WO2002088516A1 - Systeme et procede de detachement d'une colonne montante de forage sous-marin - Google Patents

Systeme et procede de detachement d'une colonne montante de forage sous-marin Download PDF

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Publication number
WO2002088516A1
WO2002088516A1 PCT/EP2002/004850 EP0204850W WO02088516A1 WO 2002088516 A1 WO2002088516 A1 WO 2002088516A1 EP 0204850 W EP0204850 W EP 0204850W WO 02088516 A1 WO02088516 A1 WO 02088516A1
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WO
WIPO (PCT)
Prior art keywords
subsea
riser
blowout preventor
disconnect
bop
Prior art date
Application number
PCT/EP2002/004850
Other languages
English (en)
Inventor
Peter Eric Azancot
Original Assignee
Shell Internationale Research Maatschappij B.V.
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 Shell Internationale Research Maatschappij B.V. filed Critical Shell Internationale Research Maatschappij B.V.
Priority to GB0323869A priority Critical patent/GB2391889A/en
Publication of WO2002088516A1 publication Critical patent/WO2002088516A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/0355—Control systems, e.g. hydraulic, pneumatic, electric, acoustic, for submerged 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
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • E21B33/061—Ram-type blow-out preventers, e.g. with pivoting rams
    • E21B33/062—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams
    • E21B33/063—Ram-type blow-out preventers, e.g. with pivoting rams with sliding rams for shearing drill pipes
    • 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
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • E21B33/064—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers specially adapted for underwater well heads
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser

