WO2021094717A1 - Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin - Google Patents

Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin Download PDF

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Publication number
WO2021094717A1
WO2021094717A1 PCT/GB2020/052823 GB2020052823W WO2021094717A1 WO 2021094717 A1 WO2021094717 A1 WO 2021094717A1 GB 2020052823 W GB2020052823 W GB 2020052823W WO 2021094717 A1 WO2021094717 A1 WO 2021094717A1
Authority
WO
WIPO (PCT)
Prior art keywords
rcd
seals
housing
throughbore
control device
Prior art date
Application number
PCT/GB2020/052823
Other languages
English (en)
Inventor
Kevin Wilson
Richard Johnston
Garry Robert STEPHEN
Original Assignee
Oil States Industries (Uk) Limited
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Oil States Industries (Uk) Limited filed Critical Oil States Industries (Uk) Limited
Priority to BR112022009096A priority Critical patent/BR112022009096A2/pt
Priority to EP20804652.4A priority patent/EP4058654A1/fr
Priority to US17/769,997 priority patent/US20220381105A1/en
Publication of WO2021094717A1 publication Critical patent/WO2021094717A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
    • 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
    • E21B33/08—Wipers; Oil savers
    • E21B33/085—Rotatable packing means, e.g. rotating blow-out preventers

Definitions

  • the present invention relates to an apparatus and method relating to subsea managed pressure drilling and in particular relates to a subsea managed pressure drilling (MPD) rotating control device (RCD) system incorporating at least one annular seal.
  • MPD subsea managed pressure drilling
  • RCD rotating control device
  • MPD Managed Pressure Drilling
  • the drill string is run through a riser.
  • the pressure of the returning drilling fluid is controlled within the annulus between the outside of the drill string and the inner bore of the riser.
  • the volume of drilling mud is significant due to the requirement for a larger riser. This leads to the need for a larger drill rig to support the riser.
  • the weight of the large column of mud produces high hydrostatic pressures, which result in the need for numerous casing points in areas of the formation where high pore pressures and low fracture gradients exist. Numerous casing points require a large subsea wellhead.
  • a main feature of an MPD system is a Rotating Control Device (RCD).
  • RCD Rotating Control Device
  • An RCD permits passage of the drill string through the riser and creates a seal between them, while permitting rotation of the drill string.
  • the RCD therefore prevents pressurised drilling fluid from escaping to the environment.
  • a traditional RCD system is housed within the riser and therefore a traditional RCD system still requires the riser.
  • Deep water MPD systems typically include an integration joint which typically consists of three or more components all connected in line in the riser system. These three components typically comprise an annular seal within a separate tubular and an RCD located above the annular seal within its own separate tubular, where the integration joint is located in line/in series within the riser string above an MPD flow spool and below a telescopic joint.
  • the RCD, the annular seal and the MPD flow spool along with the other components in the riser system all act together to enable closed loop drilling in deep water environments.
  • the RCD typically comprises an upper and a lower cup shaped rubber seal which is rotatable with respect to the integration joint and which can therefore rotate with the drill string as it is rotated from surface, where the pair of rotatable RCD rubber seals permit passage of the drill string through the riser but also seal around the drill string whilst permitting rotation of it thereby preventing pressurised drilling fluid from passing further up the annulus in the riser string. Accordingly, the RCD forces the returning drilling fluid to flow out of the annulus in the riser string and through goose necks provided at each side of the MPD flow spool where the goose necks are attached to drilling fluid return hoses.
  • a subsea rotating control device (RCD) system adapted to permit a tubular work string to pass there through such that there is an annulus created between the inner throughbore of subsea rotating control device (RCD) system and the outer surface of the tubular work string
  • the subsea rotating control device (RCD) system comprising a system housing comprising a throughbore; an upper end; and a lower end adapted for connection with a BOP of a wellhead; and the subsea RCD system further comprising:- at least two RCD seals arranged for selective mounting within the system housing and which are selectively actuable between an unsealed configuration in which the at least two RCD seals are radially outwardly retracted and a sealed configuration in which the at least two RCD seals are radially inwardly extended; and at least one annular seal arranged for selective mounting within the system housing below the at least two RCD seals, where
  • the at least two RCD seals are inflatable such that they can be inflated into the sealed configuration and deflated into the unsealed configuration.
  • the at least one annular seal is inflatable such that it can be inflated into the sealed configuration and deflated into the unsealed configuration.
  • the system housing comprises a wellbore fluid and/or drilling mud returns port which is preferably formed through a sidewall of the system housing. More preferably, a wellbore fluid and/or drilling mud returns hose may be connected to the said port.
  • the port permits wellbore fluid and/or drilling mud located in the throughbore of the subsea rotating control device (RCD) system to exit the throughbore and return to the surface and more preferably permits wellbore fluid and/or drilling mud located in the throughbore of the subsea rotating control device (RCD) system below the lowermost (or most upstream) of the at least two RCD seals and/or the at least one annular seal to exit the throughbore and return to the surface.
  • RCD subsea rotating control device
  • the port is located below (or upstream of) the lowermost (or most upstream) of the at least two RCD seals and/or the at least one annular seal.
  • the port permits wellbore fluid and/or drilling mud located in the throughbore of the subsea rotating control device (RCD) system and/or the BOP and wellhead below (or upstream of) the lowermost of the at least two RCD seals and/or the at least one annular seal to exit the throughbore and return to the surface via the returns hose whilst the two RCD seals and/or the at least one annular seal seal against the outer surface of the workstring at a location above (or downstream) of the port and as such prevent the wellbore fluid and/or drilling mud from escaping to the outer environment.
  • RCD rotating control device
  • Embodiments of the present invention have the advantage that, with the two RCD seals and/or the at least one annular seal sealing the annulus between the throughbore of the system housing and the outer surface of a work string (which is typically a drill string) and the wellbore fluid and/or drilling mud being returned to the surface via a separate hose, riserless but yet managed pressure drilling (without loss of any wellbore fluid and/or drilling mud to the outer subsea environment) can be achieved.
  • a work string which is typically a drill string
  • the at least two RCD seals are capable of being locked within the throughbore by at least one locking device.
  • the at least one annular seal is capable of being locked within the throughbore by at least one locking device.
  • each of the at least two RCD seals and the at least one annular seal comprise their own respective locking device.
