WO2014078094A2 - Système intelligent de pose de tête de puits et outil de pose - Google Patents

Système intelligent de pose de tête de puits et outil de pose Download PDF

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Publication number
WO2014078094A2
WO2014078094A2 PCT/US2013/067934 US2013067934W WO2014078094A2 WO 2014078094 A2 WO2014078094 A2 WO 2014078094A2 US 2013067934 W US2013067934 W US 2013067934W WO 2014078094 A2 WO2014078094 A2 WO 2014078094A2
Authority
WO
WIPO (PCT)
Prior art keywords
running tool
blowout preventer
wireless interface
preventer assembly
assembly
Prior art date
Application number
PCT/US2013/067934
Other languages
English (en)
Other versions
WO2014078094A3 (fr
Inventor
Chad Eric YATES
Dale Norman
Original Assignee
Vetco Gray Inc.
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 US13/679,789 external-priority patent/US20130088362A1/en
Application filed by Vetco Gray Inc. filed Critical Vetco Gray Inc.
Priority to SG11201503530SA priority Critical patent/SG11201503530SA/en
Priority to GB1508484.1A priority patent/GB2523680A/en
Publication of WO2014078094A2 publication Critical patent/WO2014078094A2/fr
Publication of WO2014078094A3 publication Critical patent/WO2014078094A3/fr
Priority to NO20150546A priority patent/NO20150546A1/en

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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
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • 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
    • E21B33/04—Casing heads; Suspending casings or tubings in well heads
    • E21B33/043—Casing heads; Suspending casings or tubings in well heads 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
    • E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
    • 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
    • E21B47/001—Survey of boreholes or wells for underwater installation
    • 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
    • E21B47/13—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 by electromagnetic energy, e.g. radio frequency

