 Production christmas tree
AU2002247319A AU2002247319A1 (en) 2001-03-13 2002-03-13 Production christmas tree
PCT/US2002/007507 WO2003050384A1 (en) 2001-03-13 2002-03-13 Production christmas tree
GB0504880A GB2410517B (en) 2001-03-13 2002-03-13 Controlling production from a subsea oil or gas well
US10/356,463 US6810954B2 (en) 2000-01-27 2003-01-31 Production flow tree cap
NO20034060A NO20034060L (no) 2001-03-13 2003-09-12 Ventiltrehette for produksjonsströmning

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US77058801A 2001-01-26 2001-01-26
US09/805,090 US20020100592A1 (en) 2001-01-26 2001-03-13 Production flow tree cap

Related Parent Applications (1)

Application Number Title Priority Date Filing Date
US77058801A Continuation-In-Part 2000-01-27 2001-01-26

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US10/356,463 Continuation US6810954B2 (en) 2000-01-27 2003-01-31 Production flow tree cap

Publications (1)

Publication Number Publication Date
US20020100592A1 true US20020100592A1 (en) 2002-08-01

Family

ID=25190648

Family Applications (2)

Application Number Title Priority Date Filing Date
US09/805,090 Abandoned US20020100592A1 (en) 2000-01-27 2001-03-13 Production flow tree cap
US10/356,463 Expired - Lifetime US6810954B2 (en) 2000-01-27 2003-01-31 Production flow tree cap

Family Applications After (1)

Application Number Title Priority Date Filing Date
US10/356,463 Expired - Lifetime US6810954B2 (en) 2000-01-27 2003-01-31 Production flow tree cap

Country Status (5)

Country Link
US (2) US20020100592A1 (no)
AU (1) AU2002247319A1 (no)
GB (2) GB2392692B (no)
NO (1) NO20034060L (no)
WO (1) WO2003050384A1 (no)

Cited By (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20030205385A1 (en) * 2002-02-19 2003-11-06 Duhn Rex E. Connections for wellhead equipment
US20030221823A1 (en) * 2002-02-19 2003-12-04 Duhn Rex E. Wellhead isolation tool
US20040262010A1 (en) * 2003-06-26 2004-12-30 Milberger Lionel J. Horizontal tree assembly
US20050092496A1 (en) * 2002-02-19 2005-05-05 Duhn Rex E. Wellhead isolation tool and method of fracturing a well
US20050242519A1 (en) * 2004-04-29 2005-11-03 Koleilat Bashir M Wedge seal
US6966383B2 (en) 2002-12-12 2005-11-22 Dril-Quip, Inc. Horizontal spool tree with improved porting
US20060060349A1 (en) * 2002-02-19 2006-03-23 Duhn Rex E Wellhead isolation tool and method of fracturing a well
GB2437286A (en) * 2006-04-20 2007-10-24 Vetco Gray Inc Retrievable tubing hanger installed below spool tree
US20130291961A1 (en) * 2010-02-15 2013-11-07 Petroleum Technology Company As Valve device
US20140060849A1 (en) * 2012-08-31 2014-03-06 Cameron International Corporation Cap System for Subsea Equipment
NO20160857A1 (en) * 2013-12-06 2016-05-23 Ge Oil & Gas Uk Ltd Orientation adapter for use with a tubing hanger
US20160273302A1 (en) * 2007-11-21 2016-09-22 Cameron International Corporation Back pressure valve