  • each of the at least two RCD seals and the at least one annular seal can be separately and selectively locked and unlocked as required by actuation of their own respective locking device in such a manner to permit one of them to be locked within the throughbore and the other of them to be run into and/or retrieved from the throughbore of the system housing.
  • the subsea RCD system is for use in managed pressure drilling operations and typically the tubular work string is a drill string.
  • the at least two RCD seals and the at least one annular seal are adapted to be located within the throughbore of the system housing.
  • the at least two RCD seals and the at least one annular seal are adapted in use to provide a seal within the said annulus.
  • each of the said at least two RCD seals are provided within an RCD housing and more preferably, the said at least one annular seal is provided within a separate housing from that of the at least two RCD seals.
  • the at least two RCD seals are rotateably mounted within said RCD housing by at least one bearing mechanism.
  • each of the said at least two RCD seals and the at least one annular seal is in the form of a cartridge assembly and preferably, each of the said at least two RCD seals and the at least one annular seal comprises a retrieval means to permit running in and/or retrieval of the respective each of the said at least two RCD seals and the said at least one annular seal.
  • each said seal housing comprises a locking means into which a respective locking device can engage in order to lock said seal housing of said respective seal within the throughbore of the system housing.
  • Said locking means may comprise a slot, groove or recess into which a locking device such as a locking dog may be inserted.
  • each said locking device is mounted on the system housing.
  • each said locking device comprises one or more radially moveable dog members which can be moved radially inwardly to projecting inwardly from the inner diameter of the system housing and more preferably can be moved radially inwardly to projecting inwardly from the inner diameter of the system housing into the said locking means of the respective seal housing.
  • each said locking device can be actuated between a radially inwardly projecting configuration and a retracted configuration such that they do not project into said locking means of the respective seal housing.
  • each said locking device is remotely actuatable (such as from the surface by an operator) between the radially inwardly projecting or locked configuration and the retracted or unlocked configuration, allowing for remote activation of each of the locking devices by the operator.
  • the said at least two RCD seals and the at least one said annular seal are adapted to be located co-axially within the throughbore of the system housing and more preferably the longitudinal length of the system housing is longer than the combined longitudinal length of the said at least two RCD seals and the said at least one annular seal more preferably the inner diameter of the system housing is greater than the outer diameter of each of the said at least two RCD seals such that the said at least two RCD seals are adapted to be wholly located co-axially within the system housing and most preferably the said at least two RCD seals are adapted to be wholly located co-axially within the throughbore of the system housing.
  • the system housing is adapted to be able to house both of a pair of rotation control device (RCD) seals and at least one annular seal within its throughbore, preferably in series/in line along its longitudinal length.
  • RCD rotation control device
  • At least one of the two RCD seals and the said annular seal device can be> i) run into the throughbore of the system housing, typically through an upper end of the system housing; and ii) locked to the system housing within the throughbore of the system housing.
  • At least one of the said two RCD seals and the said annular seal are capable of being unlocked from and more preferably retrieved from the throughbore of the system housing, typically by pulling it upwards through the throughbore of the system housing and further pulling it upwards through the upper end of the system housing into the surrounding subsea environment on a workstring.
  • the at least two RCD seals are arranged to be located above the annular seal device within the throughbore of the system housing.
  • the at least two RCD seals may be retrieved and run into the throughbore on its own by a running/retrieval tool or alternatively, may be retrieved and run into the throughbore with at least one annular seal.
  • One or both of the at least two RCD seals and the at least one annular seal may be located within the throughbore of and locked to the system housing when the system housing is first installed on the BOP; or one or both of the at least two RCD seals and the at least one annular seal may be retrieved from and/or run into the throughbore of the system housing through the throughbore of an upper end of the system housing and be locked to the system housing within the throughbore of the system housing after the system housing has been installed on the BOP.
  • suitable seals such as (but not limited to) O-ring seals, pressure activated seals or mechanically activated seals are provided to act between the outer surface of the at least two ROD seals and the inner throughbore of the system housing.
  • seals are provided on and/or around the outer circumferential surface of the at least two ROD seals such that they act to seal the gap between the outer surface of the at least two ROD seals and the inner throughbore of the system housing.
  • seals such as (but not limited to) O-ring, pressure activated seals or mechanically activated seals are typically provided to act between the outer surface of the said at least one annular seal and the inner throughbore of the system housing.
  • seals are provided on and/or around the outer circumferential surface of the said at least one annular seal such that they act to seal the gap between the outer surface of the said at least one annular seal and the inner throughbore of the system housing.
  • the system housing comprises a seat or other formation formed on its inner throughbore preferably at a location on its inner diameter and which prevents the at least one annular seal from moving any lower through the system housing than said seat.
  • the said seat is a formation formed on the inner diameter of the system housing and more preferably said formation comprises a narrower inner diameter load bearing shoulder than the outer diameter of at least a portion of the at least one annular seal such that the said portion seats upon said shoulder and thus any further downward movement of the at least one annular seal is arrested.
  • the said formation comprises a narrower inner diameter load bearing shoulder than the outer diameter of at least a portion of the at least one annular seal.
  • said seat or other formation comprises one or more radially moveable dog members which can be moved radially inwardly to provide a shoulder projecting inwardly from the inner diameter of the system housing for the said annular seal to seat upon in order to prevent the annular seal from moving any lower through the system housing than said shoulder or seat.
  • the at least two RCD seals comprise an outer RCD housing and two RCD seals which are rotatable with respect to the outer RCD housing.
  • the two RCD seals further comprise one or more bearings to couple them to the RCD housing such that the two RCD seals are rotatable on the bearing with respect to the stationary outer RCD housing such that the said each respective RCD seal seals against and is rotatable with the work string (which is typically a drill string) which passes through the throughbore of the system housing.
  • the at least two RCD seals are longitudinally spaced apart rotatable seals and further comprise an in use upper most RCD seal and a lowermost RCD seal.
  • each of the upper and lower RCD seals is formed from a resilient material such as rubber and/or polyurethane and which is inflatable such that when in an inflated state has an inner diameter which is a friction fit or comprises an inner diameter that matches the outer diameter of the drill string such that each of the upper and lower RCD seals are forded against the outer surface of the drill string and seals against the outer surface of the drill string such that it does not permit drilling fluid or other well fluids located in the annulus to pass through the throughbore of the two RCD seals in the upwards direction from downhole to up-hole when in the inflated state.