Definitions

  • the present invention relates to a method and system for drilling a well into an earth formation below a marine environment .
  • Drilling operations utilize a weighted drilling fluid, known as "mud" which is pumped down the drill string and circulated back to the surface through an annulus between the drill string and the borehole wall.
  • the drilling mud cools the drill bit as it rotates and cuts into the earth formation. It also provides a medium for returning drilling cuttings created by the drill it to the earth's surface via the annulus.
  • the weight of the drilling mud in the annulus further operates to control pressure in the borehole and help prevent blowouts.
  • additives in the mud are designed to form a cake on the inside walls of the borehole to provide borehole stability and to prevent formation fluids from entering the borehole prior to desired production. It will be appreciated that during land operations, the drilling mud and cuttings may be readily returned to the surface via the borehole annulus. Such is not the case in offshore operations.
  • Offshore operations require location of a drilling platform in waters located generally above the reservoir of interest.
  • the depth of the water may range from several hundred feet to well in excess of a mile.
  • a drill string must travel from the surface of the platform, down to equipment located on the seabed and then into the bore of interest prior to actually beginning cutting operations.
  • a drilling "riser" comprised of generally cylindrical elements is provided for from a wellhead located at the seabed to the surface drilling platform above the water level. The riser operates to protect the drilling string during operations and acts as an artificial annulus.
  • the risers are formed from large (on the order of 21 inches) diameter metal tubular goods linked together.
  • Buoyancy elements often manufactured from syntactic foam or metal, may be affixed the external surface of the drilling riser along its length to provide essentially neutral buoyancy.
  • the syntactic foam buoyancy elements are typically 6-12 feet in length.
  • the specific foam chemistry and diameter of the float are selected in accordance with the specific environmental conditions to be encountered in operations.
  • Riser joints may be as long as 75 feet or more in length and multiple buoyancy elements may be affixed to a single riser joint.
  • the buoyancy elements are generally manufactured onshore and shipped, together with the riser joints, to the drilling platform prior to use.
  • the buoyancy elements are usually installed on the riser prior to riser installation.
  • the foam floats may be affixed about the riser elements any number of ways as will be discussed with reference to the preferred embodiments of the invention.
  • BOPs blowout preventors
  • the BOP stack typically consists of multiple BOPs connected to each other and the wellhead and may include shear ram or annular BOPs.
  • the BOP stack is typically just below the rotary table and may be easily monitored and operated in response to a significant well event. Such is not the case, however, in subsea drilling operations.
  • the BOP stack is often located on the seafloor and requires various umbilical and control lines to monitor conditions and operate the BOP stack.
  • the umbilicals and control lines must likewise traverse the distance between the offshore platform and the subsea wellhead.
  • the riser, umbilicals, control lines and other subsea elements, including buoyancy elements, are subjected to ocean currents along their respective lengths, causing lateral deflection in the riser from the seabed to the surface platform.
  • a riser and control lines may be subjected to varying and differential ocean currents along its length resulting in complex lateral deflection of the riser. This results in a number of problems. The continued deflection of the riser may result is stress points along its length and ultimately weaken the riser.
  • the crew is similarly evacuated, leaving the riser system subject to current stresses, as well as wind and wave stresses placed on the floating platform.
  • the riser system is often disconnected from the sea floor BOP stack and tripped, together with the control lines to the platform surface. After the condition abates, the riser system, as well as the umbilicals and control lines must be reconnected to the sea floor BOP stack and a series of time-consuming safety tests run before drilling can resume.
  • Reconnection typically includes running the riser and associated umbilicals down to the seafloor BOP stack. These are typically reconnected utilizing ROVs . This process can take several hours or days followed by days of testing. Accordingly, there exists a need for a more cost-effective means of disconnecting and reconnecting drilling riser systems.
  • a system for drilling a well into an earth formation below a marine environment comprising: an offshore platform positioned above the well; a conduit providing fluid communication between the offshore platform and the well, the conduit comprising a lower portion including a subsea blowout preventor and an upper portion including a second blowout preventor arranged at the platform and a drilling riser disconnectable from said lower portion of the conduit; - a drill string extending from the offshore platform through the conduit into the well; and a subsea disconnect system for selectively disconnecting the drilling riser from said lower portion of the conduit. It is thereby achieved that in case of an emergency situation, for example during adverse weather conditions, the offshore platform can be disconnected from the well and moved away from the well location.
