US20060280560A1 - Riser tensioner with shrouded rods - Google Patents
Riser tensioner with shrouded rods Download PDFInfo
- Publication number
- US20060280560A1 US20060280560A1 US11/507,865 US50786506A US2006280560A1 US 20060280560 A1 US20060280560 A1 US 20060280560A1 US 50786506 A US50786506 A US 50786506A US 2006280560 A1 US2006280560 A1 US 2006280560A1
- Authority
- US
- United States
- Prior art keywords
- shroud
- shroud segment
- piston rod
- piston
- segments
- 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
Links
- 239000012530 fluid Substances 0.000 claims description 14
- 230000008602 contraction Effects 0.000 claims description 5
- 230000000712 assembly Effects 0.000 description 31
- 238000000429 assembly Methods 0.000 description 31
- 238000007789 sealing Methods 0.000 description 9
- 239000004020 conductor Substances 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 4
- 238000005553 drilling Methods 0.000 description 2
- ZZUFCTLCJUWOSV-UHFFFAOYSA-N furosemide Chemical compound C1=C(Cl)C(S(=O)(=O)N)=CC(C(O)=O)=C1NCC1=CC=CO1 ZZUFCTLCJUWOSV-UHFFFAOYSA-N 0.000 description 2
- 239000000314 lubricant Substances 0.000 description 2
- 238000005452 bending Methods 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000010355 oscillation Effects 0.000 description 1
- 239000011241 protective layer Substances 0.000 description 1
- 230000010356 wave oscillation Effects 0.000 description 1
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
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
-
- 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
- E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
- E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
- E21B19/004—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling supporting a riser from a drilling or production platform
- E21B19/006—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling supporting a riser from a drilling or production platform including heave compensators
Definitions
- This invention relates in general to hydro/pneumatic tensioners for applying tension to a riser supported from a floating platform.
- An offshore facility includes a riser extending to a subsea facility such as a subsea well or subsea manifold located at the sea floor.
- a subsea facility such as a subsea well or subsea manifold located at the sea floor.
- Offshore facilities that float, such as a tension leg platform move up and down and horizontally relative to the subsea well with the oscillations of the waves and currents. It is often desirous to maintain a desired tension on the riser during these oscillating movements.
- Tensioners are often utilized in order to react to the movements of offshore facilities moving with the wave oscillations and currents.
- Previous tensioner assemblies like those on tension leg platforms, include a plurality of piston assemblies suspended from a deck that connect to a tension ring surrounding the riser.
- One type relied upon gas positioned in a chamber surrounding the piston rod to create tension.
- These piston assemblies are pull-type piston assemblies because they react when the piston is being pulled through the piston chamber and the fluid surrounding the piston rod is compressed. These assemblies require large piston assemblies to accommodate the necessary fluid for creating tension in reaction to the movements of the platform.
- previous tensioner assemblies include ram style or push-type piston assemblies that have the reactive fluid on the side of the piston opposite from the piston rod.
- Ram style piston assemblies react when the piston is being pushed through the piston chamber. This arrangement allows for smaller piston assemblies because there is no piston rod in the chamber containing the fluid.
- the piston rod extends downward to the piston housed with the piston chamber. Therefore, drippings and debris from above often fall onto the piston rods which can damage the seals of the piston assembly. Failure and less reactive tensioning can occur when the seals are damaged.
- the piston rod extends upward to the piston housed with the piston chamber. In these assemblies, drippings and debris fall from above onto the rods. Such an arrangement typically required expensive coatings to be applied to the outer surface of the piston rods that were exposed to the elements.
- a surface assembly that communicates with subsea structures includes a working deck on a floating structure.
- the working deck has an aperture extending axially therethrough.
- a riser extends from a subsea location to the working deck.
- the riser extends through the aperture.
- the surface assembly includes a frame extending circumferentially around the riser.
- the frame is connected to the riser so that the frame moves axially with the riser.
