WO2014056045A1 - Raccordement d'une conduite d'hydrocarbures - Google Patents

Raccordement d'une conduite d'hydrocarbures Download PDF

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Publication number
WO2014056045A1
WO2014056045A1 PCT/AU2013/001182 AU2013001182W WO2014056045A1 WO 2014056045 A1 WO2014056045 A1 WO 2014056045A1 AU 2013001182 W AU2013001182 W AU 2013001182W WO 2014056045 A1 WO2014056045 A1 WO 2014056045A1
Authority
WO
WIPO (PCT)
Prior art keywords
conduit
sealing device
valve
apparatus defined
seal
Prior art date
Application number
PCT/AU2013/001182
Other languages
English (en)
Inventor
Jim Lawson HUGHES
Dale Parker
Original Assignee
Hp Wellhead Solutions Pty Ltd
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
Priority claimed from AU2012904452A external-priority patent/AU2012904452A0/en
Application filed by Hp Wellhead Solutions Pty Ltd filed Critical Hp Wellhead Solutions Pty Ltd
Publication of WO2014056045A1 publication Critical patent/WO2014056045A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E21B43/0122—Collecting oil or the like from a submerged leakage

Definitions

  • the present invention relates generally to connecting to a
  • a blowout in the context of well drilling is the uncontrolled release of crude oil and/or natural gas from an oil well or gas well after pressure control systems have failed.
  • blowout preventer When drilling a well, a large specialised valve called a "blowout preventer" or “BOP” is normally used to cope with extreme erratic pressures and uncontrolled flow (formation kick) emanating from a well reservoir, and for preventing well blowouts.
  • blowout preventers In additioh to controlling the downhole pressure and the flow of oil and gas, blowout preventers are intended to prevent tubing (e.g. drill pipe and well casing), tools and drilling fluid from being blown out of the wellbore when a blowout threatens. Blowout preventers are critical to the safety of crew, rig, and the environment, and to the monitoring and maintenance of well integrity. Consequently, blowout preventers are intended to be fail-safe devices.
  • Blowout preventers are installed early on in the process of drilling a well before any blowouts can occur.
  • the blowout preventer can usually be successfully operated to bring the well back under control.
  • it can be very difficult to regain control over the well, In such situations, it would be desirable to have an apparatus that can be readily installed on the well after the blowout has occurred, and that can be employed to bring the well back under control.
  • an apparatus for connecting to a hydrocarbon conduit comprising a sealing device including a body through which a passage for receiving the conduit extends, and a seal operable to seal a gap between the body and the conduit.
  • the apparatus is adapted for connecting to a riser that extends from the wellbore of a hydrocarbon well such as a subsea hydrocarbon well, for example. It is also preferred that the apparatus is for connecting to a hydrocarbon conduit such as a hydrocarbon pipeline or flowline.
  • the passage comprises a bore.
  • the sealing device comprises an annular blowout preventer valve
  • the seal comprises a packing unit of the annular blowout preventer valve. It is preferred that the annular blowout preventer valve comprises a spherical blowout preventer valve.
  • the apparatus also comprises a guide for guiding the conduit into the passage of the sealing device body.
  • the guide By guiding the conduit into the passage of the sealing device body, the guide allows for easy alignment and engagement of the sealing device body with the conduit. It is preferred that the guide comprises a funnel.
  • one or more openings may be provided in a side wall of the guide so that at least some of the hydrocarbon stream can pass through the side wall of the guide without exerting high loads on the guide, sealing device, or any components that may be secured thereto (e.g. a riser assembly).
  • the openings may be any suitable shape, it is preferred that the openings comprise slots. The size, shape, and arrangement of the slots are preferably such that the guide is configured substantially as a cage.
  • the apparatus also comprises a securing device for securing the apparatus to the conduit.
  • the securing device comprises one or more pins operable to be inserted into one or more latching/locking features of the conduit.
  • the one or more latchingflocking features comprise one or more holes in a wall of the conduit.
  • the securing device comprises a compression fitting.
  • the apparatus also comprises a drill for drilling the one or more holes in the wall of the conduit.
  • the apparatus also comprises a diverter valve operable to divert a fluid flowing from the conduit. It is preferred that the diverter valve is also operable to actuate the sealing device so that the seal of the sealing device is able to seal the gap between the sealing device body and the conduit.
  • the diverter valve comprises a piston, a valve body comprising a valve seat for the piston to seal against, and an inlet that extends through the valve body of the diverter valve to the valve seat so that a fluid injected through the inlet is able to clean the valve seat.
  • the apparatus also comprises an automatic fail-safe device/system that is able to operate the diverter valve in the event of the failure of other systems that are operable to control the diverter valve.
  • the apparatus also comprises a riser or other conduit such as a flowline through which a fluid flowing from the hydrocarbon conduit is able to flow.
  • a riser or other conduit such as a flowline through which a fluid flowing from the hydrocarbon conduit is able to flow.
