WO2023073022A1 - Ensemble tête de puits sous-marin destiné à être utilisé dans des opérations de forage sans colonne montante - Google Patents

Ensemble tête de puits sous-marin destiné à être utilisé dans des opérations de forage sans colonne montante Download PDF

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Publication number
WO2023073022A1
WO2023073022A1 PCT/EP2022/079939 EP2022079939W WO2023073022A1 WO 2023073022 A1 WO2023073022 A1 WO 2023073022A1 EP 2022079939 W EP2022079939 W EP 2022079939W WO 2023073022 A1 WO2023073022 A1 WO 2023073022A1
Authority
WO
WIPO (PCT)
Prior art keywords
control device
tubular
rotating control
head assembly
well head
Prior art date
Application number
PCT/EP2022/079939
Other languages
English (en)
Inventor
Kristian Engelbrecht HANSEN
Original Assignee
Noble Drilling A/S
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from DKPA202101018A external-priority patent/DK202101018A1/en
Priority claimed from DKPA202101020A external-priority patent/DK202101020A1/en
Application filed by Noble Drilling A/S filed Critical Noble Drilling A/S
Publication of WO2023073022A1 publication Critical patent/WO2023073022A1/fr

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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 invention relates to a drilling vessel with subsea well head assembly for use in riserless drilling operations and being adapted for enclosing a tubular, the subsea well head assembly comprises a Rotating Control Device (RCD) and a blowout preventer (BOP). Furthermore, the invention relates to a Rotating Control Device (RCD) for use in a subsea well head assembly for performing riserless drilling operations
  • RCD Rotating Control Device
  • BOP blowout preventer
  • risers serve to move fluids from the sea floor to an offshore drilling unit on the sea surface.
  • a well head assembly is connected to a marine riser having several functionalities, namely to serve as a return conduit for drilling fluid coming from well, to be used for attachment of rigid choke and kill lines that must be in place between a Subsea BOP and a drilling rig for well control, to handle the subsea BOP relatively to the wellhead on the seabed, and to avoid pollution during drilling.
  • a flex joint allows the riser to bent relatively to the well head assembly, and thereby release stress acting on the well head assembly due to sea originated forces acting on riser.
  • the well head assembly in riserless configurations comprises a blowout preventer adapted for preventing a blowout from a well bore and a Rotating Control Device (RCD) being adapted for sealing a tubular during operation.
  • the RCD may be adapted to divert drill fluid for return to a rig via a mud return Pipe-
  • the RCD is used for sealing off the well on top of the BOP.
  • Tubulars such as drilling or tripping drill pipes or casings passes through the RCD.
  • For the connected condition while tripping or drilling the rigs operating offset will be restricted by an allowable angle between the tubular and RCD defined by yielding of the tubular.
  • the purpose of the invention is to make the well head assembly in a riserless configuration more robust.
  • This purpose is according to the invention achieved by a drilling vessel with equipment for performing riserless drilling operations as defined in claim 1, a method of performing riserless drilling operations by using a well head assembly as defined in claim 9, and a Rotating Control Device for use in a subsea well head assembly adapted for riserless drilling operations as defined in claim 11.
  • a subsea well head assembly is defined in claim 16
  • a method of performing riserless drilling operations is defined in claim 21
  • a Rotating Control Device for use in a subsea well head assembly adapted for riserless drilling operations is defined in claim 23.
  • Preferred embodiments are defined in the dependent claims.
  • a flex joint is provided between the RCD and the BOP.
  • the BOP may be a hydraulic or conventional BOP or an electrical BOP. This configuration which enables the RCD to follow the drilling angle defined by the tubular through RCD and BOP. By letting the flex joint taking up that relative angle between the tubular and the RCD, bending stress in the tubular will be reduced and further provides better sealing conditions for the RCD to seal around the tubular.
  • the flex joint is provided as an integral element of the blowout preventer for use in a subsea well head assembly adapted for enclosing a tubular and adapted for riserless drilling operations.
  • the blowout preventer (BOP) being adapted for preventing a blowout from a well bore operated by a tubular.
  • the BOP has a housing element being integral with a lower housing element of a flex joint.
  • An upper housing element of the flex joint is prepared for connecting to an RCD. The flex joint allows the upper housing element, and thereby the RCD, to align with the tubular.
  • the flex joint is provided as an integral element of the Rotating Control Device (RCD) for use in a subsea well head assembly adapted for riserless drilling operations.
  • the RCD comprises a housing enclosing a sealing element for sealing a tubular, and a connector element for connecting the RCD to a BOP.
  • the RCD further comprises a flex joint having an upper housing element integral with the housing and a lower housing element integral with the connector element.