  • the subsea BOP is a minimal BOP as it does not need to have the full functionality of a conventional subsea BOP.
  • the subsea BOP is a ram-type BOP such as a shear ram-type BOP
  • the second BOP at the offshore platform
  • This embodiment is particularly attractive for wells of smaller diameter than conventional wells, as such slender wells require only a small diameter drilling riser which is capable of withstanding relatively high internal pressures.
  • An additional advantage is that such small diameter riser is relatively light so that less stringent load bearing capabilities are imposed on the offshore platform.
  • the system further comprises a subsea control system for monitoring and controlling the subsea blowout preventor, and a surface control system in communication with the subsea control system.
  • the subsea control system is preferably arranged to also control the subsea disconnect- system.
  • the riser system traverses the distance from the seafloor to the offshore platform.
  • the riser system is then connected to the surface BOP stack, which may include both ram and annular BOPs, which are supported by the platform utilizing known tensioning devices.
  • the surface BOP stack may be readily monitored and controlled using a system that is located on the platform, as opposed to a subsurface BOP stack.
  • the integrity of the surface BOP may be readily tested and, if required, repairs may be readily made to the surface BOP stack.
  • the subsea ram BOP it is operated and monitored utilizing a subsea control module located adjacent to the subsea BOP.
  • the module is comprised of a power, processing and communications section.
  • the power section includes stored pressurized air that may be used to pneumatically activate the BOP.
  • the processing system may be comprised of a suitable programmable controller or a microprocessor in an environmentally suitable enclosure. Electrical power to the module is provided by means of batteries and is used to operate the circuitry for the module.
  • a hydraulic system and pump may be used as a power source to operate the subsea BOP.
  • the pressurized air or hydraulic fluid and pump are designed such that they may be regularly serviced or replaced using ROVs.
  • the subsea BOP is in communications with the surface utilizing known acoustic transponder system that may be used to send command information to the subsea BOP or send information on the status of the subsea BOP to the surface system.
  • the operator of the platform decides to disconnect the riser and sends a signal through the water utilizing the acoustic transponder system.
  • the acoustic transponder system may be powered utilizing a battery system of other suitable self-contained means.
  • an acoustic transponder system and the self contained power system effectively eliminates the need for umbilicals for the subsea BOP, reducing cost and time associated with the running of the umbilical lines during an installation or disconnect.
  • an ROV may be landed on the module to activate the necessary controls for the BOP and utilize the stored gas as a power source for operation.
  • the method of disconnecting the present system begins with the tripping of the drill pipe to remove the bit and drill collar and any associated tools or logging equipment from the subsea formation and the riser system.
  • the operator transmits a set of coded commands from the platform through the water utilizing the acoustic transponder system.
  • the acoustic signals are received by the acoustic transponder system located on or near the subsea BOP.
  • the acoustic signal is converted to an electrical signal and transmitted to a control module , where it is interpreted and acted on by the processor or controller located in the module and the appropriate signals are sent to the BOP control system to close the rams, thereby sealing off the hole.
  • the processor or controller monitors the status of the BOP operation and issues a control signal to the surface via the acoustics transponder system that the rams have been activated and the well is sealed off.
  • an ROV may be dispatched to complete operation of the BOP.
  • the operator unlatches one portion of the disconnect system from the other. This may be accomplished from the surface or with ROV intervention.
  • the riser system and the platform are independent of the subsea BOP and may be relocated or tripped
  • the reconnection of the riser system begins with the repositioning, if required, of the offshore platform.
  • the drilling riser remained connected to the platform following disconnect.
  • the drilling riser may be likewise tripped and disassembled following disconnect.
  • the drilling riser is reconnected to the surface BOP stack and extended down to the subsea BOP in sections.
  • the riser connection is made up once again, either entirely from the surface or utilizing ROVs.
  • An ROV it may also be used to check the status of the module with respect to power and communications.
  • the subsea BOP may be tested and upon satisfactory completion of such tests, the rams may be opened.
  • the rams are reopened by issuing a transponder signal from the platform that is received by the subsea BOP acoustic transponder and transferred to the control module.
  • the control module the BOP controls and the air pressure or hydraulic fluid may be used to open the BOP rams .