  • the apparatus also comprises a cutting device for cutting off a portion of the conduit prior to the passage of the sealing device receiving the conduit.
  • the cutting device comprises a saw.
  • the apparatus also comprises a jamming prevention device for preventing the cutting device from jamming as it cuts through the conduit.
  • the jamming prevention device is able to prevent a partially cut-off portion of the conduit from collapsing under its own weight or the weight of any devices secured to it back on to the remainder of the conduit and the cutting device as the conduit is being cut.
  • the apparatus also comprises a clamping device for clamping the apparatus to the conduit.
  • the apparatus also comprises a hydraulic cylinder operable to lower the sealing device on to the conduit.
  • the apparatus also comprises a support for supporting the apparatus on a substantially horizontal surface when the conduit has a substantially horizontal orientation.
  • the apparatus also comprises a choke and kill line that is able to communicate with the passage of the sealing device body.
  • the apparatus also comprises a control valve that is connected to the choke and kill line.
  • a sealing device for the apparatus according to the first broad aspect of the present invention, the sealing device comprising a body through which a passage for receiving a " hydrocarbon conduit extends, and a seal operable to seal a gap between the body and the conduit.
  • a fourth broad aspect of the present invention there is provided a method of operating the sealing device according to the third broad aspect of the present invention, the method comprising the steps of:
  • Figure 1 is a perspective view of a subsea well riser and a partial cross-sectional perspective view of a first preferred embodiment of an apparatus for connecting to the riser;
  • Figure 2 is a perspective view of a subsea well riser and a partial cross-sectional perspective view of a second preferred embodiment of an apparatus for connecting to the riser;
  • Figure 3 is a cross-sectional view of the sealing device and the diverter valve of the apparatus depicted in figure 2;
  • Figure 4 is a perspective view of a lower portion of the apparatus depicted in figure 2 which includes the clamping device, one of the drilling devices, and the hydraulic cylinders for lowering the sealing device over the well riser;
  • Figure 5 is a cross-sectional plan view of the apparatus depicted in figure 2 which depicts the clamping device, and the hydraulic cylinders for lowering the sealing device over the well riser;
  • Figure 6 is a perspective view of the cutting device of the apparatus depicted in figure 2 and the hydraulic cylinders for lowering the sealing device of the apparatus over the well riser;
  • Figure 7 is a cross-sectional plan view of the apparatus depicted in figure 2 which depicts the cutting device, and the hydraulic cylinders for lowering the sealing device over the well riser;
  • Figure 8 is a perspective view of the sealing device and funnel of the apparatus depicted in figure 2 when the sealing device comprises an annular blowout preventer valve rather than a spherical blowout preventer valve;
  • Figure 9 depicts the sealing device of the apparatus depicted in figure 2 when the sealing device comprises an annular blowout preventer valve and as the sealing device is lowered on to the riser by the hydraulic cylinders of the apparatus;
  • Figure 10 is a perspective view of the apparatus depicted in figure 9 when a riser pipe is connected to the annular blowout preventer;
  • Figure 11 is a cross-sectional plan view of the apparatus which is similar to figure 7 except that it also shows a support which can be used to support the apparatus on the seabed when the riser has a horizontal orientation;
  • Figure 12 is a diagrammatic cross-sectional view of the sealing device depicted in figure 3 and a first alternative diverter valve;
  • Figure 13 is a diagrammatic cross-sectional view of the sealing device depicted in figure 3 and a second alternative diverter valve;
  • Figure 14 is a diagrammatic cross-sectional view of the sealing device depicted in figure 3 and a third alternative diverter valve.
  • Figure 15 is a cross-sectional view of a third preferred embodiment of an apparatus for connecting to a subsea well riser. DESCRIPTION OF EMBODIMENTS
  • FIG. 1 there is shown an apparatus/rescue riser clamp
  • Apparatus 500 comprises a sealing device 502 that comprises an annular blowout preventer valve 503.
  • Annular blowout preventer valve 503 includes a body 504 through which a passage in the form of a bore 505 for receiving the pipe 501 extends.
  • annular blowout preventer valve 503 includes a seal comprising a packing unit (not depicted) operable to seal a gap (not depicted) between the body 504 and the pipe 501 so that a fluid flowing from the pipe 501 is prevented by the seal from leaking out of the bore 505 through the gap.
  • a guide comprising a funnel 506 for funneling the fluid flowing from the pipe 501 into the bore 505 of the sealing device 502 and for guiding the pipe
  • a securing device 508 for securing the apparatus 500 to the pipe 501 is secured to an upper end 509 of the body 504.
  • Securing device 509 includes a body 510 through which the bore 505 extends.
  • a plurality of screw-in locking pins 511 are housed within the body 510 and are able to be extended into and retracted out of the bore 505 by screwing them in an appropriate direction.
  • one or more holes 5 2 are drilled in a wall 513 of the pipe 50 .
  • the purpose of these holes 512 is to receive the pins 511 of the securing device 508 so that the apparatus 500 is thereby secured to the pipe 501.
  • Apparatus 500 can include other components such as a diverter valve, riser pipe, or another blow out preventer valve so that the fluid flowing from the pipe 501 is able to flow through them.