- the assembly also includes a tensioner assembly connected between the working deck and the frame.
- the tensioner assembly comprises a piston, a piston chamber, a sealing portion between the piston and the piston chamber, a piston rod extending from the piston and away from the piston chamber, and a shroud enclosing the piston rod and at least the sealing portion of the piston assembly.
- the sealing portion is between the piston and an interior surface of the shroud.
- a piston chamber is defined by the sealing portion, the piston, and the shroud.
- the tensioner assembly can also include a cylinder.
- the sealing portion can then be located between the piston and the cylinder.
- the piston chamber is then defined by the sealing portion, the piston, and the cylinder.
- the shroud typically has a closed upper end, and an open lower end that exposes a portion of its interior surface to atmospheric pressure.
- a surface assembly for subsea wells includes a working deck on a floating structure.
- the working deck has an aperture extending axially therethrough.
- a riser extends from a subsea location to the working deck and through the aperture.
- a frame extends circumferentially around the riser. The frame is connected to the riser so that the frame moves axially with the riser.
- a tensioner assembly is connected between the working deck and the frame.
- the tensioner assembly includes a piston slidably carried in a piston chamber, a piston rod extending from the piston and away from the piston chamber, and a shroud enclosing the piston rod.
- the shroud has a plurality of segments with at least one of the shroud segments being movable in unison with the piston rod.
- the plurality of segments can include an inner shroud segment being stationary relative to the piston rod.
- the plurality of segments can have an inner shroud segment and an outer shroud segment, with the outer shroud segment telescoping over the inner shroud segment when the tensioner assembly is in a contracted position. A substantial portion of the inner shroud segment can be uncovered when the tensioner assembly is in an extended position. Either the outer shroud segment or the inner shroud segment that is fixedly connected to an end portion of the piston chamber that receives the piston rod.
- the plurality of segments can also include an intermediate shroud segment.
- the intermediate shroud segment telescoping over the inner shroud segment when the tensioner assembly is in a contracted position, and the outer shroud segment telescoping over the intermediate and inner shroud segments when the tensioner assembly is in a contracted position.
- a piston rod extends from the piston chamber.
- the piston rod and piston are movable between a contracted position and an extended position of the tensioner assembly.
- a shroud surrounds at least part of the piston rod while in the contracted and extended positions.
- the shroud has a plurality of shroud segments with at least one of the shroud segments being movable in unison with the piston rod and at least one of the shroud segments being fixedly connected to an end portion of the piston chamber that receives the piston rod.
- the plurality of shroud segments can include an inner shroud segment and an outer shroud segment.
- the inner shroud segment can have a flange end connected to either the piston chamber or the piston rod and a telescoping end having an outer lip.
- the outer shroud can also have a flange end connected to the other of the piston chamber or the piston rod and a telescoping end having an inner lip.
- the plurality of shroud segments can also include an intermediate shroud segment.
- the intermediate shroud segment telescopes over the inner shroud segment when the tensioner assembly is in a contracted position.
- the outer shroud segment telescopes over the intermediate and inner shroud segments when the tensioner assembly is in a contracted position.
- Each intermediate shroud segment can have an extension end and a contraction end.
- the extension end has an outer lip and the contraction end has an inner lip.
- FIG. 1 is a schematic side view of a riser tensioner constructed in accordance with this invention and shown in an extended position.
- FIG. 2 is a schematic side view of the riser tensioner in FIG. 1 , shown in a contracted position.
- FIG. 3 is a schematic side view of an alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 4 is a schematic side view of an alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 5 is a schematic side view of an alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 6 is a schematic side view of an alternate embodiment of a riser tensioner in accordance with this invention and shown in a partially an extended position.
- FIG. 7 is a schematic side view of another alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 8 is a schematic side view of the riser tensioner in FIG. 7 , shown in a contracted position.
- FIG. 9 is a schematic side view of another alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 10 is a schematic side view of another alternate embodiment of a riser tensioner in accordance with this invention and shown in an extended position.