  • the said two RCD seals comprise an in use de energised or deflated inner diameter which is greater than the outer diameter of the drill string which passes there through such that when the said two RCD seals in use are de-energised, they allow the free movement of the drill string there through and therefore do not impede the movement there through and therefore do not seal against the outer diameter of the drill string.
  • each of the said two RCD seals can be selectively energised or de energised by the respective introduction or removal of fluid from a respective cavity or chamber in fluid communication with a surface of the said two RCD seals and more preferably said respective cavity or chamber is in fluid communication with an outer surface of each of the said two RCD seals such that when fluid is pumped into said respective cavity or chamber, the said two RCD seals are forced inwards into contact with the tubular work string passing through the system housing to thereby form a seal in the annulus between the outer surface of the tubular work string and the inner throughbore of the system housing.
  • the said annular seal comprises an in use de-energised or deflated inner diameter which is greater than the outer diameter of the drill string which passes there through such that when the said annular seal in use is de-energised it allows the free movement of the drill string there through and therefore does not impede the movement there through and therefore does not seal against the outer diameter of the drill string.
  • the said annular seal typically comprises an in use energised or inflated inner diameter which matches the outer diameter of the drill string which passes there through such that when the said annular seal in use is energised it seals against the outer diameter of the drill string and therefore does not permit drilling fluid located in the annulus to pass through the throughbore of the annular seal in the upwards direction from downhole to up-hole when in the inflated state.
  • the annular seal can be selectively energised or de-energised by the respective introduction or removal of fluid from a cavity or chamber in fluid communication with a surface of the said annular seal and more preferably said cavity or chamber is in fluid communication with an outer surface of the said annular seal such that when fluid is pumped into said cavity or chamber, the said annular seal is forced inwards into contact with tubular work string passing through the system housing to thereby form a seal in the annulus between the outer surface of the tubular work string and the inner throughbore of the system housing.
  • the subsea RCD system further comprises a hydraulic fluid control system capable of controlling the pressure of fluid within the respective chamber and in particular within the two RCD seal chambers. More preferably, the hydraulic fluid control system is capable of controlling the pressure of fluid within the two RCD seal chambers such that said pressure is maintained at a positive delta pressure compared with the pressure of the wellbore fluids and/or drilling mud within the throughbore of the system housing.
  • the hydraulic fluid control system comprises a pressure sensing mechanism to sense the pressure within the throughbore of the system housing and further comprises a hydraulic fluid source which is typically a hydraulic fluid accumulator capable of providing pressurised hydraulic fluid. More preferably, said hydraulic fluid control system comprises a fluid pressure signal transmission system which is preferably a wireless fluid pressure signal transmission system and most preferably is a BluetoothTM wireless fluid pressure signal transmission system.
  • the locking devices are configured such that in use, in the locked configuration, the respective two RCD seals and the said annular seal cannot move relative to the system housing and in the unlocked configuration the respective two RCD seals and the said annular seal can move relative to the system housing.
  • This provides for a locking system wherein when the respective locking device is moved from the unlocked configuration to the locked configuration the respective two RCD seals and the said annular seal can move relative to the system housing.
  • the subsea RCD system is connected to the BOP via a suitable connection device and more preferably said suitable connection device comprises a flexible joint to permit flexible deviation of the subsea RCD system off the longitudinal axis of the BOP.
  • said flexible joint comprises a Flex JointTM offered by Oil States Industries of Heartlands, Scotland and is further preferably coupled to a LynxGripTM HARTM connector offered by Oil States Industries of Heartlands, Scotland.
  • the embodiments of the present invention have many advantages including great flexibility due to the modular nature of the two RCD seals and the said annular seal.
  • Embodiments of the present invention have the great advantage that a riser string does not need to be used unlike conventional RCD systems and therefore much smaller drilling rigs and platforms could be used than has hitherto been possible.
  • wellbore refers to a wellbore or borehole being provided or drilled in a manner known to those skilled in the art.
  • the wellbore may be ‘open hole’ or ‘cased’, being lined with a tubular string.
  • work string refers to any tubular arrangement for conveying fluids and/or tools from a surface into a wellbore.
  • drill string is the preferred work string.
  • compositions, an element or a group of elements are preceded with the transitional phrase "comprising”, it is understood that we also contemplate the same composition, element or group of elements with transitional phrases “consisting essentially of”, “consisting”, “selected from the group of consisting of”, “including” or “is” preceding the recitation of the composition, element or group of elements and vice versa.
  • the words “typically” or “optionally” are to be understood as being intended to indicate optional or non-essential features of the invention which are present in certain examples but which can be omitted in others without departing from the scope of the invention.
  • Fig. 1 is a cross sectional side view of a first embodiment of a subsea rotating control device (RCD) system showing in its in use configuration for connection to the upper end of a BOP (albeit the drill string which would in use pass through the throughbore of the subsea RCD system is not shown);
  • RCD rotating control device
  • Fig. 1A is a more detailed close up cross sectional side view showing section A of Fig. 1, showing the pressure energised seals employed to seal the outer surface of the RCD outer housing to the inner surface of the system outer housing;
  • Fig. 1 B is a more detailed close up cross sectional side view showing section B of Fig. 1 in more detail and which shows a series of staged dynamic seals which are employed to seal the lower end of the inner rotatable part of the RCD to the lower end of the stationary part of the RCD;
  • Fig. 1C is a cross sectional side view in more detail of section C of Fig. 1 and which shows an anti-rotation key which is mounted on an outer surface of a lower static annular packer seal housing in order to selectively rotationally lock the lower static annular packer seal housing to the inner bore of the system outer housing;
  • Fig. 1D is a cross sectional view of section D of Fig. 1 in more detail and which shows the inner bore 312U of the upper inflatable RCD packer 304 as being provided with a polyurethane (PU) sleeve 314U thereon in order to increase the lifespan of the upper inflatable RCD packer 304;
  • PU polyurethane
  • Fig. 1E is a cross sectional side view of the first embodiment of a rotating control device (RCD) of Fig. 1 positioned above a cross sectional side view of a lower static annular packer of Fig. 1, where both the RCD and the lower static annular packer are ready to be attached to a running in tool and thus be run into the system outer housing of Fig. 1 in order to form the first embodiment of a subsea RCD system of Fig. 1;
  • RCD rotating control device
  • Fig. 2 is a cross sectional side view of a second embodiment of a subsea RCD system for connection to the upper end of a BOP, where a drill pipe would normally be running through the throughbore of the subsea RCD system (but the drill pipe string is not shown in Fig. 2); and Fig. 2 A is a cross sectional side view of the second embodiment of a rotating control device (RCD) as shown in the subsea RCD system of Fig. 2 and is shown as positioned above a second embodiment of a lower static annual packer as also shown in the subsea RCD system of Fig. 2, where both will be picked up by a retrieval tool mounted on a drill string and both will then be run into the throughbore of the system outer housing 10 in order to form the second embodiment of a subsea RCD system of Fig. 2.