  • a diverter valve such as crude oil and/or natural gas
  • the apparatus 500 could include a diverter valve and another blowout preventer valve.
  • the diverter valve would enable the apparatus 500 to be initially used to divert the hydrocarbons to storage tanks so that the hydrocarbons do not continue to pollute the
  • blowout preventer valve and the diverter valve could be operated to completely shut down the flow of
  • the apparatus 500 could be lowered on to the pipe 501 , with or without the assistance of a Remotely Operated underwater Vehicle (ROV), by a crane of a Mobile Offshore Drilling Unit (MODU) which is positioned above the pipe 501.
  • ROV Remotely Operated underwater Vehicle
  • MODU Mobile Offshore Drilling Unit
  • the ROV would operate the securing device 508 so that the pins 511 are inserted into the holes 512 to thereby secure the apparatus 500 to the pipe 501.
  • FIG. 1 An apparatus/rescue riser clamp 520 for connecting to a subsea hydrocarbon well riser pipe 501 is depicted in figures 2 to 7.
  • the apparatus 520 comprises a sealing device
  • annular blowout preventer 503 of the apparatus 520 is a spherical blowout preventer 521.
  • Apparatus 520 also includes a diverter valve 522.
  • Diverter valve 522 includes a valve body 523 that includes a passage in the form of a bore 524 through which fluid flowing from the pipe 501 is able to flow.
  • Valve body 523 also includes a plurality of outlets 525 connected to the bore 524 by a plurality of upwardly inclined passages 526 so that the fluid flowing through the bore 524 is able to be diverted to flow from the bore 524 and out of the valve body 523 through each outlet 525 instead of all of the way through the bore 524.
  • Diverter valve 522 also includes a hollow piston 527 that is received by the bore 524 of the valve body 523. Piston 527 is slidingly moveable along the bore 524 of the valve body 523 so as to control the flow of the fluid through each outlet 525 and to actuate the sealing device 502. [0044] An upper end 528 of the valve body 523 is machined or otherwise configured so that it is able to be connected to a riser pipe 529 which is also part of the apparatus 520.
  • the valve body 523 includes a valve seat 530, and an upper end 531 of the piston 527 is configured so that the upper end 531 is able to sealingly engage with the valve seat 530.
  • the spherical blowout preventer valve 521 comprises an annular valve body 532 that includes a passage in the form of a bore 533 through which fluid flowing from the pipe 501 is able to flow.
  • the valve body 532 is inserted into the bore 524 of the diverter valve body 523 such that the valve body 532 and the piston 527 overlap with each other as shown in figure 3.
  • the diverter valve body 523 and the blowout preventer valve body 532 are secured together by a H4 connector or a latch locking system (not depicted).
  • the valve bodies 523, 532 are secured together such that the joint between them is sealed.
  • a piston chamber 534 is defined by the valve bodies 523, 532.
  • the piston chamber 534 is sealed by a plurality of Oring seals (not depicted) that are located in grooves 535 in the valve body 523, and by a plurality of O-ring seals (not depicted) that are located in a plurality of grooves 536 in the valve body 532.
  • the piston chamber 534 is divided into separate sealed sections by a plurality of O-ring seals (not depicted) that are located in a plurality of grooves 537 in the piston 527.
  • the maximum length of travel of the piston 527 in the piston chamber 534 is the same as the length of an upper section 538 of the piston 527.
  • a hollow piston 539 is received by the bore 524 such that the piston
  • a piston chamber 540 is defined by the valve body 532.
  • the piston chamber 540 is sealed by a plurality of O-ring seals (not depicted) that are located in a plurality of grooves 541 and 542 in the piston 539, and by the plurality of O-ring seals (not depicted) in the plurality of grooves 536 in the piston 527.
  • the diverter valve 522 can only be opened by roughly 75% before the piston 527 reaches the maximum extent of its travel within the piston chamber 540.
  • a seal ring 543 is inserted into the bore 533 such that it extends around the piston 539.
  • the seal ring 543 is secured to a removable head 544 that includes a curved, spherical inner surface 545.
  • a packing unit 546 is disposed between the piston 539 and the head 544.
  • the head 544 is secured to the valve body 532 by a plurality of bolts and/or a latch locking system.
  • a wear plate (not depicted) is located between the head 544 and the packing unit 546, and another wear plate (not depicted) is located between the piston 539 and the packing unit 546.
  • the apparatus 520 includes a funnel 506 for funneling fluid flowing from the pipe 501 into the bore 533 of the valve body 532.
  • a lower end 547 of the head 544 is machined or otherwise configured so that it is able to be connected to the funnel 506.
  • the packing unit 546 includes a curved, rubber or elastomeric annular body 548, and a plurality of curved metal inserts (not depicted) corresponding to the curved, spherical inner surface 545 of the head 544.
  • the metal inserts are disposed within the annular body 548 in a generally circular fashion and spaced apart in radial planes extending from a central axis of the bore 533.
  • the piston 539 resides in a piston chamber 549 which is sealed by the plurality of O-ring seals located in the grooves 542 in the piston 539, and by a plurality of O-ring seals (not depicted) that are located in grooves 550 in the seal ring 543.
  • the seal ring 543 and the O-rings located in the grooves 550 seal the chamber 549 off from the packing unit 546.