  • Fig. 1 illustrates schematically a floating vessel performing a riserless drilling operation according to an embodiment of the invention
  • Fig. 2 illustrates schematically one embodiment of a well head assembly according to the invention
  • Fig. 3 illustrates schematically a blowout preventor (BOP) for use in riserless drilling operation according to an embodiment of the invention
  • Fig. 4 illustrates schematically a flex joint for use in riserless drilling operation according to an embodiment of the invention
  • Fig. 5 illustrates schematically a rotating control device (RCD) for use in riserless drilling operation according to an embodiment of the invention
  • Fig. 6 illustrates schematically a blowout preventor (BOP) with integrated flex joint according to an embodiment of the invention
  • Fig. 7 illustrates schematically a rotating control device (RCD) with integrated flex joint according to an embodiment of the invention.
  • Fig. 1 illustrates schematically a floating vessel 10 performing a riserless drilling or maintenance operation according to one embodiment of the invention.
  • the vessel 10 is in the illustrated embodiment a so-called semi-sub.
  • the vessel 10 is floating on the surface 11 of the sea and has a hull 12 carrying a derrick 14 and a drill deck defining one or more well centers 16.
  • the vessel 10 has at least two submerged, ballasted, watertight pontoons 18.
  • the riserless drilling operation is based on Riserless Mud Recovery (RMR) technology with one or more subsea pumps 28 provided on seabed 21.
  • RMR Riserless Mud Recovery
  • subsea pump 28 By means of the subsea pump 28, well cuttings are moved away from a subsea template, which allows drill mud and cuttings to be returned from a subsea wellhead 31 (shown in fig. 2) to the vessel 10 via the subsea pump 28.
  • RMR Riserless Mud Recovery
  • vessels like e.g. jack-up and floater rigs may be used on vessels like e.g. jack-up and floater rigs.
  • the riserless drilling operation is operated from the well center 16, from where a tubular, such as a drillstring 20, extends via a well head assembly 25 down to a subsea well 30. Mud is pumped by a mud pumping system present on the drill deck via the drillstring 20 down into the drilled subsea well 30. In the well 30, the drillstring 20 rotates the bottom hole assembly (BHA) or the drill bit 34. By using the RMR technology cuttings from the drill bit 34 and mud is diverted from the well head assembly 25 via a return mud tube 22 and pumped back to vessel 10 with the subsea pump 28.
  • BHA bottom hole assembly
  • Tubular running refers to a generic process of handling tubulars on a rig, lowering tubulars to the well and installing casing accessories. Tubulars are stocked up on the rig (and replenished as required) prior to being run into the well.
  • the return mud tube 22 may be a flexible liquid-tight hose bringing mud and cuttings to the vessel for separation, and subsequently recirculating the mud.
  • the return mud tube 22 may be a steel pipe assembled by multiple pipe elements.
  • the mud pumps on the drill floor may be sufficient to drive the mud circulation, why the subsea pump 28 may be omitted.
  • the drilling operator may obtain several benefits due to the reduced weight the hoisting system on the drill floor must handle. This may improve wellbore stability, reduce volumes of circulated drilling fluid, reduce volumes of cement used in the well construction, reduce the drilling time and the logistics costs.
  • the reduced weight lifted by the hoisting system may reduce the required capacity of the hoisting system, or increase the depths on which the vessel 10 is able to operate.
  • the well head assembly 25 will be described in greater details with reference to fig. 2. As seen, the well head assembly 25 is mounted on top of the well head 31 just above the seabed 21. The well head 31 is the upper termination of the drilled well 30.
  • the well head assembly 25 comprises a blowout preventer (BOP) 40 and a Rotating Control Device (RCD) 60.
  • BOP 40 has a connector 41 for connecting to the well head 31.
  • high-pressure lines are attached to the return mud tube 22, and these high-pressure lines allows fluids to be pumped into or removed from the well with the BOP 40 s closed.
  • the choke and kill lines are connected to the well head assembly 25 and controlled from the surface vessel 10.
  • the choke and kill lines are used to circulate fluids into and out of the wellbore to control well pressure.
  • an umbilical is present in parallel to the return mud tube 22, to enable communication between a control room on the vessel 19 and the subsea equipment present in the well head assembly 25 whereby the subsea equipment may be controlled from the surface vessel 10.
  • the tubular 20 passes through the well head assembly 25 and down to the well 30.
  • a flex joint 50 is provided in between the RCD 60 and the BOP 40. This enables the RCD 60 to align with the tubular 20.
  • the RCD 60 comprises a guiding funnel 61 ending in an opening for guiding the tubular 20 when received. Furthermore, the RCD 60 has a sealing element 62 for sealing the tubular 20, and a housing 64, and a mud outlet 63 for diverting fluids to the return mud tube 22. Furthermore, the RCD 60 includes bearing 66 for positioning the tubular 20, and a connector element 65 for mounting the RCD 60 to the flex joint 50.