  • RCD rotating control device
  • Fig. 1 shows a first embodiment of a subsea RCD system 1 and which comprises two main parts.
  • the first main part is a system outer housing 10 (and which is also common to the second embodiment of a subsea RCD system 2 as will be described subsequently).
  • the second part is a first embodiment of an RCD 300 and a lower static annular packer 190, where the RCD 300 and/or lower static annular packer 190 can be run into and/or retrieved from the inner throughbore of the system outer housing 10 by being latched onto by a retrieval tool (not shown) mounted within a drill string (not shown) or other suitable work string (not shown).
  • Fig. 1E shows the RCD 300 and lower static annular packer 190 as having been separated from the system outer housing 10 and therefore the RCD 300 and lower static annular packer 190 can be seen in greater clarity in Fig. 1E.
  • connection joint 14 will provide some ability to flex the sealed connection or coupling between itself 14 and the lower end 10L of the system outer housing 10 in order to accommodate a drill string that is off longitudinal axis and a much preferred connection joint 14 is a Flex Joint offered by Oil States Industries of Heartlands, Scotland, but other suitable joints could also be used instead.
  • connection joint 14 is coupled to the upper end 16U of a further suitable connector 16 and a preferred suitable connector 16 is a LynxGripTM HARTM offered by Oil States Industries of Heartlands, Scotland, but other suitable connectors could also be used instead.
  • a LynxGripTM HARTM offered by Oil States Industries of Heartlands, Scotland, but other suitable connectors could also be used instead.
  • BOP blowout preventer
  • a work string such as a drill string (not shown) is run into the wellbore through the throughbore 11 of the subsea RCD system 1 in order to drill the wellbore and it is the function of the subsea RCD system 1 to seal against the outer surface of the drill string in order to control the wellbore fluid and/or drilling mud returning from the wellbore and which is located in the annulus between the outer surface of the drill string and the inner surface 12 of the throughbore 11 of the subsea RCD system 1.
  • the system outer housing 10 is, in the embodiment shown in Figs. 1 and 2 provided with a drilling mud returns outlet port 20 formed through its sidewall 15 at a location at or toward its lower end 10L (and importantly at a location below or upstream of the location at which the lower static annular packer 190 (which will be described subsequently) can seal against the outer surface of the drill string in order to seal the annulus) such that drilling mud returning back up from the wellbore up the annulus between the inner bore 12 of the lower end 10L of the system outer housing 10 and the outer surface of the drill string will be prevented from passing up past the lower static annular packer 190 and/or the rotating control device RCD 300 as will be subsequently described.
  • the subsea RCD system 1 can provide for riserless Managed Pressure Drilling (MPD) which provides an operator with great advantages, as will be subsequently described.
  • MPD Managed Pressure Drilling
  • the specific location of the drilling mud returns outlet port 20 could in one or more alternative embodiment(s) be moved further lower such that for example it or they were located in the sidewall of the connection joint 14 and such embodiments would have the advantage that the said drilling mud returns hose(s) (that connect(s) to the drilling mud returns outlet port(s) 20) would be static with respect to the connection joint 14 and thus wouldn’t experience flex even if the lower end 10L of the system outer housing 10 flexed (with respect to the connection joint 14) when accommodating a drill string that is off longitudinal axis.
  • the skilled person will understand that although Figs.
  • drilling mud returns outlet port 20 only show one drilling mud returns outlet port 20, more than one drilling mud returns outlet port 20 may be provided in and around the sidewall of the lower end 10L or connection joint 14 as appropriate in order to accommodate two or more drilling mud returns hose(s).
  • the diameter of the throughbore of the drilling mud returns outlet port(s) 20 can be varied depending upon the volume of drilling mud returns to be accommodated therein and which will flow there through.
  • the system outer housing 10 comprises a throughbore 11 having an inner throughbore surface 12 and outer diameter surface 13 and a sidewall 15 such that the system outer housing 10 is generally tubular along its longitudinal length.
  • the sidewall 15 is generally sealed along its length (with the exception of the drilling mud returns outlet port 20 and some other hydraulic fluid inlets which will be subsequently described). Accordingly, pressurised fluids such as wellbore or reservoir fluids, drilling mud and drill cuttings located within the throughbore 11 and thus the rest of the joints 14, 16 and the BOP 18 are safely contained by and within the sidewall 15 of the system outer housing 10.
  • the system outer housing 10 further comprises a guide funnel 19 at its uppermost end and which comprises an outwardly tapering profile for ensuring guiding of the ROD 300 and lower static annular packer 190 into the system outer housing 10 when being run into the system outer housing 10, as will be described subsequently.
  • the RCD 300 is shown in more detail in Fig. 1E and comprises two main parts, the first main part being a generally outer stationary part 342 which mainly comprises an RCD outer housing 308 which is generally cylindrical in nature.
  • the second main part of the RCD 300 is the generally inner rotatable part 340 of the RCD 300, albeit a significant portion being the upper portion 340U of the rotatable part 340 projects upwardly and outwardly from the stationary part 342 or the RCD outer housing 308.
  • the generally inner rotatable part 340 comprises an RCD inner housing 306 having an end cap 307 secured to its lower most end, where the end cap 307 comprises an axially extending spigot 307S and which in turn is provided with one or more (three are shown) staged dynamic seals 336 longitudinally spaced apart on the outer surface of the spigot 307S and which seal against the inner surface of the throughbore of the lower end 308L of the RCD outer housing 308.
  • the staged dynamic seals 336 will act to prevent any fluid from passing up between the outside surface of the spigot 307S and the inner throughbore of the lower end 308L and also permit rotation to occur between the RCD inner housing 306 and the RCD outer housing 308.