  • the piston chamber 549 is divided into separate sealed section by a plurality of O-ring seals (not depicted) that are located in a plurality of grooves 551 in the piston 539.
  • the piston 539 reaches its maximum extent of upward travel in the piston chamber 549 when the piston 527 reaches it maximum extent of upward travel in the piston chamber 534,
  • the valve body 523 includes a port 552 that is connected to an upper section of the piston chamber 534, and a port 553 that is connected to a lower section of the piston chamber 534. Hydraulic fluid can be pumped into or vented from the upper section of the piston chamber 534 via the port 552. Similarly, hydraulic fluid can be pumped into or vented from the lower section of the piston chamber 534 via the port 553.
  • the valve body 532 includes a port 554 that is connected to the piston chamber 540 so that hydraulic fluid can be pumped into or vented from the piston chamber via the port 554.
  • Sealing device 502 and the funnel 506 of the apparatus 520 are secured to a support frame 555 which is in turn secured to four pistons 556 belonging to four upstanding hydraulic cylinders 557. Cylinders 557 are operable to lower the sealing device 502 on to the pipe 501, and can also be used to raise the sealing device 502 above the pipe 501.
  • Apparatus 520 also includes a clamping device 558 for clamping the apparatus 520 to the pipe 501.
  • Clamping device 558 includes a pipe backrest 559 which is secured to a cross member 560 and a cross member 561 which are both secured to the same pair of cylinders 557 such that they extend between the cylinders 557 at different locations.
  • Two jaws 562 are hinged to the backrest 559 and the jaws 562 are operable to be opened and closed by a respective hydraulic cylinder 563 that extends between and that is secured to each jaw 562 and the cross member 560.
  • Jaws 562 are also operable to be opened and closed by a respective hydraulic cylinder 564 that extends between and that is secured to each jaw 562 and a respective cross member 565 secured to a respective pair of the hydraulic cylinders 557. Cylinders 563 and 564 are operable to open and close the jaws 562 such that the pipe 50 is able to be clamped by the jaws 562 between them and the backrest 559 as shown.
  • the locations of the hinges that secure the jaws 562 to the backrest 559 are off cenlre to allow for easy insertion and removal of the pipe 501 against the backrest 559 and between the jaws 562.
  • Inserts may be fitted to the back rest 559 and the jaws 562 so that smaller diameter pipes are able to be clamped by the jaws 562 between them and the backrest 559.
  • the apparatus 520 may also include a securing device 508 for securing the apparatus 520 to the pipe 501.
  • the apparatus 520 may also include three drills 566 for drilling three holes 512 in the wall 513 of the pipe 501 for receiving the pins 511 of the securing device 508,
  • the drills 566 may for example be hydraulic, electric, or ROV operated drills. Two of the drills 566 are each secured to a respective one of the jaws 562, with the third drill 566 being secured to the backrest 559.
  • Apparatus 520 also includes a cutting device 567 for cutting off a portion of the pipe 501 prior to the bore 533 of the sealing device 502 receiving the pipe 501.
  • Cutting device 567 comprises a saw 568 and includes a motor 569 that is secured to the cross member 561.
  • Motor 569 may for example be a hydraulic, electric, or ROV operated motor.
  • a rotatable drive shaft 570 is coupled to the motor 569 and to a respective gearbox 571 secured to each cross member 565 such that the motor 569 is able to rotate the shaft 570 about its longitudinal axis.
  • a respective threaded drive shaft 572 is coupled to each gearbox 571 and extends along a respective one of the cross members 565 as shown.
  • the threaded drive shafts 572 are secured to the cross members 565 and are coupled to the gearboxes 571 such that they are able to be rotated about their longitudinal axes by the motor 569.
  • a travelling block 573 is slideably engaged with a dovetail track way 574 of one of the cross members 565, and a motor 575 is slideably engaged with a dovetail track way 576 of the other one of the cross members 565.
  • the block 573 and the motor 575 are coupled to the drive shafts 572 such that rotation of the drive shafts 572 by the motor 569 causes the block 573 and the motor 575 to respectively slideably move along the way 574 and the way 576.
  • Motors 569 and 575 may for example be hydraulic, electric, and/or ROV operated motors.
  • An endless cutting chain 577 is trained around a drive wheel or sprocket 578 which is able to be rotated by the motor 575, and around an idler wheel or sprocket 579 which is mounted on the block 573 such that it is able to rotate relative thereto.
  • Cutting chain 577 can be circulated around the wheels 578, 579 by operating the motor 575.
  • the direction of circulation of the cutting chain 577 can be reversed simply by operating the motor 575 to reverse the direction of rotation of the drive wheel 578.
  • the tension on the cutting chain 577 can be adjusted by moving the wheel 579 so that it is displaced relative to the wheel 578.
  • Saw 568 is able to cut through the pipe 501 by firstly operating the motor 569 to position the block 573 and the motor 575 along the threaded shafts 572 such that the cutting chain 577 is located off to one side of the pipe 501.
  • Motor 575 rotates the cutting chain 577 at an appropriate speed and in an appropriate direction to cut the pipe 501.
  • motor 569 is operated to progressively move the block 573 and the motor 575 further towards the pipe 501 in a synchronous manner.