  • the RCD 60 comprises at least one outlet 63 for diverting wellbore fluids from the well bore 30 and being adapted for providing a closed-loop environment to contain and divert fluids and to enable wellbore pressure management in a closed-loop drilling (CLD) system.
  • CLD closed-loop drilling
  • the sealing element 62 includes hydraulic control for obtaining a required sealing force towards the tubular 20.
  • the RCD 60 is a pressure-control device used during drilling for the purpose of making a seal around the tubular 20 while the tubular 20 moves, either by rotation or by axial movement. This device is intended to create a pressure-tight barrier against drilling hazards, such as to contain hydrocarbons or other wellbore fluids and prevent their release to the environment.
  • the RCD 60 is a critical component of any closed-loop drilling (CLD) system, in which the RCD 60 creates a closed-loop environment to contain and divert fluids and to enable wellbore pressure management.
  • the sealing element 62 is adapted for sealing the rotating tubular running 20, and being adapted for creating a pressure-tight barrier for wellbore fluids contained and for preventing their release to the surroundings.
  • the bearings 66 of the RCD 60 includes in some embodiments axial-radial cylindrical bearings providing low-torque rotation and load support.
  • the sealing element 62 of RCD 60 is manufactured from natural rubber, nitrile, butyl, or urethane. The sealing element 62 may be hydraulically controlled.
  • the RCD 60 isolates the environment from potentially harmful wellbore fluids and gases during drilling operations and diverts drilling fluids and cuttings to solids control equipment.
  • the flex joint 50 has a first mounting flange or connector element 51 for connecting the flex joint 50 to the RCD 60, and a second mounting flange or connector element 58 for connecting the flex joint 50 to the BOP 40.
  • the flex joint 50 comprises a top part 52 and a lower part 54.
  • the top part 52 and the lower part 54 has sets of interacting spheric surfaces 55 permitting a longitudinal axis 23 of a lower part of the well head assembly 25 to vary relatively to a longitudinal axis 24 of an upper part of the well head assembly 25.
  • the top part 52 and the lower part 54 are shown aligned, but for illustrative purposes the longitudinal axis 24 is tilted relatively to the longitudinal axis 23 for indicating the purpose of the flex joint 50, namely to permit the longitudinal axis 24 to tilt relatively to the longitudinal axis 23.
  • the indication of the longitudinal axis 24 may be seen as the maximum deflection of the top part 52 relatively to the longitudinal axis 23.
  • the lower part 54 and a locking part 53 are connected to each other via a biasing package ring or an elastomeric flex element 57.
  • the lower part 54 and the locking part 53 are flexible relatively to each other when sufficient forces are applied.
  • the spheric surface of the upper part 52 is received in a bowl 56, and the locking part 53 and the upper part 52 are bolted together. When no forces are acting on the tubing 20, the two longitudinal axes 23 and 24 will be aligned.
  • the flex joint 50 is a steel and elastomer assembly having a central through- passage equal to or greater in diameter than the diameter of the tubular 20.
  • the flex joint 50 may be positioned in the well head assembly 25 to reduce local bending stresses.
  • the flex joint 50 is a laminated metal and elastomer assembly, having a central through-passage equal to or greater in diameter than the interfacing pipe or tubing bore, to permit relative angular movement of the tubular 20 and reduce stresses due to vessel motion and environmental forces.
  • the blowout preventer 40 is adapted for preventing a blowout from a well bore operated by the tubular 20, no matter whether the tubing 20 is used for drilling, is tripping or is out of the well.
  • Fig. 3 shows the blowout preventer (BOP) 40.
  • the BOP 40 has a connector 41 or connector flange for connecting to the BOP 40 to the well head 31, and a connector or connector flange 45 for connecting to the BOP 40 to the flex joint 50.
  • the BOP 40 has a set of pipe rams 42, a set of blindshear rams 43, and an annular preventer 44. These valve components, the set of pipe rams 42, the set of blind-shear rams 43, and the annular preventer 44, are attached to a vertical tower element 46 extending between the connectors 41 and 45.
  • the blowout preventer 40 comprises at least one of the following one set of blind-shear rams 42, one set of pipe rams 43, and an annular preventer 44. In another embodiment, the blowout preventer 40 comprises one set of blind-shear rams 42, one set of pipe rams 43, and an annular preventer 44.
  • the set of pipe rams 42 are adapted for isolating the annular space by wrapping around the tubular when closed, and must be capable of closing and sealing on the tubular body of any drill pipe, workstring, and tubing under maximum anticipated surface pressure.
  • the set of blind-shear rams 43 are adapted to seal the wellbore by cutting through the drill string as the rams close off the well.
  • the Annular preventer 44 is a ring-shaped piece of equipment on the top of the valve stack of the blowout preventer (BOP) 40 and is used to prevent flow through the annular space between the drill string or casing and the annular preventer.