  • An alternative embodiment of the present invention calls for the place of the connector at some distance below the ocean surface.
  • the riser When the riser is disconnected following sealing of the subsea BOP, the riser length remains connected to the subsea BOP and only a portion is relocated or tripped with the platform.
  • the riser section left subsea may be supported by flotation elements that are placed about the riser sections.
  • the subsea floatation elements may also be used to reduce subsea vortex induced vibration.
  • the end of the riser section may be located by means of acoustic transponder or ROV and reconnected with the riser system extended from the platform.
  • this embodiment does not require umbilicals for the operation of the subsea BOP.
  • Figure 1 is a depiction of a prior art drilling system utilizing a subsea BOP stack
  • Figure 2 is a depiction of a prior art subsea BOP stack
  • Figure 3 is a depiction of a drilling system utilizing a preferred embodiment of the present invention.
  • Figure 4 is a depiction of an alternative embodiment of the present invention.
  • FIG. 1 is a simplified depiction of a prior art offshore platform drilling system.
  • a floating platform 10 is positioned at the desired location and maintains the position by way of mooring lines (not shown) and/or dynamic positioning systems (not shown) .
  • the floating platform is a semi-submersible rig.
  • the simplified drawing depicts a drilling rig 12, which typically includes a number of systems, including rotary table, kelley, pipe handling equipment and other equipment not shown.
  • offshore operations do not have a natural annulus reaching from the wellhead back to the surface. Accordingly, an artificial annulus is created through the use of a drilling riser 18, which extends from the surface down to the wellhead 24 located on the seafloor 22.
  • the riser is typically located below the rotary table and is suspended from the platform 10, utilizing a tensioning system 16.
  • a spider and gimbal system is installed to permit the riser system 18 to flex in response to wind, wave and current conditions acting on not only the riser 18 but the platform as well.
  • the riser 18 is itself comprised of multiple joints connected together at the surface using suitable means, such as flanges and bolts (not shown) .
  • the riser 18 system further might include telescoping joints (not shown) to further permit the riser 18 system to flex in response to environmental conditions.
  • the riser 18 further includes umbilical or control lines 20A and 20B that are typically secured to the riser 18 and made up as the riser is made up and lowered into the ocean.
  • control lines 20A and 20B The function of the control lines 20A and 20B is to provide control signals and power for operation of the subsea BOP stack 26, as will be discussed in further detail below.
  • the riser 18 sections and control lines 20A and 20B are made up until the riser 18 reaches the wellhead 24.
  • the riser 18 is not connected to the wellhead 24 itself but through a subsea blowout preventor (BOP) stack 26 that is sealingly connected to top of the wellhead 24.
  • BOP subsea blowout preventor
  • the wellhead 24 further includes a casing hanger (not shown) for the purposes of suspending casing in the borehole to provide structural support during drilling operations.
  • the topside of subsea BOP stack 26 terminates in a connector 32 that mates with the riser 18 system flex joint connector 34.
  • the control lines 20A and 20B are generally connected via flow lines or manifolds to the subsea BOP power system for operations.
  • the drill string including bit, drill collar and any attendant equipment, such as bent subs, drilling motors, pulsers and Logging While Drilling (LWD) is lowered through the spider and gimbal system 14, through the riser 18 system, through the subsea BOP 25 and into the wellhead 24 to perform drilling operations.
  • Drilling mud is circulated down the interior of the drill string (not shown) and back up the annulus formed by the borehole and the drill string, the subsea BOP stack 26, through the riser 18 and back into the mud pits (not shown) on the platform 10 for analysis and cleaning.
  • Figure 2 is a detailed view of a typical subsea BOP stack 26.
  • the subsea BOP stack 26 is typically made up of multiple BOPs.
  • the subsea BOP stack 26 stack is mated to the wellhead 24 by bolting or other mechanical means and is generally installed prior to the riser system 18 being lowered.
  • the subsea BOP stack 26 depicted in Figure 2 is representative of a guidelineless BOP stack manufactured and sold by the Cameron division of Cooper Industries, Inc. It is comprised of multiple ram-type BOPs 28 that are in series with each other.
  • Fig. 2 depicts four ram BOPs 28 mounted in series in the wellhead 24.
  • the ram BOPs 28 are themselves connected to an annular BOP 30, such that the drill string may be lowered through the annular 30 and ram 28 BOPs.
  • the connector 32 atop the subsea BOP stack 26 is depicted in partial cut-away, with the riser 18 and flex joint 34 in which it terminates.
  • the control lines 20A and 20B may be connected by means of a manifold, or, with ROV assistance, flowlines to one or more control pods 36.
  • the control pods 36 may include programmable controllers or processors to process commands issued by the operator and sent down the control lines 20A and 20B, monitor the BOP stack 26 and the individual BOPs therein 28, 30.