  • the motor 575 is operated so that circulation of the chain 577 ceases and the motor 569 is operated to return the block 573 and motor 575 to their starting positions on the opposite side of the pipe 50 .
  • Apparatus 520 may also include a jamming prevention device 580 for preventing the cutting device 567 from jamming as it cuts through the pipe 501.
  • Jamming prevention device 580 may include a hydraulic cylinder 581 that is operable to drive a pointed member such as a chisel-ended member in to the cut in the pipe 501 behind the cutting chain 577 so that the pointed member is able to prevent the portion of the pipe 501 above the cut resting on the chain 577 and preventing it from circulating.
  • the apparatus 520 may have an annular blowout preventer valve 590 as shown in figure 8.
  • the apparatus 520 need not include the diverter valve 522 or anything else connected to the sealing device 502.
  • the riser pipe 529 may be connected directly to the sealing device 502 as shown in figure 10.
  • the riser pipe 529 may extend to an intervention vessel or an oil rig and may allow tooling to be passed through the diverter valve 522 (if present) and the sealing device 502 once they are securely locked on to the riser pipe 501.
  • the diverter valve 522 is able to divert the flow of hydrocarbons from the riser pipe 501 through the outlets 525 so that it is then possible to restring the well.
  • the apparatus 520 can be employed in a similar manner to the apparatus 500 to bring a well that includes the riser 501 under control.
  • the apparatus 520 can be lowered as a single unit over the riser 501 by a crane that is connected to the apparatus 520 by a plurality of cables that are connected to the tops of the hydraulic cylinders 557.
  • the apparatus 520 can be lowered as a single unit over the riser 501 by a riser or string attached to the diverter valve 522 (if present), or the sealing device 502 if the apparatus 520 does not include the diverter valve 522.
  • a ROV may be used to assist in positioning the apparatus 520 over the riser 501.
  • the apparatus 520 Is positioned relative to the riser 501 so that the riser 501 contacts the backrest 559 and is located between the jaws 562 of the clamping device 558.
  • the flow rate of hydrocarbons from the riser 501 will generally be very high, consequently the clamping device 558 is brought into proximity of the riser 501 from the side of the riser 501 such that the sealing device 502 is not passed across the stream of hydrocarbons flowing out of the riser 501 which would tend to deflect the sealing device 502 off centre relative to the riser 501.
  • the cutting device 567 is positioned so that it is located beneath that portion of the riser 501.
  • the hydraulic cylinders 563, 564 of the clamping device 558 are operated so that the riser 501 is firmly clamped between the jaws 562 and the backrest 559 of the clamping device 558.
  • the cutting device 567 and the jamming prevention device 580 are operated in the previously described manner to cut off and dress the portion of the riser 501 which is located above the cutting device 567.
  • the drills 566 are operated to drill the holes 512 in the pipe wall 513.
  • the jaws 562 of the clamping device 558 are loosened by suitably operating the hydraulic cylinders 563, 564.
  • the crane or riser to which the apparatus 520 is still attached is then operated so as to lower the apparatus 520 further down the riser 501 to a position which will allow the sealing device 502 to be lowered on to the riser by operating the hydraulic cylinders 557, and which will also allow the securing device 508 (if present) to be operated to insert the pins 5 1 into the holes 512 so that the apparatus 520 is securely locked to the riser 501.
  • the hydraulic cylinders 557 are operated to retract the pistons 556 so that the sealing device 502 is drawn down over the riser 501 in such a manner that the riser 501 is received by the bore 533 of the sealing device 502.
  • the apparatus 520 includes a securing device 508, the sealing device 502 is drawn down over the riser 501 so that the securing device 508 can be operated to insert its pins 511 into the holes 512 in the pipe wall 513 so that the apparatus 520 is securely locked to the riser 501.
  • the funnel 506 guides the riser pipe 501 into the sealing device 502 and also guides fluid flowing from the pipe 501 into the device 502.
  • the sealing device 502 is operated so that that the gap between the valve body 523 and the riser 501 is sealed by the seal of the sealing device 502 so that any hydrocarbons flowing from the riser 501 cannot pass or leak through the gap at the bottom of the sealing device 502.
  • the packing unit 546 which functions as the seal can be operated to seal the gap. This can be done in a number of ways.
  • One way is to pump hydraulic fluid into the upper section of the piston chamber 549 through a port in the valve body 532 that leads to the chamber 549, and by allowing hydraulic fluid in the lower section of the piston chamber 549 to be vented through another port in the valve body 532 that leads to the chamber 549. This moves the piston 539 downwardly along the bore 533. As the piston 539 moves downwards it translates force to packing unit 546. The force translated to the packing unit 546 from the piston 539 is directed downward toward the head 544.
  • the packing unit 546 displaces downward and inwardly, which compresses the packing unit 546 against the riser 501 so that the packing unit 546 forms a seal between the riser 501 and the valve body 532,
  • Another way to operate the spherical blowout preventer valve 521 so that the packing unit 546 forms a seal between the riser 501 and the valve body 532 is by operating the diverter valve 522 so that the diverter valve 522 thereby actuates the spherical blowout preventer 521.