  • a plurality of bearings 332 are provided on the outer surface of the RCD inner housing 306 and in Fig. 1E it can be seen that there are two main sets of bearings 332, an upper most set 332U and a lower more set 332L and which in use will permit or allow the inner rotatable part 340 of the RCD 300 to rotate (whilst experiencing only minimal friction) with respect to the stationary part 342 of the RCD 300 and therefore the inner rotatable part 340 will be able to rotate with the drill string which passes through and is contained within the throughbore 11 of the subsea RCD system 1 when the pair of inflatable packers 304, 302 are inflated to seal against the outer surface of the drill string as will now be described.
  • the inner rotatable part 340 and in particular the RCD inner housing 306 comprises two recesses 301 U and 301 L provided on its inner throughbore surface 305.
  • An upper inflatable RCD packer 304 is located in the upper recess 301 U and accordingly the upper inflatable RCD packer 304 is trapped within the upper recess 301 U and therefore cannot move longitudinally with respect thereto.
  • the upper inflatable RCD packer 304 can be forced to move radially inwardly if required (e.g.
  • the chamber 304C is located behind, against or on the outer circumference of the upper inflatable RCD packer 304 such that when hydraulic fluid is pumped from the accumulator 316 via the hydraulic fluid pathway 318 via the hydraulic port 318U into the chamber 304C, the hydraulic fluid forces the upper inflatable RCD packer 304 to move radially inwardly to make contact with and thus seal against the outer surface of the drill pipe located in the throughbore 11.
  • the operator can control the pressure of the hydraulic fluid being pumped from the accumulator 316 such that the operator can increase that pressure to be a predetermined or certain amount greater than the wellbore pressure of the reservoir/wellbore fluids and/or drilling mud and cuttings within the throughbore 11 such that the inflatable upper RCD packer 304 provides a constant seal when required against the outer surface of the drill pipe string and thus prevents any drilling fluid or reservoir fluids from passing past the upper inflatable RCD packer 304 and thus prevents any reservoir fluids or drilling mud from exiting the throughbore 11 via the upper end 340U into the outer subsea environment.
  • the drilling mud and reservoir fluids are forced to exit the subsea RCD system 1 via a drilling mud returns outlet port 20 formed through the sidewall 15 of the system outer housing 10 at a location below (or upstream of) the upper inflatable RCD packer 304 (and moreover at a location below or upstream of the lower inflatable RCD packer 302 and the lower static annular packer 190) and such drilling muds can be returned to the platform or drilling rig at the surface of the water above the BOP 18 by means of a suitable hose connected between said drilling mud returns outlet port 20 and said platform or rig (not shown).
  • the radially inner most surface or throughbore 312U of the upper inflatable RCD packer 304 is provided with a sleeve 314U which is preferably formed of a hardwearing material such as Polyurethane (PU) in order to protect the more compliant material of the upper inflatable RCD packer which may be rubber or the like. Accordingly, it is the relatively harder wearing and longer lasting PU sleeve 314U which is in contact with the drill pipe string once the upper inflatable RCD packer 304 has been inflated.
  • PU Polyurethane
  • the lower inflatable RCD packer 302 is located vertically below (and is therefore located upstream of) the upper inflatable RCD packer 304 and therefore it is in series or in line along the longitudinal axis 17 of the subsea RCD system 1.
  • the lower inflatable RCD packer 302 is similarly located within a recess 301 L formed in the RCD inner housing 306 in the inner rotatable part 340 and the lower inflatable RCD packer 302 also has a chamber 302C formed on its outer surface where the chamber 302C is also in fluid communication via hydraulic port 318L with the same hydraulic fluid pathway 318 as the upper inflatable RCD packer 304. Accordingly, actuation of the lower inflatable RCD packer 302 can be achieved at exactly the same time as actuation of the upper inflatable RCD packer 304 by pumping hydraulic fluid from the accumulator 316.
  • the subsea RCD system 1 further comprises a hydraulic fluid control system to control operation of the accumulator 316, where the hydraulic fluid control system comprises a pressure transducer and combined BluetoothTM transmitter 22, where the pressure transducer 22 sends the pressure of fluids contained within the throughbore 11 and the BluetoothTM transmitter 22 sends that sensed pressure reading to a BluetoothTM receiver 323 and the hydraulic fluid control system can then receive that sensed pressure signal from the BluetoothTM receiver 323 and can then instruct the hydraulic accumulator 316 accordingly, depending on whether additional hydraulic fluid pressure is required to be provided into the chambers 304C, 302C in order to provide a greater seal between the upper 304 and lower 302 inflatable RCD packers or whether they should be deflated (in which case the hydraulic fluid pressure should be reduced to withdraw the hydraulic fluid from both chambers 304C, 302C) if the fluid pressure should be reduced in order to avoid damaging the packers 304, 302 or indeed if they should be moved radially outwards so that they are no longer in contact with the drill string if
  • An anti-rotation key 352 is provided towards the upper end of the RCD housing 308, where the anti-rotation key 352 is arranged to be located within a slot formed in the outer surface of the RCD outer housing 308 and where the key 352 is biased outwardly by a biasing means such as one or more springs.
  • the key 352 is provided at a specific location on the outside of the RCD outer housing 308 such that it will be possible to be aligned with an axially extending slot formed on the inner surface 12 of the system outer housing 10 such that when the key 352 aligns with said slots in the system outer housing 10, it will be biased into that slot and will therefore assist in preventing rotation of the RCD outer housing 308 (and thus the rest of the stationary part 342) occurring relative to the system outer housing 10.
  • the keys 352 are also provided with tapered edges at their upper and lower most ends such that pulling upon the RCD 300 (for example by means of a retrieval profile provided on the outer surface of a retrieval tool included in a drill string (not shown) which can locate in a retrieval profile 310 formed on the inner surface 305 of the inner rotatable part 340 of the RCD 300 and therefore pulling upwards by the drill string can pull the RCD 300 upwards out of the system outer housing 10 and such pulling will overcome the biasing action of the springs of the key 352 and therefore the RCD 300 can be pulled upwards out of the system outer housing 10.
  • An arrangement of pressure energised seals 326 is further provided on the outer surface of the RCD outer housing 308 and in particular there is preferably provided a lower set of pressure energised seals 326L at or towards the lower end of the RCD outer housing 308 and an upper set of pressure energised seals 326U provided at or towards the upper end of the RCD outer housing 308.