  • the control pods 36 may derive their power through the control lines and/or may further include a separate power, e.g., battery back up. In the illustrated system, the control pods 36, may themselves be replaced or serviced by ROV.
  • the control pods 36 supply electrical, hydraulics, and/or pneumatic power to the individual BOPs 28 by means of control lines 38 within the subsea BOP stack 26.
  • the entire subsea BOP stack 26 is generally supported by a framework 40 that not only lends structural integrity to the system but also operates to protect the components during installation and servicing. The process of disconnecting the riser 18 system from the wellhead 24 begins with the withdrawal of the drill string.
  • Commands are issued by the operator and transferred to the control pods 36 by means of control lines 20A and 20B to close the ram 28 and annular 30 BOPs.
  • the appropriate power is applied to the BOPs through control lines 38 to close off the hole.
  • the riser 18 system is then unlatched by disconnecting the flex joint from the top of the subsea BOP stack 26.
  • the riser 18 system and the control lines 20A and 20B are then relocated or tripped and disassembled.
  • the reconnection of the riser 18 to the subsea BOP stack 26 begins with the repositioning of the riser 18 system or making it up and lowering to the subsea BOP stack 26 from the platform 10.
  • the connectors 34 on the flex joint and 32 atop the subsea BOP stack 26 are mated with the assistance of ROVs.
  • the control lines 20A and 20B must then be connected to the appropriate manifold lines on the BOP stack 26 to come into communication with the control pods 36 and/or control lines 38. While seemingly straightforward, the positioning of the riser 18 system and the reconnection of the control lines 20A and 20B is often performed at depths of thousands of feet. The BOP stack must then be tested for integrity and the ability to properly operate.
  • test procedure must test not only the individual BOPs, but must also test the BOPs in combination with each other. This can be a time consuming process. Only after the entire BOP stack 26 has been tested can mud be circulated back downhole to control pressure, the drill string lowered through the riser 18 system, BOP stack 26 and wellhead 24 and drilling recommenced.
  • the problems associated with locating the BOP stack on the seafloor have been addressed to a degree.
  • the idea of using a surface BOP attached to the wellhead has been addressed by several companies.
  • the article, Surface BOPs Free Modest Semis for Immodest Depths, Offshore Engineer, March 2001, pp. 31-34 discusses the problems related to subsea BOPs and how to address them.
  • a second design discussed at pages 33-34 of the article depicts a suspension system for a surface BOP riser system as used by Shell/Woodside . It is stated that the Shell design decreases bending moments by allowing for lateral movement. The article further addresses the need for a disconnect capability when using a surface BOP. As noted, therein, quite often the general practice is to plug and abandon the well.
  • the preferred embodiment of the present invention addresses the need for disconnect in the event of a metaocean condition while minimizing the time required for the disconnect/reconnect operation.
  • the platform 10 is again shown at the surface, having a surface BOP stack 15 supported by a tensioner system 16.
  • the tensioner system 16 may be of types generally known in the industry as illustrated in the above referenced article.
  • the riser 18 is comprised of multiple riser joints connected together to extend from the platform 10 down toward the wellhead 24. It should be noted, however, the riser 18 system of the present invention does not include control lines as in the prior art.
  • the riser 18 system may include various telescoping or flexure connections and may be supported by buoyancy elements (not shown) together with the tensioner system 16.
  • the riser 18 system terminates at a flexible joint connector 34 and mates with connector 32 mounted atop the subsea BOP stack 26, which is in turn, mounted on the wellhead 24.
  • the subsea BOP stack 26 is a minimal BOP stack comprised of at least one BOP, preferably, a ram-type, as will discussed further below.
  • the subsea BOP stack is supported by a framework that is attached to the ram BOP by means of flange bolted to the framework.
  • the framework itself is attached to a wellhead connector which is designed to sealingly connect with the wellhead to provide an open bore when the rams are open.
  • the BOP stack further includes accumulator tanks which may be used to store pressurized gas to pneumatically operate the BOP through piping.
  • the accumulator tanks are slaved to a battery driven control unit which may include a programmable controller or processor, and is designed to not only operate the BOP, but to monitor the status of the BOP stack through sensors on the accumulator tanks and BOP.
  • the control unit is further adapted to permit an ROV to land on the control unit and perform service tasks, such as control maintenance or battery replacement.
  • the control unit communicates with the platform by means of an acoustic transponder system mounted on the framework.
  • the transponder is powered by and under the direction of the control unit.
  • Coded control signals are issued from a similar transponder on the platform.
  • the code selected is preferably one that allows for easy error correction that may result from extraneous noise introduced into the marine environment from drilling operations, maritime vessels or other sources.