- FIG. 11 is a schematic side view of the riser tensioner in FIG. 10 , shown in a contracted position.
- FIG. 12 is an exploded view of a cylinder assembly in the riser tensioner shown in FIGS. 7-9 .
- a floating platform deck 11 is schematically shown.
- Deck 11 may, for example, be a deck of a barge, a tension leg platform, a spar or other types. However, the arrangement of FIG. 1 is particularly suited for a spar.
- Deck 11 has an opening 13 through which a riser 15 extends.
- riser 15 is connected on its lower end to a subsea well.
- riser 15 is a production riser.
- a production tree (not shown) is mounted to the upper end of riser 15 .
- Well fluids flow from the subsea wellhead of production riser 15 to the tree.
- the floating platform will support a number of risers 15 .
- a tensioner assembly comprising a plurality of hydro/pneumatic cylinder assemblies 17 supplies tension to each riser 15 as deck 11 moves upward and downward.
- Two cylinder assemblies 17 are shown in FIG. 1 , but preferably, at least two more cylinder assemblies 17 will provide tension to each riser 15 .
- Each cylinder assembly 17 includes a cylinder 19 and a piston 21 that strokes within cylinder 19 .
- Piston 21 has a rod 23 that protrudes from one end of cylinder 19 . In this embodiment, rod 23 is located on the upper end of cylinder 19 above deck 11 .
- a closed system of pressurized gas over fluid is utilized to provide force.
- the pressurized fluid and gas may be internal or external to the cylinder. Both internal and external sources may be used together.
- An external pressurized fluid and gas source or accumulator 24 is shown. If desired, fluid under atmospheric or low pressure may be placed in the annular space surrounding rod 23 above piston 21 to serve as lubricant for piston 21 . The lubricant may lead to a reservoir for maintaining a constant supply as piston 21 strokes up and down.
- a plurality of seals 22 surround the circumference of piston 21 .
- seals 22 engage an interior surface of cylinder 19 .
- a piston chamber is defined by piston 21 , seals 22 and cylinder 19 .
- a plurality of seals 26 also extend from cylinder 19 to sealingly engage rod 23 .
- Cylinder 19 is connected on its lower end to a brace 27 by a pin 25 .
- pin 25 is spherical so as to allow pivotal rotation not only in the plane containing the drawing, but also in a Z-plane perpendicular to the plane containing the drawing.
- Brace 27 in this embodiment is secured to deck 11 , and the lower ends of cylinders 19 are located approximately at the same level as deck 11 .
- Each cylinder assembly 17 inclines relative to riser 15 and deck 11 in the embodiment shown in FIG. 1 and 2 .
- the upper ends of rods 23 are closer to riser 15 than the lower ends of cylinders 19 .
- Rods 23 are secured by spherical pins 29 to a top frame 31 .
- Top frame 31 is mounted to a tension ring 33 that is clamped or otherwise secured to riser 15 for movement therewith.
- the radial distance from the axis of riser 15 to upper pins 29 is less than the radial distance from the riser axis to lower pins 25 .
- the angle of each cylinder assembly 17 relative to the riser 15 will change as rods 23 stroke from a retracted position as shown in FIG. 2 to an extended position shown in FIG. 1 .
- FIG. 1 In FIG.
- a wave or tidal variation has caused deck 11 to rise relative to riser 15 , causing cylinder assembly 17 to retract.
- deck 11 has moved downward from that shown in FIG. 2 due to wave movement or tidal action.
- the pressurized gas over fluid maintains pressure on the lower side of piston 21 to cause cylinder assemblies 17 to extend.
- a shroud 35 encloses the exposed portion of rod 23 of each cylinder assembly 17 .
- Shroud 35 is a cylindrical member having a closed upper end 37 and an open lower end 39 .
- Each rod 23 extends through a hole in closed end 37 that is preferably sealed to prevent corrosive fluids from contacting rod 23 .