  • the seals 326 have a radially inner face which is in contact with a fluid conduit 328 formed at least through the RCD outer housing 308 between the upper 326U and the lower 326L seals.
  • the fluid conduit 328 is further in fluid communication with a hydraulic port 330 formed through the sidewall of the RCD outer housing 308.
  • the fluid port 330 has a dual function, however, in that it also provides an aperture into which a locking dog 68 can be moved into.
  • the locking dog is mounted on the outer surface of the system outer housing 10 within an aperture formed through the sidewall 15 of the system outer housing 10, where the locking dog 68 can be moved radially inwards (in order to lock into the fluid port 330) and can be moved radially outwards (to unlock from the fluid port 330) and therefore to release the RCD 300 such that it can be retrieved from the system outer housing 10.
  • the locking dog 68 has a fluid port formed longitudinally through its centre such that hydraulic fluid can be pumped therethrough from a hydraulic fluid supply line 65U which in turn connects with a flying lead which is connected to the BOP 18.
  • signals sent to the BOP 18 can instruct the BOP 18 to pump hydraulic fluid into (or pump out of) the supply line 65U and therefore into or out of the fluid conduit 328 in order to actuate/energise the pressure energise seals 326 or de- actuate/de-energise the pressure energised seals 326 in order to either seal or unseal the RCD 300 and in particular the outer surface thereof with respect to the inner surface of the system outer housing 10 such that no unwanted wellbore fluids can flow from the throughbore 11 up between the outside of the RCD outer housing 308 and the inner throughbore of the system outer housing 10.
  • the lower static annual packer 190 comprises a housing 200 which is generally cylindrical and which contains a throughbore 211 and recess within the inner surface 205 of the throughbore 211 , where the recess 201 contains the inflatable lower static annular packer seal 202 in such a manner that the packer seal 202 is held captive within the recess 201 such that is cannot move axially.
  • An anti-rotation key 252 is also provided on the outer surface of the packer housing 200 and is adapted to locate within a longitudinal slot formed at a suitable location on the inner surface 12 of the system outer housing 10 in order to prevent rotation of the lower static annual packer 190 within the system outer housing 10.
  • a set of pressure energised seals 226L is provided at or towards the lower end of the packer seal housing 200 and an upper set 226U of pressure energised seals is provided at or towards the upper end of the packer seal housing 200, where both pressure energised seals 226 are actuated by means of hydraulic fluid being pumped into fluid conduit 228 which connects both sets of pressure energised seals 226 via a fluid and locking port 230.
  • the inner surface 205 of the packer seal 200 is further provided with a retrieval profile 210 preferably at its upper end in order to permit a suitable retrieval profile (not shown) formed on the outer surface of a drill pipe string (not shown) to land therein and retrieve the lower static annual packer 190 should that be required and/or to run in a new lower static annular packer 190 instead.
  • both the lower static annual packer 190 and the RCD 300 can be retrieved from or run in to the throughbore 11 of the system outer housing 10 together by locating the retrieval profile of the drill pipe string into the retrieval profile 210 of the lower static annular packer 190 and sitting the RCD 300 on top of the lower annular static packer 190 around the drill pipe string such that both can be run into or retrieved from the throughbore 11 of the system outer housing 10 at the same time.
  • the lower static annular packer 190 Once the lower static annular packer 190 is located within the system outer housing 10, it can be locked in place by means of a lowermost first set of locking dogs 64L being actuated to move radially inwards such that they locate within the fluid and locking port 230 and further locked in place by means of a lowermost second set of locking dogs 64R being actuated to move radially inwards such that they locate within the fluid and locking port 231. Hydraulic fluid can then be pumped through the throughbore of the locking dog 64L via fluid conduit 65L via the flying lead 70 from the BOP 18 in order to actuate the pressure energised seals 226.
  • the operator can instruct the BOP 18 to pump hydraulic fluid from the BOP 18 through the flying lead 70 and through the throughbore of the second set of locking dogs 64R (once they have been moved radially inwards in order to lock into the fluid locking port 231) such that the hydraulic fluid flows from the port 231 via the fluid conduit 218 into the space 2020 between the outer surface of the packer seal 202 and the inner surface of the recess 201 in order to create the chamber 202C such that the packer seal 202 is inflated in order to move it radially inwards to compress against the outer surface of the drill pipe.
  • the operator would likely wish to actuate or inflate the lower static annular packer seal 202 in circumstances where the RCD 300 can no longer adequately seal against the outer surface of the drill pipe and therefore in such a circumstance, either or both of the upper 304 or lower 302 RCD packers need to be replaced.
  • the seals 304, 302 on the RCD 300 would be deflated but only after the lower static annular packer seal 202 has been inflated such that the wellbore fluids located below the lower static annual packer 190 are contained by the inflated lower static annual packer seal 202.
  • the RCD 300 can then be unlatched from its locking dog 68 and can then be retrieved from the wellbore by a retrieval tool landing its profile in the landing profile 310.
  • the lower annual packer 190 is a static packer in that, whilst it is actuable and inflatable to move it radially inwards to seal against the outer surface of the drill pipe located in its throughbore 211, it is a static packer 190 in that it is not intended to be able to rotate relative to the subsea outer housing 10.
  • the reason for this is that if the lower annual packer 190 is actuated to seal against the outer surface of the drill string then the operator will not be drilling and will therefore not be rotating the drill pipe because the lower annual packer 190 is likely to be the only annular seal against the outer surface of the drill pipe within the subsea RCD system because the RCD 300 is likely to be out of operation or is being replaced.
  • the lower annual packer 190 could be modified such that it is provided for example with bearings in order to allow the inflatable lower annual packer seal 202 to rotate with the drill pipe string.
  • the subsea RCD system could be modified such that there is provided two or more inflatable lower annual packer seals 202 in series such that there is redundancy in place.
  • the inflatable lower static annular packer seal 202 can be provided with a sleeve such as a polyurethane sleeve (not shown) on its inner throughbore surface in order to provide additional life span and durability in a similar manner to the PU sleeve 312 provided on either or both of the upper 304 and lower 302 inflatable RCD packers.
  • a sleeve such as a polyurethane sleeve (not shown) on its inner throughbore surface in order to provide additional life span and durability in a similar manner to the PU sleeve 312 provided on either or both of the upper 304 and lower 302 inflatable RCD packers.