  • the frequency (ies) for the coded control signals is selected to permit efficient transmission of the control signals between the platform 10 and subsea BOP stack.
  • Transponder systems of this type include the Nautica system which has been successfully utilized in a deep sea environment .
  • the operation of the present invention begins with the decision to disconnect the drilling riser 18 from the wellhead 24 in response to metaocean conditions, such as hurricanes, typhoons or emergency situations that may require temporary platform abandonment.
  • the drill string (not shown) is tripped from the formation below the wellhead 24, through wellhead 24, BOP 26, through riser connectors 32 and 34, riser 18 system, and finally through the surface BOP stack 15.
  • An acoustic signal is issued by the platform 10 and received by the acoustic transponder on the subsea BOP stack 26. It will be appreciated that in emergency situations, the rams may be closed with the drill string still engaged, effectively shearing the drill string and closing the hole.
  • the drill string may be recovered from the hole following subsequent reconnection.
  • the acoustic transponder generates an electric signal corresponding to the acoustic signal received and transmits it to the control unit.
  • the control unit receives the signal and decodes the signal into a set of control instructions.
  • the control unit in response to the control instructions, then activates the appropriate relays to activate valves to transfer compressed air from the accumulator tanks to ram BOP 26 pneumatic actuators to close the bore.
  • the control unit could activate a hydraulic pump (not shown) to transfer fluid to the actuators, in this instance hydraulic actuators.
  • the BOP 26 may be instrumented to generate a signal indicating the state of the BOP 26, i.e., fully open, fully closed, or something in between.
  • This signal may be transferred back to the control unit and transmitted to the platform 10 by the acoustic transponder.
  • the operator can receive a confirmation of the actuation of the subsea BOP stack 26 prior to taking any further action.
  • the surface BOP stack 15 is then closed essentially isolating the riser 18.
  • the riser 18 may then be disconnected from the BOP stack 26 with the assistance of an ROV and the riser may be tripped and/or the platform relocated.
  • the process of reconnection is essentially the reverse, beginning with the relocation of the platform 10 to its appropriate position for reconnection.
  • the riser 18 is made up and lowered down to the subsea BOP stack 26.
  • the riser 18 system of the present invention does not utilize control lines. This will reduce the time required to make up riser joint connections and decrease the cost of the joint itself.
  • the riser 18 with flex joint connector 34 is then connected to the subsea BOP stack 26 connector 32 with the aid of an ROV. Following inspection of the connection, the operator begins testing of the surface BOP stack 15. This is typically accomplished by testing the functioning of the BOPs individually and in combination. It will be appreciated that the control of the surface BOP stack 15 is under surface control and the BOPs may be readily monitored and tested. Should repairs need to be made on the BOPs that comprise the surface BOP stack, they may be performed readily, as opposed to in a subsea environment as is done in the prior art.
  • a coded acoustic signal is transmitted from the platform 10 to the subsea BOP stack 26.
  • the acoustic signal is received by the acoustic transponder and a corresponding electrical signal transferred to the control unit.
  • the control unit decodes the signal activates the appropriate valves to provide pressurized gas or hydraulic fluid to the actuators located on the BOP 26.
  • the BOP 26 instrumentation generates a signal to indicate the status of the BOP 26.
  • the signal is received by the control unit and transferred back to the platform 10 by means of the acoustic transponder. The operator may then resume drilling operations.
  • An alternative embodiment of the present invention calls for the disconnect of the riser at some point below the surface but well above the seafloor.
  • the platform 10 is shown as similar to that depicted in Fig. 3.
  • the riser 18A terminates in a flex joint connector 64.
  • the flex joint connector mates with connector 66, which is itself connected to a second riser string 18B that extends from connector 66 to the subsea BOP stack 26.
  • the second riser string terminates in a flex connector 34 that mates with a connector 32 located on top of the subsea BOP stack 26.
  • the remainder of the embodiment is similar to that set forth in Figure 3.
  • a sufficient number of flotation buoys are affixed about riser 18B string to impart enough buoyancy to riser 18B to permit it to maintain a given depth below the ocean surface.
  • the method of disconnect is the very same as that discussed with reference to Fig. 3 with the exception that the disconnect takes place not near the seafloor 22. It will be appreciated that the time required to trip the riser 18A joints will be reduced, thereby reducing associated costs. Likewise the time and costs associated with making up riser 18A and lowering it to connect with riser 18B will be reduced.
  • the riser 18B and connector 64 may be readily located utilizing acoustic transponders and ROVs may be used to reconnect connectors 34 and 64. This second embodiment may be utilized in response to specific ocean conditions, e.g., in areas susceptible to ice floes or icebergs.