- Shroud 35 protects rod 23 and seals 26 from any debris falling onto cylinder assemblies 17 from above.
- the length of shroud 35 is selected so that lower end 39 will be close to the lower ends of cylinders 19 while cylinder assembly 17 is fully retracted as shown in FIG. 2 .
- lower end 39 of each shroud 35 is spaced below the upper end of cylinder 19 .
- the interior of shroud 35 is at low or atmospheric pressure.
- Sets of guide rollers 41 are employed to engage riser 15 and maintain riser 15 generally centralized in opening 13 but allow for angular offset of the riser relative to the platform. Although only two guide rollers 41 are shown, preferably more would be employed for each riser 15 .
- Each guide roller 15 is mounted to an arm 43 that is fixed in length in the preferred embodiment. Arm 43 has an outer end that is secured by a pin 45 to a lug 47 . Lug 47 mounts to deck 11 in this embodiment. Pivot pins 45 allow rods 43 to be pivoted and rotated away from deck opening 13 for other operations, such as when a larger diameter drilling riser is employed in a preliminary operation. In this embodiment, arms 43 are spaced above deck 11 only a short distance, thus provide centralizing to riser 15 at opening 13 .
- An upper deck 51 is located below tensioning ring 33 and above deck 11 in this embodiment. Mounting guide rollers to deck 51 reduces any moment arm on guide rollers 41 due to the failure of a cylinder assembly 17 . Preventing angular movements are desirable during many workover and intervention operations. Preferably, pivot pins 45 allow rods 43 to be pivoted and rotated so that rollers 41 connected to upper deck 51 may be disengaged and pivoted away from riser 15 . This may be desirable during operations where angular movements are allowable, or when a larger diameter drilling riser is employed.
- FIG. 3 is the same as the embodiment of FIGS. 1 and 2 except for placement of guide rollers 41 and upper deck 51 . Consequently, the same numerals will be used except for the different structure.
- upper deck 51 is mounted above tension ring 33 and a considerable distance above deck 11 .
- Arms 43 for guide rollers 41 are mounted to upper deck 51 .
- An advantage of the embodiment of FIG. 3 occurs if one of the cylinder assemblies 17 loses pressure. A loss in pressure causes a bending moment arm to be applied to riser 15 , which is resisted by guide rollers 41 . Because of the placement above tension ring 33 , the force applied by the moment arm is reduced over that which would exist if rollers 41 were placed as in FIGS. 1 and 2 .
- the embodiment shown in FIG. 4 includes the use of a sleeve or conductor 53 .
- Conductor 53 is mounted to top frame 31 and extends concentrically around riser 15 .
- Conductor 53 extends downward a distance that is at least equal to the total stroke of cylinder assemblies 17 .
- Guide rollers 41 engage conductor 53 rather than directly engaging riser 15 .
- Conductor 53 provides wear protection to riser 15 due to contact with rollers 41 .
- cylinder assemblies 17 are inverted in this alternative embodiment.
- Piston 21 sealingly engages the interior surface of cylinder 19 which contains pressurized gas as in the previously discussed embodiments.
- Cylinder 19 has an open lower end for receiving piston 21 , but it does not sealingly engage rod 23 in this embodiment. Accordingly, the lower end of piston 21 , below seals 22 is open to atmospheric pressure. Any fluid or debris dripping onto cylinder assembly 17 from above lands on cylinder 19 , which protects the sealing region between seals 22 and the interior surface of cylinder 19 . There is no separate surrounding rods 23 in this embodiment.
- cylinder assemblies 17 and tension ring 33 are located below deck 11 .
- Cylinder assemblies 17 extend downward at an angle so that the lower ends of cylinder assemblies 17 are radially inward and below the upper ends of cylinder assemblies 17 .
- Shroud 35 continues to protect rod 23 from any debris falling onto cylinder assemblies 17 from above.