  • This can be accomplished by pumping hydraulic fluid into the upper section of the piston chamber 534 through the port 552 and by venting hydraulic fluid in the lower section of the piston chamber 534 through the port 553 so that the piston 527 is moved downwards towards the piston 539.
  • hydraulic fluid in the piston chamber 540 is vented therefrom through the port 554. After the piston 527 reaches the piston 539 it continues to move
  • the diverter valve 522 remains in the fully open position for as long as is required for the well to remain open so that fluid flowing from the well is diverted to flow from the bore 524 and out of the valve body 523 through the outlets 525.
  • This second method of operation of the spherical blowout preventer valve 521 can be particularly useful in the event that the spherical blowout preventer 521 has a hydraulic failure which prevents the packing unit 546 from being moved to the closed position by pumping hydraulic fluid into the upper section of the piston chamber 549 and venting hydraulic fluid from the lower section of the piston chamber 549.
  • the diverter valve 522 in the manner just described fully opens the valve 522 so that fluid that flows from the riser 501 is diverted to flow through the passages 526 and out of the outlets 525 of the diverter valve 522 rather than all of the way through the diverter valve 522 through the bore 524.
  • the outlets 525 may be connected to pipes or hoses that lead to a storage tank on a floating production storage and offloading (FPSO) vessel or elsewhere so that the fluid is captured and does not pollute the surrounding environment.
  • FPSO floating production storage and offloading
  • a vacuum may be applied to the pipes or hoses connected to the outlets 525 to make it easier to fit the apparatus 520 on to the riser pipe 501.
  • the piston 527 blocks the passages 526 and therefore the outlets 525 so that no fluid is able to flow from the bore 524 into the passages 526 and out of the valve body 523 through the outlets 525. Instead, the fluid will simply pass through the bore 524 and flow into the riser pipe 529.
  • the diverter valve 522 is able to be opened by a maximum of about 75% before the piston 527 contacts the piston 539 of the spherical blowout preventer valve 521 , As mentioned above, if the piston 527 is operated so as to operate the spherical blowout preventer valve 521, the diverter valve 522 will then be fully open (i.e. 100% open) so that more hydrocarbons can flow out of the valve body 523 through the outlets 525.
  • the apparatus 500, 520 may include another blowout preventer valve (not depicted) such as an annular or spherical blowout preventer valve, for example.
  • This additional blowout preventer valve may be operable to completely shut down the flow of hydrocarbons from the riser pipe 501.
  • the diverter valve 522 would also need to be closed in order for the flow of hydrocarbons from the riser pipe 501 to be completely shut down, and this would usually be done after the additional blowout preventer valve is closed.
  • the diverter valve 522 can be closed by pumping hydraulic fluid into the lower section of the piston chamber 534 through the port 553, pumping hydraulic fluid into the piston chamber 540 through the port 554, and by allowing hydraulic fluid in the upper section of the piston chamber 534 to be vented out through the port 552.
  • the diverter valve 522 is closed once the upper end 531 of the piston 527 sealingly engages with the valve seat 530 so that fluid from the well to which the riser pipe 501 is connected is no longer able to flow from the bore 524 and out of the valve body 523 through the outlets 525.
  • the spherical blowout preventer valve 521 can be opened to unseal the gap between the valve body 532 and the riser 501 by opening the packing unit 546. This can be accomplished by pumping hydraulic fluid into the lower section of the piston chamber 549 through the port connected to that section of the piston chamber 549, and by allowing hydraulic fluid in the upper section of the.chamber 549 to be vented out through the ports connected to that section of the chamber 549.
  • the apparatus 500, 520 can be unlocked from the riser pipe 501 by operating the securing device 508 (if present, in the case of the apparatus 520) so that the pins 511 are withdrawn from the holes 512 in the pipe wall 513.
  • the pipe 501 can then be withdrawn from the sealing device 502. This is done by moving the sealing device 502 along the pipe 501 until the pipe 501 is no longer received by the sealing device 502.
  • the pipe 501 can be removed from the sealing device 502 by operating the hydraulic cylinders 557 to extend the pistons 556.
  • the sealing device 502 Before withdrawing the pipe 501 from the sealing device 502, the sealing device 502 will usually be operated so that the gap between the sealing device body and the pipe 501 is no longer sealed.
  • the apparatus 520 may also include a support 600 comprising a support frame 601 for supporting the apparatus 520 on the seabed when the riser 501 has a horizontal orientation that necessitates the apparatus 520 to also have a horizontal orientation.
  • the support frame 601 is secured to mounting points 602 on the cross members 565.
  • Support frame 601 includes a plurality of hydraulic cylinders 603 for adjusting the height of the apparatus 520 above the seabed and for lowering the clamping device 558 on to the pipe 501,
  • Figure 12 depicts the sealing device 502 depicted in figure 3 and a first alternative diverter valve 650 which is identical to the diverter valve 522 except that it also includes an automatic fail-safe device/system 651 that is able to operate the diverter valve 650 in the event of the failure of other systems that are operable to control the diverter valve 650.