Families Citing this family (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6520263B2 (en) * 2001-05-18 2003-02-18 Cooper Cameron Corporation Retaining apparatus for use in a wellhead assembly and method for using the same
NO322829B1 (no) * 2003-05-22 2006-12-11 Fmc Kongsberg Subsea As Gjenopptagbar plugg, ventiltre med plugg og fremgangsmate for bronnintervensjon i bronn med minst en plugg
AU2003904183A0 (en) * 2003-08-08 2003-08-21 Woodside Energy Limited Method for completion or work-over of a sub-sea well using a horizontal christmas tree
WO2005047639A2 (en) * 2003-11-05 2005-05-26 Fmc Technologies, Inc. Subsea completion system and method of using same
GB0409189D0 (en) * 2004-04-24 2004-05-26 Expro North Sea Ltd Plug setting and retrieving apparatus
US20050284639A1 (en) * 2004-06-28 2005-12-29 Reimert Larry E Pressure-compensated flow shut-off sleeve for wellhead and subsea well assembly including same
GB2432172B (en) * 2005-11-09 2008-07-02 Aker Kvaerner Subsea Ltd Subsea trees and caps for them
US7607485B2 (en) * 2006-01-26 2009-10-27 Vetco Gray Inc. Tubing hanger and wellhead housing with mating tubing annulus passages
GB2440940B (en) 2006-08-18 2009-12-16 Cameron Internat Corp Us Wellhead assembly
US8087465B2 (en) * 2007-02-14 2012-01-03 Aker Subsea Inc. Locking cap for subsea tree
US8726991B2 (en) 2007-03-02 2014-05-20 Schlumberger Technology Corporation Circulated degradable material assisted diversion
US7743832B2 (en) * 2007-03-23 2010-06-29 Vetco Gray Inc. Method of running a tubing hanger and internal tree cap simultaneously
US20090071656A1 (en) * 2007-03-23 2009-03-19 Vetco Gray Inc. Method of running a tubing hanger and internal tree cap simultaneously
US7621338B2 (en) * 2007-07-27 2009-11-24 Vetco Gray Inc. Non-orienting tree cap
US7823634B2 (en) * 2007-10-04 2010-11-02 Vetco Gray Inc. Wellhead isolation sleeve assembly
US8230928B2 (en) * 2008-04-23 2012-07-31 Aker Subsea Inc. Low profile internal tree cap
CN103485740B (zh) * 2008-04-28 2017-03-01 阿克海底公司 内部树帽和itc送入工具
DK178357B1 (da) * 2008-06-02 2016-01-11 Mærsk Olie Og Gas As Juletræ til brug i en brønd
US8151892B2 (en) * 2009-03-06 2012-04-10 Dril-Quip, Inc. Wellhead conversion system and method
US8136604B2 (en) * 2009-03-13 2012-03-20 Vetco Gray Inc. Wireline run fracture isolation sleeve and plug and method of operating same
US8074724B2 (en) * 2009-03-27 2011-12-13 Vetco Gray Inc. Bit-run nominal seat protector and method of operating same
US8327943B2 (en) * 2009-11-12 2012-12-11 Vetco Gray Inc. Wellhead isolation protection sleeve
BR112013031557B8 (pt) * 2011-06-09 2020-11-03 Halliburton Energy Services Inc método de medir uma distância entre uma superfície suporte e uma localização em um conjunto preventor.
US8397827B2 (en) 2011-06-09 2013-03-19 Halliburton Energy Services, Inc. Reducing trips in well operations
US9022122B2 (en) * 2012-02-29 2015-05-05 Onesubsea Ip Uk Limited High-pressure cap equalization valve
US9127524B2 (en) * 2013-03-11 2015-09-08 Bp Corporation North America Inc. Subsea well intervention system and methods
US9909380B2 (en) * 2015-02-25 2018-03-06 Onesubsea Ip Uk Limited System and method for accessing a well
US9523259B2 (en) * 2015-03-05 2016-12-20 Ge Oil & Gas Uk Limited Vertical subsea tree annulus and controls access
US10982494B2 (en) 2018-08-21 2021-04-20 Stuart Petroleum Testers, Llc Fluid discharge suppressor