  • both of the upper 304 and lower 302 inflatable RCD seals can be used for pressure control of the drilling mud and wellbore fluids located in the throughbore 11 for both drilling operations (i.e. whilst the drill string is rotating) and also stripping operations (i.e. whilst the drill string is tripping into or out of the wellbore) and moreover the lower static annual packer 190 can be used to provide pressure control of the wellbore fluids and drilling mud located within the throughbore 11 for stripping operations where the drill string is being tripped into or pulled out of the wellbore.
  • the lower end of the subsea RCD system 1 is typically attached to the upper end of the flex connection joint 14 and the suitable connection 16 at the surface of the sea on the platform or drilling rig.
  • a retrieval tool is included in a work string such as a drill string at the surface of the sea on the platform or drilling rig.
  • the retrieval profile on the retrieval tool is coupled to and connected into the retrieval profile 210 provided within the lower static annular packer 190 or more preferably via the retrieval profile 310 provided within the RCD 300 such that the subsea RCD system 1 plus connections 14, 16 are hanging off the retrieval tool provided within the drill string.
  • the drill string is then lowered through the BOP 18 into the wellbore from the platform or drilling rig at the surface of the sea until the connection 16 makes contact with the BOP 18 and is secured and sealed thereto.
  • An ROV or other suitable means is used to connect the flying lead 70 from the BOP 18 to the system outer housing 10 such that the hydraulic fluid supply from the flying lead is connected into the locking dogs 64L, 64R via their respective lines 65L. 65R.
  • the retrieval tool within the drill string is de-actuated such that it disconnects from the retrieval profile 310 (or 210 as appropriate) and the drill string is pulled someway back up to the surface as far as required in order to remove the retrieval tool from the drill string.
  • this step can be skipped.
  • the upper 304 and lower 302 inflatable RCD packers are inflated by actuation of the hydraulic fluid control system which instructs the actuator 316 to provide pressurised hydraulic fluid to the chambers 302C and 304C to the required fluid pressure such that said pressure is greater that the drilling mud and wellbore fluid pressure located within the throughbore 11 (as sensed by the pressure transducer and Bluetooth transmitter 22). It should be noted that both upper 304 and lower 302 inflatable RCD packers are inflated so that the seals formed thereby against the drill pipe string are duplicated such that there is back up in case one of them fails.
  • the operator can then commence managed pressure drilling (MPD) operations because the inner rotatable part 340 can now rotate with the drill pipe string and furthermore the drill pipe string can be moved downwards through the subsea RCD system 1, with the drill pipe joints passing through the seals 304, 302 in a stripping operation.
  • MPD managed pressure drilling
  • the embodiments of the present invention have the great advantage that the hydraulic control system can automatically adjust the pressure exerted upon the drill string by the upper 304 and lower 302 inflatable packer seals and it can increase or decrease the force as required in order to ensure that an appropriate positive delta pressure is maintained between the force being applied and the pressure of the wellbore fluids and drilling mud located within the throughbore 11.
  • step 4 Should either or both of the upper 304 and lower 302 RCD inflatable packer seals require to be replaced and if step 4 was followed, then the drilling operations will be halted and the drill string is pulled back to surface in order that a retrieval tool can be included in the drill string at surface.
  • the retrieval/running tool is then run into the throughbore 11 until it aligns with the retrieval profile 310 within the RCD 300.
  • the retrieval tool is then actuated to latch inside the retrieval profile 310.
  • the lower static annular packer seal 202 is then inflated to seal against the outer surface of the drill pipe.
  • the upper most set of locking dogs 68 can then be retracted radially outwards such that they no longer engage/lock within the fluid port/locking port 330 of the RCD 300.
  • the operator can instruct the hydraulic fluid control system to de-pressurise and therefore deflate the upper 304 and lower 302 inflatable RCD packers. Such an action will also deflate the upper 304 and lower 302 inflatable RCD packers, such that all of the annular sealing is being provided by the inflated lower static annular packer seal 202.
  • the operator can instruct the hydraulic fluid control system to de-pressurise and therefore deflate the upper 304 and lower 302 inflatable RCD packers, such that all of the annular sealing is being provided by the inflated lower static annular packer seal 202. 10.
  • the RCD 300 can then be retrieved or pulled back to the surface on the drill pipe string, with the drill pipe joints being stripped through the inflated and sealed lower static annular packer seal 202.
  • the old/worn RCD 300 can be replaced with a new RCD 300 and it can be run back in on the running tool of the drill pipe string by means of its retrieval profile 310 being engaged by the running tool.
  • the new RCD 300 will be run in until it reaches its in use location and the upper set of locking dogs 68 will engage in the new RCD 300 such that the new RCD 300 is locked in placed by the locking dogs 68.
  • the retrieval tool can be de-actuated and the upper 304 and lower 302 RCD packers can be inflated in order to seal against the outer surface of the drill pipe.
  • the lower static annular packer seal 202 can then be deflated.
  • the retrieval tool can be pulled back to the surface if needs be, removed from the drill string and the drill string can then be run back into the hole through the subsea RCD system 1 and drilling operations can be commenced.
  • the running tool can be included in the drill string and the drill string can be run into the subsea RCD system 1 until the running tool is aligned with the retrieval profile 210 and the retrieval profile can latch into the retrieval profile 210 of the lower static annular packer 190. Once it is locked in place, the next stage occurs.
  • Both sets of locking dogs 68, 64 are retracted radially outwards such that neither the RCD 300 nor the lower static annular packer 190 are locked with respect to the system outer housing 10. The RCD 300 and the lower static annular packer 190 can then be recovered back to the surface by pulling the upper end of the drill string upwards.
  • the old RCD 300 and lower static annular packer 190 can be replaced at the surface with respective new RCD 300 and lower static annular packer 190 and can be run back down into the system outer housing 10 on the retrieval tool of the drill string. 15. Both sets of locking dogs 64, 68 are then actuated to lock into their respective fluid and locking ports 230, 231; 330.
  • the retrieval tool can then be retrieved back to the surface by pulling up on the drill string.
  • the retrieval tool can be removed from the drill string if required and drilling operations can then be commenced again once the upper RCD packer 304 and the lower ECD packer 302 have been inflated.
  • Embodiments of the present invention therefore provide a subsea RCD system 1 incorporating removable annular seals 304, 302, 202.
  • embodiments of the present invention provide a pair of removable rotating (RCD) inflatable packers 304, 302 which can be inflated to seal on the drill string while drilling.