  • the automatic fail-safe device/system 651 that is able to operate the diverter valve 650 in the event of the failure of other systems that are operable to control the diverter valve 650.
  • the automatic fail-safe device/system 651 that is able to operate the diverter valve 650 in the event of the failure of other systems that are operable to control the diverter valve 650.
  • the automatic fail-safe device/system 651 that is able to operate the diverter valve 650 in the event of the failure of other systems that are operable to control the diverter valve 650.
  • device/system 651 includes a coil spring 652 that extends around the piston 527 and that is located on a lowering side of the piston 527 between the piston 527 and the valve body 523.
  • the coil spring 652 is compressed when the diverter valve 650 is closed. If a problem arises and power or a signal Is lost to the stack, a solenoid-operated valve (not depicted) of the diverter valve 650 will open so that hydraulic pressure on the opposite side of the piston 527 to the spring 652 will be released so as to allow the spring 652 to lower the piston 527 and open the diverter valve 650, Once the diverter valve 650 is opened the diverter valve 650 is able to divert the flow of fluid in the usual manner.
  • the piston 527 is shown moving to an open position in figure 12.
  • Figure 13 depicts the sealing device 502 depicted in figure 3 and a second alternative diverter valve 660 which is identical to the diverter valve 650 except that it includes a coil spring 661 located on a lifting side of the piston 527 between the piston 527 and the valve body 523, The coil spring 661 is
  • Figure 14 depicts the sealing device 502 depicted in figure 3 and a third alternative diverter valve 670 which is identical to the diverter valve 650 except that, in addition to the coil spring 652, it includes a coil spring 661 located on a lifting side of the piston 527 between the piston 527 and the valve body 523. If a problem arises and power or a signal is lost to the stack while the diverter valve 670 is closed, a first solenoid-operated valve (not depicted) of the diverter valve 670 will open so that hydraulic pressure on the opposite side of the piston 527 to the spring 652 will be released so as to allow the spring 652 to lower the piston 527 and open the diverter valve 670.
  • the diverter valve 670 is able to divert the flow of fluid in the usual manner.
  • a second solenoid-operated valve (not depicted) of the diverter valve 670 will open so that hydraulic pressure on the opposite side of the piston 527 to the spring 661 will be released so as to allow the spring 661 to lift the piston 527 and close the diverter alve 670.
  • the piston 527 is shown in a closed position in figure 14. Combining the springs 652, 661 with the necessary hydraulics allows the fail-safe device/system 651 of the diverter valve 670 to function as a double locking system.
  • Apparatus 700 for connecting to a subsea well riser.
  • Apparatus 700 includes a sealing device 502 and a diverter valve 522 which are very similar to the sealing device 502 and diverter valve 522 of the apparatus 520 except that the passages 526 of the diverter valve 522 of the apparatus 700 are downwardly inclined rather than upwardly inclined.
  • the valve body 523 of the diverter valve 522 includes a plurality of inlets 701 that extend to the valve seat 530.
  • the inlets 701 are part of a flushing or cleaning system that is operable to clean the valve seat 530 to ensure that the piston 527 is able to properly seal against the valve seat 530 when the valve 522 is closed.
  • the flushing system functions by injecting a suitable cleaning fluid through the inlets 701 so that the fluid cleans the valve seat 530.
  • Apparatus 700 also includes a securing device 508 in the form of a compression fitting 702 for sealingly securing the sealing device 502 to a pipe such as a well riser pipe that the apparatus 700 is to be connected to.
  • a securing device 508 in the form of a compression fitting 702 for sealingly securing the sealing device 502 to a pipe such as a well riser pipe that the apparatus 700 is to be connected to.
  • Compression fitting 702 comprises a compression ring/collet 703 which is preferably made from a malleable metal such as copper or brass, for example,
  • the compression ringfcollet 703 is configured so that the pipe is able to be inserted through it.
  • the compression fitting 702 includes a
  • each bolt 705 secures the compression sleeve/collet housing 704 to the removable head 544 of the sealing device 502.
  • Each bolt 705 includes a respective torque multiplier 706.
  • the torque multipliers 706 are then operated to tighten the bolts 705.
  • the compression sleeve/collet housing 704 is drawn towards the head 544.
  • the compression ring/collet 703 is sealingly compressed against the pipe,
  • the apparatus 700 includes a plurality of choke and kill lines that are able to communicate with bores 524, 533.
  • Each choke and kill line is able to be used to supply kill mud to a well that the apparatus 700 is connected to, measure the pressure in the well, periodically flush or clean the interior of the apparatus 700, and/or quench gas which may emanate from the well.
  • a respective control valve (not depicted) connected in series with each choke and kill line is operable to open or close the line.
  • Each apparatus 500, 520, and 700 is configurable as a work through apparatus so that drill strings, wirelines, or other equipment are able to be inserted through it and the bore of the conduit (e.g. well riser) to which the apparatus is connected so that work can be carried out through the conduit bore while the apparatus is connected to the conduit.
  • the conduit e.g. well riser