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

Abstract

L'invention porte sur un système de forage d'un puits sous-marin, comprenant une plate-forme en mer placée au-dessus du puits, ainsi qu'un conduit assurant une communication fluidique entre la plate-forme en mer et le puits. Le conduit comprend une partie inférieure présentant un système d'éruption libre sous-marin (26) et une partie supérieure comportant un second système d'éruption libre sous-marin (15) se trouvant au niveau de la plate-forme (10), et une colonne montante pouvant être détachée de la partie inférieure du conduit. Un train de tiges de forage s'étend de la plate-forme en mer (10) via le conduit dans le puits. Un système de détachement sous-marin permet de déconnecter sélectivement la colonne montante (18) de ladite partie inférieure du conduit.
PCT/EP2002/004850 2001-04-30 2002-04-26 Systeme et procede de detachement d'une colonne montante de forage sous-marin WO2002088516A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
GB0323869A GB2391889A (en) 2001-04-30 2002-04-26 Subsea drilling riser disconnect system and method

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US28735801P 2001-04-30 2001-04-30
US60/287,358 2001-04-30

Publications (1)

Publication Number Publication Date
WO2002088516A1 true WO2002088516A1 (fr) 2002-11-07

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PCT/EP2002/004850 WO2002088516A1 (fr) 2001-04-30 2002-04-26 Systeme et procede de detachement d'une colonne montante de forage sous-marin

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Publication number Priority date Publication date Assignee Title
WO2006010906A1 (fr) * 2004-07-24 2006-02-02 Bamford Anthony S Ameliorations du forage en mer
SG134999A1 (en) * 2002-11-26 2007-09-28 Cooper Cameron Corp Subsea connection apparatus for a surface blowout preventer stack
US8590634B2 (en) 2004-07-24 2013-11-26 Geoprober Drilling Limited Subsea drilling
WO2013126114A3 (fr) * 2012-02-23 2014-02-27 Cameron International Corporation Système d'interrogation à fréquences acoustiques et de données
WO2013135694A3 (fr) * 2012-03-12 2014-07-03 Managed Pressure Operations Pte. Ltd. Procédé et appareil de forage d'un puits de forage souterrain
US8789605B2 (en) 2008-04-30 2014-07-29 Parker-Hannifin Corporation Riser clamp
GB2515419A (en) * 2012-03-12 2014-12-24 Managed Pressure Operations Method of and apparatus for drilling a subterranean wellbore
EP2863005B1 (fr) 2009-02-09 2015-12-23 FMC Kongsberg Subsea AS Joint de déclenchement
WO2016182449A1 (fr) * 2015-05-08 2016-11-17 Optime Subsea Services As Système de commande à distance d'équipement de fond de trou
WO2016192729A1 (fr) * 2015-05-29 2016-12-08 Maersk Drilling A/S Procédé de forage arctique
US9605502B2 (en) 2012-04-11 2017-03-28 Managed Pressure Operations Pte Ltd Method of handling a gas influx in a riser
US10309191B2 (en) 2012-03-12 2019-06-04 Managed Pressure Operations Pte. Ltd. Method of and apparatus for drilling a subterranean wellbore
CN111188597A (zh) * 2019-12-31 2020-05-22 中国海洋石油集团有限公司 一种软悬挂状态下的隔水管安全监测系统及方法

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US4682913A (en) * 1986-08-28 1987-07-28 Shell Offshore Inc. Hydraulic stab connector
EP0709545A2 (fr) * 1994-10-31 1996-05-01 Mercur Subsea Products As Système de forage à trou mince dans des eaux profondes
US6109352A (en) * 1995-09-23 2000-08-29 Expro North Sea Limited Simplified Xmas tree using sub-sea test tree
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WO1998058152A1 (fr) * 1997-06-17 1998-12-23 Sofitech N.V. Procede et appareil de forage de puits sous-marins