- This embodiment is particularly useful for replacing tensioner assemblies on existing structures, like existing tension leg platforms, wherein the tension ring is located below the deck.
- gas over fluid pressure acts on the annular space between rod 23 and housing 19 to pull housing 19 upward.
- tension ring 33 is mounted to riser 15 , and guide rollers 41 are mounted in engagement with riser 15 or conductor 53 ( FIG. 3 ).
- Gas pressure in cylinder 19 exerts a desired upward force on riser 15 to maintain a desired tension in riser 15 .
- cylinder assemblies 17 retract.
- cylinder assemblies 17 extend.
- seals 22 are protected from drippings and debris from above while in both the contracted and retracted positions.
- shroud 35 also protects rod 23 and seals 26 , in addition to the sealing region located between piston 21 and the interior surface of cylinder 19 .
- FIGS. 7-11 shroud 35 is replaced with a shroud 35 ′ having telescoping shroud portions 35 a ′, 35 b ′, 35 c ′.
- piston and piston rod 22 , 23 , and cylinder 19 from the embodiments shown in FIGS. 1-6 are replaced with piston 22 ′, piston rod 23 ′, and cylinder 19 ′.
- FIGS. 7 and 8 are similar to the embodiment shown in FIGS. 1 and 2 , with upper deck 51 being positioned below engagement ring 31 .
- FIG. 7 illustrates the alternative embodiment in an extended position
- FIG. 8 illustrates the alternative embodiment in a contracted position.
- FIG. 9 is similar to the embodiment shown in FIG.
- FIGS. 10-11 are similar to the embodiment shown FIG. 5 , with cylinder 19 ′ being disposed above piston rod 23 ′ and shroud 35 ′.
- FIGS. 10 and 11 illustrate this alternative embodiment in both an extended and a contracted position.
- the alternative embodiments illustrated in FIGS. 7-11 also show cylinder assemblies 17 ′ extending substantially vertical rather than extending at an angle radially inward from lower deck 11 to upper deck 51 .
- shroud 35 ′ includes a plurality of tubular, telescoping shroud portions or segments 35 a ′, 35 b ′, and 35 c ′.
- outer shroud segment 35 a ′ has an inner diameter larger enough to receive intermediate shroud segment 35 b ′ and shroud segment 35 c ′.
- Intermediate shroud segment 35 b ′ preferably has an inner diameter large enough to receive inner or small shroud segment 35 c ′.
- Outer or large shroud segment 35 a ′ is preferably positioned above intermediate and small shroud segments 35 b ′, 35 c ′ so that shroud 35 ′ shields piston rod 23 ′ from drippings from above when shroud 35 ′ is both extended and contracted, whether cylinder is positioned below shroud 35 ′ ( FIGS. 7-9 ) or below shroud 35 ′ ( FIGS. 10-11 ).
- shroud segments 35 a ′, 35 b ′, 35 c ′ include upper and lower lips 61 , 63 for engaging each other when moving from the contracted position to the extended position.
- Lower lips 63 are preferably formed on an interior surface of the respective shroud segments for engaging an outer surface of another shroud segment disposed therein.
- Lower lips 63 are typically formed on a contraction end—or the end in the direction of movement of the shrouds during contraction—of each shroud segment.
- Upper lips 61 are preferably formed on an outer surface of the respective shroud segments for engaging an inner surface of another shroud.
- upper lips 61 are formed on an extension end—or the end in the direction of movement of the shrouds during extension—of each shroud segment.
- upper and lower lips 61 , 63 engage each other when shroud 35 ′ is in its extended position and help to define the overall length of shroud 35 ′ when extended.
- each intermediate segment 35 b′ includes both upper and lower lips 61 b , 63 b because each intermediate shroud segment receives a shroud segment, and is received by a larger shroud segment.