  • the annular preventer may include a doughnut shaped bladder that when in the open position allows the drill pipe to rotate but in the closed position seals the annulus.
  • Fig. 6 illustrates schematically a Blow-Out Preventor (BOP) 40 with integrated flex joint 50 according to an embodiment of the invention and is in this context named a BOP with flex joint 70.
  • the BOP with flex joint 70 has a connector 41 for connecting to the well head 31.
  • the BOP with flex joint 70 has a set of pipe rams 42, a set of blind-shear rams 43, and an annular preventer 44 attached to a vertical tower element 46.
  • the vertical tower element 46 is integral with a lower housing element 54* of the flex joint.
  • the lower housing element 54* is terminated to the upper part of the flex joint as discussed with reference to fig. 4. This means that the lower housing element 54* and a locking part are connected to each other via an elastomeric flex element.
  • the spheric surface 55 of the upper part 52 is received in a bowl 56, the locking part 53 and the upper part 52 are bolted together.
  • the top part and the lower part of the flex joint has sets of interacting spheric surfaces 55 permitting a longitudinal axis 23 of a lower part of the well head assembly 25 to vary relatively to a longitudinal axis 24 of an upper part of the well head assembly 25.
  • the vertical tower element 46 is integral with a lower housing element 54* of the flex joint of the combined BOP with flex joint 70, whereby the connector element 58 (fig. 4) and the connector or connector flange 45 (fig. 3) may be saved and a lower building height may be obtained.
  • Fig. 7 illustrates in cross-section a Rotating Control Device (RCD) 60 with integrated flex joint 50 according to an embodiment of the invention and is in this context named an RCD with flex joint 80.
  • the RCD with flex joint 80 has a connector element 58 for connecting to the BOP 40.
  • the RCD with flex joint 80 has a flex joint section comprising an upper housing element 52* and a lower part 54.
  • the upper housing element 52* and the lower part 54 has sets of interacting spheric surfaces 55 permitting longitudinal axes 23 and 24 of the upper and lower part of the well head assembly 25 to vary.
  • the upper housing element 52* and the lower part 54 are shown aligned, but for illustrative purposes the longitudinal axis 24 of the upper housing element 52* is shown tilted relatively to the longitudinal axis 23 of the lower part 54 for indicating the purpose of the flex joint, namely to permit the longitudinal axis 24 to tilt relatively to the longitudinal axis 23.
  • the lower part 54 and a locking part 53 are connected to each other via a biasing package ring or an elastomeric flex element 57.
  • the lower part 54 and the locking part 53 are flexible relatively to each other when sufficient forces are applied.
  • the spheric surface 55 of the upper housing element 52* is received in a bowl 56, whereafter the locking part 53 and the upper housing element 52* are bolted together.
  • the housing 64 of the RCD is integral with a upper housing element 52* of the flex joint of the combined RCD with flex joint 80, whereby the mounting flange 51 (fig. 4) and the connector or connector element (fig. 5) may be omitted and an overall lower building height may be obtained.
  • the RCD with flex joint 80 has a sealing element 62 for sealing the tubular 20, and bearings 66 for positioning the tubular 20.
  • the indication of the longitudinal axis 24 may be seen as the maximum deflection of the upper housing element 52* relatively to the longitudinal axis 23.
  • the flex joint constitutes an integrated part of the RCD 80 as the upper housing element 52* is integral with the housing 64 and a lower housing element 54 is integral with the connector element 58.
  • the sealing element 62 is adapted for creating a pressure-tight barrier for wellbore fluids contained and for preventing their release to the surroundings.
  • the RCD 80 is adapted for being part of a closed-loop environment to contain and divert fluids and to enable wellbore pressure management in a closed-loop drilling (CLD) system.
  • the bearings 66 are provided as axial-radial cylindrical bearings for providing low-torque rotation and load support for the tubular.
  • the sealing element 62 in provided in natural rubber, urethane, nitrile, or butyl.
  • a method of performing riserless drilling operations may be performed by using tubulars, such as drilling or tripping drill pipes or casings, when establishing new wells or when making workover or well intervention on existing wells involving invasive techniques, such as wireline, coiled tubing or snubbing.
  • a well head assembly 25 being adapted for enclosing the tubular 20 is used.
  • the well head assembly 25 comprises an RCD 60 and a BOP 40.
  • a flex joint 50 is provided in between the RCD 60 and the BOP 40.
  • the flex joint 50 allows the RCD 60 to align to the tubular 20 above the well head to reduce stress on the RCD caused by sea originated forces acting on the on the tubing 20.
  • the method includes diverting of wellbore fluids contained from the RCD 60 through at least one outlet 63 for providing a closed-loop environment to contain and divert fluids and to enable wellbore pressure management in a closed-loop drilling (CLD) system.
  • CLD closed-loop drilling