Definitions

  • This invention relates in general to subsea running tools and, in particular, systems and methods that provide remote communications from a subsea running tool to a surface platform through subsea equipment in communication with the surface platform.
  • Subsea running tools are used to operate equipment within subsea wellheads and subsea Christmas trees. This may include landing and setting of hangers, trees, wear bushings, logging tools, etc.
  • Current running tools may be hydraulically or mechanically operated.
  • a running tool may be run to a subsea wellhead to land and set a casing hanger and associated casing string.
  • a mechanical running tool will land and set the casing hanger within the wellhead by landing on a shoulder and undergoing a series of rotations using the weight of the casing string to engage dogs or seals of the casing hanger with the wellhead.
  • a hydraulic running tool may land and set the casing hanger by landing the hanger on a shoulder in the wellhead, and then use drop balls or darts to block off portions of the tool. Hydraulic pressure will build up behind the ball or dart causing a function of the tool to operate to engage locking dogs of the hanger or set a seal between the hanger and wellhead. Pressure behind the ball or dart can then be increased further to cause the ball or dart to release for subsequent operations.
  • Some tools may be combination mechanical and hydraulic tools and perform operations using both mechanical functions and hydraulically powered functions. These tools are extremely complex and require complex and expensive mechanisms to operate. These mechanisms are prone to malfunction due to errors in both design and manufacturing.
  • the tools may fail at rates higher than desired when used to drill, complete, or produce a subsea well. Failure of the tool means the tool must be pulled from and rerun into a well, adding several days and millions of dollars to a job.
  • production running tools that require a hydraulic umbilical to be run with the running tool to power a hydraulic operation. These tools require the use of expensive equipment and additional time to run the umbilical within the riser and production or landing string.
  • the umbilical requires significant facilities on the top side of the rig. This requires mobilizing specialized equipment and support personnel which add to the logistical challenges of completing a subsea well.
  • a running tool communication system including a running tool configured to interface with one or more blowout preventer assembly communication members, themselves connected to or interfaced with the subsea well and having access to subsea-surface equipment communication network, to provide real-time feedback to the rig operator.
  • subsea communication system including a running tool configured to receive real-time instructions from the rig operator through the subsea wellhead-surface equipment communication network, particularly when a problem is encountered.
  • various embodiments of the present invention advantageously provide a running tool subsea communication system including a running tool configured to interface with one or more blowout preventer assembly communication components, themselves connected to or interfaced with the subsea well and having access to subsea-surface equipment communication network.
  • Such embodiment or embodiments can advantageously provide realtime feedback to the rig operator regarding the status of the running tool and/or whether or not the running tool functioned properly during engagement with the wellhead.
  • Various embodiments of the present invention also advantageously provide a subsea communication system including a subsea wellhead equipment component configured to receive from the rig operator via the subsea-surface equipment communication network, and to transmit real-time running tool instructions, and a running tool configured to receive and act upon such instructions.
  • a subsea communication system including a subsea wellhead equipment component configured to receive from the rig operator via the subsea-surface equipment communication network, and to transmit real-time running tool instructions, and a running tool configured to receive and act upon such instructions.
  • Such embodiment or embodiments can advantageously provide such remote communications, particularly when a problem is encountered, in order to attempt correction rather than having to retrieve and rerun the running tool.
  • an embodiment of the present invention includes a running tool subsea communication system for communicating between a subsea running tool assembly disposed within a subsea wellhead, a blowout preventer assembly, or a combination thereof, and a surface platform.
  • the running tool assembly includes a running tool adapted to be suspended within a subsea wellhead, and/or a blowout preventer assembly, on or by a running string lowered from a surface platform.
  • the running tool assembly also includes a running tool wireless interface carried by the running tool and configured to communicate with a blowout preventer assembly wireless interface through a fluid medium located between the running tool wireless interface and the blowout preventer assembly wireless interface.
  • the communications are generally relatively short range due to transmission power limitations and attenuation due to the nature of the fluid medium, and thus, generally are designed to occur when the running tool is operably positioned within the axial bore of a member of the blowout preventer assembly or a bore extending through the subsea wellhead and when the running tool wireless interface is at a location within the relatively short communication range with the blowout preventer assembly wireless interface.
  • the running tool wireless interface provides running tool sensor data to the blowout preventer assembly wireless interface, which can be forwarded to the surface operator via the subsea electronic module communication network.
  • the system can include a blowout preventer assembly disposed on a subsea wellhead, a wireless interface carried by one or more members of the blowout preventer assembly and configured to provide running tool sensor data to a subsea electronics module, a running tool adapted to be suspended within the subsea wellhead and/or one or more members of the blowout preventer assembly, or a combination thereof, on or by a running string lowered from a surface platform; and a running tool wireless interface carried by the running tool.
  • the running to wireless interface is configured to communicate with the blowout preventer assembly wireless interface through a fluid medium located between the running tool wireless interface and the blowout preventer assembly wireless interface when the running tool is operably positioned within an axial bore extending through one of the members of the blowout preventer assembly or an axial bore extending through the subsea wellhead and when the running tool wireless interface is at a location within communication range with the blowout preventer assembly wireless interface to thereby provide running tool sensor data to the subsea electronics module.