Family Cites Families (14)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3279536A (en) 1961-04-03 1966-10-18 Richfield Oil Corp Submarine drilling and production head and method of installing same
US3662822A (en) 1969-05-12 1972-05-16 Atlantic Richfield Co Method for producing a benthonic well
US3731742A (en) 1971-03-17 1973-05-08 Otis Eng Corp Well flow controlling method, apparatus and system
GB1405728A (en) 1972-07-28 1975-09-10 Baker Oil Tools Inc Shifting tool for use in a well pipe
US4077472A (en) 1976-07-26 1978-03-07 Otis Engineering Corporation Well flow control system and method
GB2166775B (en) 1984-09-12 1987-09-16 Britoil Plc Underwater well equipment
GB8617698D0 (en) 1986-07-19 1986-08-28 Graser J A Wellhead apparatus
US4886121A (en) 1988-02-29 1989-12-12 Seaboard-Arval Corporation Universal flexbowl wellhead and well completion method
EP0572732B1 (en) * 1992-06-01 1998-08-12 Cooper Cameron Corporation Wellhead
US5372199A (en) 1993-02-16 1994-12-13 Cooper Industries, Inc. Subsea wellhead
EP0624711B1 (en) * 1993-05-11 1998-02-04 Cooper Cameron Corporation Valve assembly in wellheads
US6062314A (en) 1996-11-14 2000-05-16 Abb Vetco Gray Inc. Tubing hanger and tree with horizontal flow and annulus ports
US5988282A (en) * 1996-12-26 1999-11-23 Abb Vetco Gray Inc. Pressure compensated actuated check valve
GB2345927B (en) * 1999-02-11 2000-12-13 Fmc Corp Subsea completion system with integral valves

Cited By (32)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8863829B2 (en) 2002-02-19 2014-10-21 Seaboard International Inc. Wellhead isolation tool and wellhead assembly incorporating the same
US7322407B2 (en) 2002-02-19 2008-01-29 Duhn Oil Tool, Inc. Wellhead isolation tool and method of fracturing a well
US7520322B2 (en) 2002-02-19 2009-04-21 Duhn Oil Tool, Inc. Wellhead isolation tool and method of fracturing a well
US20050092496A1 (en) * 2002-02-19 2005-05-05 Duhn Rex E. Wellhead isolation tool and method of fracturing a well
US6920925B2 (en) 2002-02-19 2005-07-26 Duhn Oil Tool, Inc. Wellhead isolation tool
US8333237B2 (en) 2002-02-19 2012-12-18 Seaboard International Inc. Wellhead isolation tool and wellhead assembly incorporating the same
US7726393B2 (en) 2002-02-19 2010-06-01 Duhn Oil Tool, Inc. Wellhead isolation tool and wellhead assembly incorporating the same
US20060060349A1 (en) * 2002-02-19 2006-03-23 Duhn Rex E Wellhead isolation tool and method of fracturing a well
US8272433B2 (en) 2002-02-19 2012-09-25 Seaboard International Inc. Wellhead isolation tool and wellhead assembly incorporating the same
US20100193178A1 (en) * 2002-02-19 2010-08-05 Duhn Rex E Wellhead isolation tool and wellhead assembly incorporating the same
US20070272402A1 (en) * 2002-02-19 2007-11-29 Duhn Rex E Wellhead isolation tool, wellhead assembly incorporating the same, and method of fracturing a well
US20030205385A1 (en) * 2002-02-19 2003-11-06 Duhn Rex E. Connections for wellhead equipment
US20080093067A1 (en) * 2002-02-19 2008-04-24 Duhn Oil Tool, Inc. Wellhead isolation tool and method of fracturing a well
US7416020B2 (en) 2002-02-19 2008-08-26 Duhn Oil Tool, Inc. Wellhead isolation tool, wellhead assembly incorporating the same, and method of fracturing a well
US7493944B2 (en) 2002-02-19 2009-02-24 Duhn Oil Tool, Inc. Wellhead isolation tool and method of fracturing a well
US20030221823A1 (en) * 2002-02-19 2003-12-04 Duhn Rex E. Wellhead isolation tool
US6966383B2 (en) 2002-12-12 2005-11-22 Dril-Quip, Inc. Horizontal spool tree with improved porting
US20040262010A1 (en) * 2003-06-26 2004-12-30 Milberger Lionel J. Horizontal tree assembly
US20050242519A1 (en) * 2004-04-29 2005-11-03 Koleilat Bashir M Wedge seal
US20070246220A1 (en) * 2006-04-20 2007-10-25 Vetco Gray Inc. Retrievable Tubing Hanger Installed Below Tree
GB2437286B (en) * 2006-04-20 2011-03-16 Vetco Gray Inc Retrievable tubing hanger installed below tree
US7909103B2 (en) * 2006-04-20 2011-03-22 Vetcogray Inc. Retrievable tubing hanger installed below tree
GB2437286A (en) * 2006-04-20 2007-10-24 Vetco Gray Inc Retrievable tubing hanger installed below spool tree
US9719323B2 (en) * 2007-11-21 2017-08-01 Cameron International Corporation Back pressure valve
US20160273302A1 (en) * 2007-11-21 2016-09-22 Cameron International Corporation Back pressure valve
US10156122B2 (en) 2007-11-21 2018-12-18 Cameron International Corporation Back pressure valve
US9500062B2 (en) * 2010-02-15 2016-11-22 Petroleum Technology Company As Valve device of a wellhead Christmas tree assembly
US20130291961A1 (en) * 2010-02-15 2013-11-07 Petroleum Technology Company As Valve device
US20140060849A1 (en) * 2012-08-31 2014-03-06 Cameron International Corporation Cap System for Subsea Equipment
US9534466B2 (en) * 2012-08-31 2017-01-03 Onesubsea Ip Uk Limited Cap system for subsea equipment
NO20160857A1 (en) * 2013-12-06 2016-05-23 Ge Oil & Gas Uk Ltd Orientation adapter for use with a tubing hanger
NO342968B1 (en) * 2013-12-06 2018-09-10 Ge Oil & Gas Uk Ltd Orientation adapter for use with a tubing hanger