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

Abstract

L'invention concerne un engin de forage flottant dotée d'un équipement permettant d'effectuer des opérations de forage sans colonne montante, l'engin de forage flottant (10) étant configuré pour réaliser une technologie de récupération de boue sans colonne montante (RMR) avec une ou plusieurs pompes sous-marines (28) disposées sur le fond océanique (21) et comprenant un ensemble de tête de puits (25) étant conçu pour enfermer un élément tubulaire (20). L'ensemble tête de puits sous-marin comprend un dispositif de commande rotatif (60) et un bloc obturateur de puits (40). Le dispositif de commande rotatif (60) est conçu pour sceller l'élément tubulaire (20) tandis que l'élément tubulaire (20) se déplace, et présentant au moins une sortie (63) pour dévier des fluides de puits de forage contenus dans l'élément tubulaire (20) vers l'une ou les pompes sous-marines (28). Le bloc obturateur de puits (40) est conçu pour empêcher une éruption d'un puits de forage actionné par l'élément tubulaire (20). Un joint flexible (50) est disposé entre le dispositif de commande rotatif (60) et le bloc obturateur de puits (40) permettant au dispositif de commande rotatif (60) de s'aligner avec l'élément tubulaire (20).
PCT/EP2022/079939 2021-10-28 2022-10-26 Ensemble tête de puits sous-marin destiné à être utilisé dans des opérations de forage sans colonne montante WO2023073022A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
DKPA202101018A DK202101018A1 (en) 2021-10-28 2021-10-28 Subsea well head assembly for use in riserless drilling operations
DKPA202101018 2021-10-28
DKPA202101020 2021-10-28
DKPA202101020A DK202101020A1 (en) 2021-10-28 2021-10-28 Rotating control device (rcd) for use in a subsea well head assembly

Publications (1)

Publication Number Publication Date
WO2023073022A1 true WO2023073022A1 (fr) 2023-05-04

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PCT/EP2022/079939 WO2023073022A1 (fr) 2021-10-28 2022-10-26 Ensemble tête de puits sous-marin destiné à être utilisé dans des opérations de forage sans colonne montante

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Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20130126182A1 (en) 2010-07-30 2013-05-23 Ocean Riser Systems As Riserless, pollutionless drilling system
US20150330205A1 (en) * 2014-05-13 2015-11-19 Weatherford Technology Holdings, Llc Marine diverter system with real time kick or loss detection
WO2019014428A1 (fr) * 2017-07-14 2019-01-17 Bp Corporation North America Inc. Systèmes et procédés de forage sans riser à pression gérée
WO2021094717A1 (fr) * 2019-11-11 2021-05-20 Oil States Industries (Uk) Limited Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20130126182A1 (en) 2010-07-30 2013-05-23 Ocean Riser Systems As Riserless, pollutionless drilling system
US20150330205A1 (en) * 2014-05-13 2015-11-19 Weatherford Technology Holdings, Llc Marine diverter system with real time kick or loss detection
WO2019014428A1 (fr) * 2017-07-14 2019-01-17 Bp Corporation North America Inc. Systèmes et procédés de forage sans riser à pression gérée
WO2021094717A1 (fr) * 2019-11-11 2021-05-20 Oil States Industries (Uk) Limited Appareil et procédé concernant un forage à pression commandée (mpd) tout en utilisant un système rcd sous-marin

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