- large shroud segment 31 a ′ includes only lower lip 63 a, but has a flange 62 at its upper end for connecting to a piston rod connector flange 67 located on a piston rod connector 65 ( FIGS. 7-9 ), or a flange located at the upper end portion of cylinder 19 ′ ( FIGS. 10-11 ).
- small shroud segment 35 c ′ only includes upper lip 63 c.
- small shroud segment 35 c ′ also includes a flange 64 at its lower end for connecting to a flange located at the upper end portion of cylinder 19 ′ ( FIGS. 7-9 ) or to piston rod connector flange 67 ( FIGS. 10-11 ).
- piston rod 23 ′ is at least one shroud length longer than piston rod 23 in the previous embodiments because no shroud segment telescope over cylinder 19 ′.
- small shroud segment 35 c ′ could be adapted to telescope over an outer surface of cylinder 19 ′, for example with a lower lip 63 rather than a flange 64 , so that piston rod 23 ′ could have substantially the same length as piston rod 23 .
- seals 22 are protected from drippings and debris from above while in both the contracted and retracted positions.
- shroud 35 ′ also protects rod 23 ′ and seals 26 , in addition to the sealing region located between piston 21 ′ and the interior surface of cylinder 19 .
- Protecting the outer surface of piston rod 23 ′ allows for a less expensive manufacture of piston rod 23 ′ because a protective layer will not be necessary.
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
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- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US11/507,865 US20060280560A1 (en) | 2004-01-07 | 2006-08-22 | Riser tensioner with shrouded rods |
GB0716193A GB2441212B (en) | 2006-08-22 | 2007-08-20 | Riser tensioner with shrouded rods |
NO20074230A NO337099B1 (no) | 2006-08-22 | 2007-08-20 | Overflatemontasje for undersjøiske brønner og spennanordning for å opprettholde spenn i et stigerør |
US12/715,552 US8286714B2 (en) | 2004-01-07 | 2010-03-02 | Riser tensioner with shrouded rods |
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US53483104P | 2004-01-07 | 2004-01-07 | |
US11/020,857 US20050147473A1 (en) | 2004-01-07 | 2004-12-23 | Riser tensioner with shrouded rods |
US11/507,865 US20060280560A1 (en) | 2004-01-07 | 2006-08-22 | Riser tensioner with shrouded rods |
Related Parent Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US11/020,857 Continuation-In-Part US20050147473A1 (en) | 2004-01-07 | 2004-12-23 | Riser tensioner with shrouded rods |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US12/715,552 Continuation US8286714B2 (en) | 2004-01-07 | 2010-03-02 | Riser tensioner with shrouded rods |
Publications (1)
Publication Number | Publication Date |
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US20060280560A1 true US20060280560A1 (en) | 2006-12-14 |
Family
ID=38566653
Family Applications (2)
Application Number | Title | Priority Date | Filing Date |
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US11/507,865 Abandoned US20060280560A1 (en) | 2004-01-07 | 2006-08-22 | Riser tensioner with shrouded rods |
US12/715,552 Active 2025-11-07 US8286714B2 (en) | 2004-01-07 | 2010-03-02 | Riser tensioner with shrouded rods |
Family Applications After (1)
Application Number | Title | Priority Date | Filing Date |
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US12/715,552 Active 2025-11-07 US8286714B2 (en) | 2004-01-07 | 2010-03-02 | Riser tensioner with shrouded rods |