Cited By (26)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
SG134999A1 (en) * 2002-11-26 2007-09-28 Cooper Cameron Corp Subsea connection apparatus for a surface blowout preventer stack
US7779917B2 (en) 2002-11-26 2010-08-24 Cameron International Corporation Subsea connection apparatus for a surface blowout preventer stack
US8136598B2 (en) 2002-11-26 2012-03-20 Cameron International Corporation Subsea connection apparatus for a surface blowout preventer stack
US8695691B2 (en) 2002-11-26 2014-04-15 Cameron International Corporation Subsea connection apparatus for a surface blowout preventer stack
US9085951B2 (en) 2002-11-26 2015-07-21 Cameron International Corporation Subsea connection apparatus for a surface blowout preventer stack
US7819204B2 (en) 2004-07-24 2010-10-26 Geoprober Drilling Limited Subsea drilling
US8590634B2 (en) 2004-07-24 2013-11-26 Geoprober Drilling Limited Subsea drilling
WO2006010906A1 (fr) * 2004-07-24 2006-02-02 Bamford Anthony S Ameliorations du forage en mer
US8950501B2 (en) 2008-04-30 2015-02-10 Parker-Hannifin Corporation Riser clamp
US8789605B2 (en) 2008-04-30 2014-07-29 Parker-Hannifin Corporation Riser clamp
US9212525B2 (en) 2008-04-30 2015-12-15 Parker-Hannifin Corporation Riser clamp
EP2863005B1 (fr) 2009-02-09 2015-12-23 FMC Kongsberg Subsea AS Joint de déclenchement
WO2013126114A3 (fr) * 2012-02-23 2014-02-27 Cameron International Corporation Système d'interrogation à fréquences acoustiques et de données
US9397759B2 (en) 2012-02-23 2016-07-19 Cameron International Corporation Acoustic frequency interrogation and data system
GB2515673A (en) * 2012-02-23 2014-12-31 Cameron Int Corp Acoustic frequency interrogation and data system
GB2515673B (en) * 2012-02-23 2019-05-29 Cameron Tech Ltd Acoustic frequency interrogation and data system
GB2515419B (en) * 2012-03-12 2019-07-31 Managed Pressure Operations Method of and apparatus for drilling a subterranean wellbore
WO2013135694A3 (fr) * 2012-03-12 2014-07-03 Managed Pressure Operations Pte. Ltd. Procédé et appareil de forage d'un puits de forage souterrain
US10309191B2 (en) 2012-03-12 2019-06-04 Managed Pressure Operations Pte. Ltd. Method of and apparatus for drilling a subterranean wellbore
GB2515419A (en) * 2012-03-12 2014-12-24 Managed Pressure Operations Method of and apparatus for drilling a subterranean wellbore
US9605502B2 (en) 2012-04-11 2017-03-28 Managed Pressure Operations Pte Ltd Method of handling a gas influx in a riser
WO2016182449A1 (fr) * 2015-05-08 2016-11-17 Optime Subsea Services As Système de commande à distance d'équipement de fond de trou
US10890043B2 (en) 2015-05-08 2021-01-12 Fmc Kongsberg Subsea As System for remote operation of downhole well equipment
WO2016192729A1 (fr) * 2015-05-29 2016-12-08 Maersk Drilling A/S Procédé de forage arctique
US10415315B2 (en) 2015-05-29 2019-09-17 Maersk Drilling A/S. Arctic drilling process
CN111188597A (zh) * 2019-12-31 2020-05-22 中国海洋石油集团有限公司 一种软悬挂状态下的隔水管安全监测系统及方法

Also Published As

Publication number Publication date
GB0323869D0 (en) 2003-11-12
MY141181A (en) 2010-03-31
GB2391889A (en) 2004-02-18

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