Abstract

La présente invention concerne un appareil (520) permettant le raccordement à une conduite d'hydrocarbures (501) qui comporte un dispositif d'étanchéité (502) comprenant un corps (532) à travers lequel s'étend un passage (533) destiné à recevoir le conduit (501). Un joint d'étanchéité (546) sert à rendre étanche et combler un espace entre le corps (532) et le conduit (501).
PCT/AU2013/001182 2012-10-11 2013-10-11 Raccordement d'une conduite d'hydrocarbures WO2014056045A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
AU2012904452A AU2012904452A0 (en) 2012-10-11 Hydrocarbon Conduit Connection
AU2012904452 2012-10-11
AU2013204745A AU2013204745A1 (en) 2012-10-11 2013-04-12 Hydrocarbon Conduit Connection
AU2013204745 2013-04-12

Publications (1)

Publication Number Publication Date
WO2014056045A1 true WO2014056045A1 (fr) 2014-04-17

Family

ID=50476791

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/AU2013/001182 WO2014056045A1 (fr) 2012-10-11 2013-10-11 Raccordement d'une conduite d'hydrocarbures

Country Status (2)

Country Link
AU (1) AU2013204745A1 (fr)
WO (1) WO2014056045A1 (fr)

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4071085A (en) * 1976-10-29 1978-01-31 Grable Donovan B Well head sealing system
US4597447A (en) * 1983-11-30 1986-07-01 Hydril Company Diverter/bop system and method for a bottom supported offshore drilling rig
US4626135A (en) * 1984-10-22 1986-12-02 Hydril Company Marine riser well control method and apparatus
US5662171A (en) * 1995-08-10 1997-09-02 Varco Shaffer, Inc. Rotating blowout preventer and method
US20100116504A1 (en) * 2008-11-11 2010-05-13 Corey Eugene Hoffman Casing annulus tester for diagnostics and testing of a wellbore

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4071085A (en) * 1976-10-29 1978-01-31 Grable Donovan B Well head sealing system
US4597447A (en) * 1983-11-30 1986-07-01 Hydril Company Diverter/bop system and method for a bottom supported offshore drilling rig
US4626135A (en) * 1984-10-22 1986-12-02 Hydril Company Marine riser well control method and apparatus
US5662171A (en) * 1995-08-10 1997-09-02 Varco Shaffer, Inc. Rotating blowout preventer and method
US20100116504A1 (en) * 2008-11-11 2010-05-13 Corey Eugene Hoffman Casing annulus tester for diagnostics and testing of a wellbore

Also Published As

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