Country Status (3)
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US (2) | US20060280560A1 (no) |
GB (1) | GB2441212B (no) |
NO (1) | NO337099B1 (no) |
Cited By (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20080304916A1 (en) * | 2007-06-11 | 2008-12-11 | Gerald Crotwell | Pull-style tensioner system for a top-tensioned riser |
US20090255683A1 (en) * | 2008-04-10 | 2009-10-15 | Mouton David E | Landing string compensator |
US20090304454A1 (en) * | 2006-07-06 | 2009-12-10 | Enovate Sytems Limited | Workover Riser Compensator System |
US20110209651A1 (en) * | 2010-03-01 | 2011-09-01 | My Technologies, L.L.C. | Riser for Coil Tubing/Wire Line Injection |
CN102673747A (zh) * | 2011-02-11 | 2012-09-19 | 韦特柯格雷公司 | 海上立管张紧器 |
US8689880B2 (en) * | 2007-04-11 | 2014-04-08 | Halliburton Energy Services, Inc. | Multipart sliding joint for floating rig |
US8944723B2 (en) | 2012-12-13 | 2015-02-03 | Vetco Gray Inc. | Tensioner latch with pivoting segmented base |
US9010436B2 (en) | 2012-12-13 | 2015-04-21 | Vetco Gray Inc. | Tensioner latch with sliding segmented base |
US20150136412A1 (en) * | 2010-04-20 | 2015-05-21 | Dril-Quip, Inc | Riser tensioning system |
US9341033B1 (en) * | 2013-08-12 | 2016-05-17 | Phyllis A. Jennings | Riser tensioner assembly |
EP2870315A4 (en) * | 2012-07-03 | 2016-07-13 | Seahorse Equip Corp | UPRIGHT COLUMN SYSTEM TURNED UP |
Families Citing this family (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
NO331342B1 (no) | 2009-09-15 | 2011-12-05 | Nat Oilwell Norway As | Stigerors strekkanordning |
US20120279719A1 (en) * | 2011-05-03 | 2012-11-08 | Benton Frederick Baugh | Internal drilling riser centralizer |
US9068403B2 (en) * | 2012-08-16 | 2015-06-30 | The Technologies Alliance, Inc. | Riser tensioner frame assembly |
FR3025787B1 (fr) * | 2014-09-16 | 2019-06-07 | IFP Energies Nouvelles | Systeme de controle du deplacement d'une charge |
US10174566B2 (en) | 2016-03-02 | 2019-01-08 | Vetco Gray, LLC | Inverted pull-up riser tensioner |
US10648251B2 (en) * | 2017-01-25 | 2020-05-12 | Tt Technologies, Inc. | Directional drill stem rod loader and method |
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US3984990A (en) * | 1975-06-09 | 1976-10-12 | Regan Offshore International, Inc. | Support means for a well riser or the like |
US4004532A (en) * | 1975-05-05 | 1977-01-25 | Western Gear Corporation | Riser tension system for floating platform |
US4808035A (en) * | 1987-05-13 | 1989-02-28 | Exxon Production Research Company | Pneumatic riser tensioner |
US5158397A (en) * | 1991-05-03 | 1992-10-27 | Paul-Munroe Hydraulics, Inc | Passive fire protective systems for articulating joints and flexible connections |
US5169265A (en) * | 1991-09-27 | 1992-12-08 | Paul-Munroe Hydraulics, Inc. | Passive fire protection system for marine risers |
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US6554072B1 (en) * | 2000-06-15 | 2003-04-29 | Control Flow Inc. | Co-linear tensioner and methods for assembling production and drilling risers using same |
US6655569B1 (en) * | 1999-05-21 | 2003-12-02 | Cetram Pty. Limited | Power actuated tool and shroud for use with the tool |
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US4432420A (en) * | 1981-08-06 | 1984-02-21 | Exxon Production Research Co. | Riser tensioner safety system |
US5252005A (en) * | 1992-03-03 | 1993-10-12 | Paul-Munroe Hydraulics, Inc. | Cylinder rod fire protection system |