Also Published As

Publication number Publication date
GB2410517B (en) 2005-09-21
GB0504880D0 (en) 2005-04-13
GB2392692A (en) 2004-03-10
GB0323949D0 (en) 2003-11-12
US6810954B2 (en) 2004-11-02
GB2392692B (en) 2005-05-25
GB2410517A (en) 2005-08-03
US20030111228A1 (en) 2003-06-19
NO20034060L (no) 2003-11-12
NO20034060D0 (no) 2003-09-12
AU2002247319A1 (en) 2003-06-23
WO2003050384A1 (en) 2003-06-19

Similar Documents

Publication Publication Date Title
US6810954B2 (en) Production flow tree cap
US6675900B2 (en) Crossover tree system
US6408947B1 (en) Subsea connection apparatus
CA2403866C (en) Tubing hanger with annulus bore
US6039119A (en) Completion system
US7025132B2 (en) Flow completion apparatus
US20140166298A1 (en) Closed-loop hydraulic running tool
AU2001247785A1 (en) Tubing hanger with annulus bore
AU2001247785A2 (en) Tubing hanger with annulus bore
GB2347161A (en) Christmas tree with a crossover conduit
WO2010022170A1 (en) Annulus isolation valve
US9127524B2 (en) Subsea well intervention system and methods
GB2397312A (en) Well completion system
EP1350918B1 (en) A method of completing a subsea well
NO342969B1 (en) Subsea Wellhead System with Flexible Operation
AU2009283910C1 (en) Annulus isolation valve

Legal Events

Date Code Title Description
AS Assignment

Owner name: KAVERNER OILFIELD PRODUCTS, INC., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:GARRETT, MICHAEL R.;BEALL, SCOTT K.;ORTIZ, ROGELIO;REEL/FRAME:012503/0852;SIGNING DATES FROM 20010731 TO 20010801

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO PAY ISSUE FEE