  • the packers 304, 302 are inflated by means of an accumulator 316 attached to the RCD 300.
  • the wellbore pressure 11 is continuously monitored, with the pressure reading transmitted to the accumulator 316 via a Bluetooth TM transmitter/receiver system to allow the packer 304, 302 actuation pressure to maintain a constant positive delta above that of the wellbore pressure 11.
  • a Bluetooth TM transmitter/receiver system to allow the packer 304, 302 actuation pressure to maintain a constant positive delta above that of the wellbore pressure 11.
  • Embodiments of the present invention therefore also provide a further single inflatable static packer in the form of the lower static annular static packer 190 and this is included in order to be able to seal on the drill string whilst stripping operations are conducted.
  • the various packers, 304, 302, 202 are installed in their respective housings which can have the form of cartridges which are landed and locked within the bore 11 of the subsea RCD system 1. These housings/cartridges can be run/retrieved to replace the respective seals therein 304; 302; 202 without the need to retrieve the full subsea RCD system or unit 1. This greatly enhances the serviceability and maintainability of the subsea RCD system 1 as these wearable seals/parts 304; 302; 202 can be quickly/easily replaced with the minimum of hassle/downtime.
  • the subsea RCD system 1 preferably includes an Oil States LynxGripTM HARTM connector in order to connect the subsea RCD system 1 to the BOP18 and further preferably includes an Oil States FlexJointTM to dampen the operational loads transferred into the BOP 18.
  • FIG. 2 An alternative second embodiment of a subsea RCD system 2 is shown in Fig. 2.
  • the second embodiment of subsea RCD system 2 comprises the same system outer housing 10 as that hereinbefore described, along with the same lower locking dog 64L, 64R arrangement and associated hydraulic fluid supply lines 65L; 65R and same upper locking dog arrangements 68 along with the same hydraulic fluid supply line 69 and the same drilling mud return outlet port 20 and the same flex connection joint 14 and suitable connection 16 for connection to the BOP18 and the same flying lead 70 along with the same guide funnel 19 for ensuring guiding of the RCD 2300 and lower static annular packer 190 into the system outer housing 10.
  • the lower static annular packer 190 is the same as that used in the first embodiment of subsea RCD system 1.
  • the main difference between the second embodiment 2 and the first embodiment 1 of subsea RCD systems is with the RCD 2300 compared to the RCD 300.
  • similar components between the RCD 2300 and the RCD 300 are indicated with the same reference numerals except with the addition of 2000 to that used in the second embodiment 2.
  • the main difference between the two embodiments 1, 2 is that with the RCD 2300, the inner rotatable part 2340 is now wholly contained within the stationary part 2342.
  • the inner rotatable part 2340 now comprises both the upper inflatable RCD 2304 and the lower inflatable RCD packer 2302 being wholly contained within the inner rotatable part 2340 which comprises the RCD inner housing 2306 which in turn now comprises at its upper end a set of staged dynamic seals 2336U and at its lower end a further set of staged dynamic seals 2336L, such that the RCD inner housing 2306 is now rotatable within the RCD outer housing 2308 by virtue of an upper 2332U and lower 2332L sets of bearings.
  • the RCD 2300 will be operated in a similar manner as already hereinbefore described to the RCD 300.
  • the lower static annular packer 2190 of Fig. 2A and Fig. 2 is operated in exactly the same manner as the lower static annular packer 190 of the first embodiment 1.

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Abstract

Système de dispositif de commande rotatif (RCD) sous-marin (1 ; 2) conçu pour permettre à une colonne de travail tubulaire de passer à travers celui-ci de telle sorte qu'un espace annulaire est créé entre l'alésage traversant interne du système de dispositif de commande rotatif (RCD) sous-marin (1 ; 2) et la surface externe de la colonne de travail tubulaire. Le système de dispositif de commande rotatif (RCD) sous-marin comprend un boîtier de système (10) comprenant un alésage traversant, une extrémité supérieure et une extrémité inférieure (10L) conçue pour être raccordée à un bloc d'obturation de puits (BOP) d'une tête de puits. Le système RCD sous-marin (1 ; 2) comprend en outre au moins deux joints RCD (302, 2302 ; 304, 2304) agencés pour être montés de façon sélective à l'intérieur du boîtier de système (10) et qui peuvent être actionnés de manière sélective entre une configuration non étanche dans laquelle lesdits deux joints RCD (302, 2302 ; 304, 2304) sont rétractés radialement vers l'extérieur et une configuration étanche dans laquelle lesdits deux joints RCD (302, 2302 ; 304, 2304) sont étendus radialement vers l'intérieur. Le système RCD sous-marin (1 ; 2) comprend en outre au moins un joint annulaire (202) agencé pour être monté de manière sélective à l'intérieur du boîtier de système (10) au-dessous desdits deux joints RCD (302, 2302 ; 304, 2304), ledit joint annulaire (202) pouvant être actionné de manière sélective entre une configuration non étanche dans laquelle ledit joint annulaire (202) est rétracté radialement vers l'extérieur et une configuration étanche dans laquelle ledit joint annulaire (202) est étendu radialement vers l'intérieur.
PCT/GB2020/052823 2019-11-11 2020-11-06 Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin WO2021094717A1 (fr)

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BR112022009096A BR112022009096A2 (pt) 2019-11-11 2020-11-06 Aparelho e método relacionado à perfuração de pressão gerenciada (mpd) enquanto estiver usando um sistema rcd submarino
EP20804652.4A EP4058654A1 (fr) 2019-11-11 2020-11-06 Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin
US17/769,997 US20220381105A1 (en) 2019-11-11 2020-11-06 Apparatus and method relating to managed pressure drilling (mpd) whilst using a subsea rcd system

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GBGB1916384.9A GB201916384D0 (en) 2019-11-11 2019-11-11 Apparatus and method relating to managed pressure drilling (MPD) whilst using a subsea RCD system
GB1916384.9 2019-11-11

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WO2023175400A1 (fr) * 2022-03-13 2023-09-21 Weatherford Technology Holdings, Llc Opérations de pression gérées sans colonne montante

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EP4058654A1 (fr) 2022-09-21
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BR112022009096A2 (pt) 2022-07-26
US20220381105A1 (en) 2022-12-01
GB202017599D0 (en) 2020-12-23
GB201916384D0 (en) 2019-12-25

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