AU1674392A (en) * | 1992-03-26 | 1993-10-21 | Pm Engineering Norway A.S. | Load sharing riser tensioning apparatus |
US20050147473A1 (en) * | 2004-01-07 | 2005-07-07 | Vetco Gray Inc. | Riser tensioner with shrouded rods |
-
2006
- 2006-08-22 US US11/507,865 patent/US20060280560A1/en not_active Abandoned
-
2007
- 2007-08-20 GB GB0716193A patent/GB2441212B/en not_active Expired - Fee Related
- 2007-08-20 NO NO20074230A patent/NO337099B1/no unknown
-
2010
- 2010-03-02 US US12/715,552 patent/US8286714B2/en active Active
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Cited By (23)
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US20140338920A1 (en) * | 2006-07-06 | 2014-11-20 | Enovate Systems Limited | Workover riser compensator system |
US20090304454A1 (en) * | 2006-07-06 | 2009-12-10 | Enovate Sytems Limited | Workover Riser Compensator System |
US20120205118A1 (en) * | 2006-07-06 | 2012-08-16 | Enovate Systems Limited | Workover riser compensator system |
US9038731B2 (en) * | 2006-07-06 | 2015-05-26 | Enovate Systems Limited | Workover riser compensator system |
US8727014B2 (en) * | 2006-07-06 | 2014-05-20 | Enovate Systems Limited | Workover riser compensator system |
US8689880B2 (en) * | 2007-04-11 | 2014-04-08 | Halliburton Energy Services, Inc. | Multipart sliding joint for floating rig |
WO2008154545A2 (en) | 2007-06-11 | 2008-12-18 | Technip France | Pull-style tensioner system for a top-tensioned riser |
WO2008154545A3 (en) * | 2007-06-11 | 2010-07-15 | Technip France | Pull-style tensioner system for a top-tensioned riser |
US20080304916A1 (en) * | 2007-06-11 | 2008-12-11 | Gerald Crotwell | Pull-style tensioner system for a top-tensioned riser |
US8021081B2 (en) | 2007-06-11 | 2011-09-20 | Technip France | Pull-style tensioner system for a top-tensioned riser |
AU2008261719B2 (en) * | 2007-06-11 | 2014-03-13 | Technip France | Tensioner system for a riser |
US20090255683A1 (en) * | 2008-04-10 | 2009-10-15 | Mouton David E | Landing string compensator |
US8733447B2 (en) | 2008-04-10 | 2014-05-27 | Weatherford/Lamb, Inc. | Landing string compensator |
US20110209651A1 (en) * | 2010-03-01 | 2011-09-01 | My Technologies, L.L.C. | Riser for Coil Tubing/Wire Line Injection |
US20150136412A1 (en) * | 2010-04-20 | 2015-05-21 | Dril-Quip, Inc | Riser tensioning system |
US9181761B2 (en) * | 2010-04-20 | 2015-11-10 | Dril-Quip, Inc. | Riser tensioning system |
US8496409B2 (en) | 2011-02-11 | 2013-07-30 | Vetco Gray Inc. | Marine riser tensioner |
CN102673747A (zh) * | 2011-02-11 | 2012-09-19 | 韦特柯格雷公司 | 海上立管张紧器 |
AU2012200634B2 (en) * | 2011-02-11 | 2016-10-20 | Vetco Gray Inc. | Marine riser tensioner |
EP2870315A4 (en) * | 2012-07-03 | 2016-07-13 | Seahorse Equip Corp | UPRIGHT COLUMN SYSTEM TURNED UP |
US8944723B2 (en) | 2012-12-13 | 2015-02-03 | Vetco Gray Inc. | Tensioner latch with pivoting segmented base |
US9010436B2 (en) | 2012-12-13 | 2015-04-21 | Vetco Gray Inc. | Tensioner latch with sliding segmented base |
US9341033B1 (en) * | 2013-08-12 | 2016-05-17 | Phyllis A. Jennings | Riser tensioner assembly |
Also Published As
Publication number | Publication date |
---|---|
US20100158615A1 (en) | 2010-06-24 |
NO20074230L (no) | 2008-02-25 |
GB2441212A (en) | 2008-02-27 |
GB0716193D0 (en) | 2007-09-26 |
NO337099B1 (no) | 2016-01-18 |
GB2441212B (en) | 2011-04-06 |
US8286714B2 (en) | 2012-10-16 |
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