  • Methods for communicating between a surface platform and a subsea running tool disposed within a subsea wellhead, a blowout preventer assembly, or a combination thereof are also provided.
  • An example of such a method can include the steps of providing a running tool wireless interface carried by a running tool, providing a blowout preventer assembly wireless interface mounted to a member of a blowout preventer assembly or mounted to a subsea wellhead connected with the blowout preventer assembly, positioning the running tool within an axial bore of one or more members of the blowout preventer assembly, an axial bore of the subsea wellhead, or a combination thereof, and communicating running tool sensor data to the blowout preventer assembly wireless interface through a fluid medium located between the running tool wireless interface and the blowout preventer assembly wireless interface.
  • the steps can also include providing the running tool having one or more running tool sensors positioned on the running tool.
  • the running tool sensor or sensors can include an azimuth sensor that provides a rotational azimuth of the running tool, a hydraulic function positive indicator sensor, a wellhead seal engagement pressure sensor, and/or a dog extension sensor.
  • the steps can correspondingly include determining running tool angular position, determining running tool alignment with respect to the wellhead, determining running tool hydraulic operation status, determining running tool setting loads imparted on a wellhead seal, and/or determining proper running tool dog engagement.
  • the steps can include providing a running tool having one or more running tool engagement sensors positioned on the running tool, determining the running tool's engagement status, and providing the running tool engagement data to the blowout preventer assembly wireless interface.
  • the running tool engagement status can include running tool rotational position, running tool alignment with respect to the wellhead, running tool hydraulic operation status, running tool setting loads imparted on a wellhead seal, and/or running tool dog engagement status.
  • the running tool has a hydraulic accumulator mounted to the running tool and at least one hydraulic valve mounted to the running tool to control fluid pressure between the hydraulic accumulator and a hydraulic function of the running tool.
  • the blowout preventer wireless interface is communicatively coupled to a subsea electronics module communicatively coupled to an umbilical extending to a surface platform, and the one or more tool engagement sensors includes a positive hydraulic function indicator sensor that provides data indicating operation of the hydraulic function of the running tool to a running tool controller.
  • the steps also include providing actuation commands to the at least one hydraulic valve to provide hydraulic pressure to the hydraulic function of the running tool responsive to control instructions provided by a platform operator and relayed through the subsea electronic module, blowout preventer wireless interface, and one or more components of the running tool wireless interface, to the running tool controller.
  • the running tool assembly includes an azimuth sensor that provides a rotational position of the running tool.
  • the step of communicating running tool sensor data to the blowout preventer assembly wireless interface includes communicating the rotational position of the running tool to the blowout preventer assembly wireless interface.
  • the steps can also include communicating the rotational position of the running tool to a surface platform operator control or monitoring unit through utilization of a subsea control module communicatively coupled to an umbilical extending to the surface platform.
  • the running tool wireless interface is configured to communicate the running tool sensor data to the blowout preventer wireless interface via RF communications through the fluid medium between antenna components thereof, mutual inductive coupling, backscatter coupling, and capacitive coupling.
  • the running tool wireless interface can include a running tool-mounted radiofrequency (RF) antenna positioned in contact with the fluid medium surrounding the running tool and the blowout preventer assembly wireless interface can include a blowout preventer member-mounted RF antenna positioned in contact with the fluid medium adjacent thereto.
  • the step of communicating running tool sensor data can include transmitting a data signal between the running tool-mounted RF antenna and the blowout preventer assembly member-mounted RF antenna through the fluid medium located therebetween.
  • the running tool wireless interface can include a running tool-mounted induction loop positioned in contact with the fluid medium surrounding the running tool and the blowout preventer assembly wireless interface can include a blowout preventer assembly member-mounted induction loop positioned in contact with the fluid medium adjacent thereto.
  • the step of communicating running tool sensor data can include positioning the running tool so that the running tool-mounted induction loop is axially positioned adjacent the blowout preventer assembly member-mounted induction loop, and inductively coupling the blowout preventer assembly member-mounted induction loop with the running tool-mounted induction loop when the running tool-mounted induction loop is axially adjacent the blowout preventer assembly member-mounted induction loop to provide the running tool sensor data to the blowout preventer assembly wireless interface.
  • the running tool wireless interface can include a running tool-mounted antenna positioned in contact with the fluid medium surrounding the running tool and the blowout preventer assembly wireless interface can include a blowout preventer assembly member-mounted antenna positioned in contact with the fluid medium adjacent thereto.
  • the step of communicating running tool sensor data can include reflecting, by the running tool wireless interface, a signal provided by the blowout preventer assembly wireless interface performed through the fluid medium between the running tool-mounted antenna and the blowout preventer assembly member-mounted antenna.
  • the running tool wireless interface can include a running tool-mounted electrode positioned in contact with the fluid medium surrounding the running tool and the blowout preventer assembly wireless interface can include a blowout preventer assembly member-mounted electrode positioned in contact with the fluid medium adjacent thereto.
  • the step of communicating running tool sensor data can include positioning the running tool so that the running tool-mounted electrode is axially positioned adjacent the blowout preventer assembly member-mounted electrode, and capacitively coupling the blowout preventer-mounted electrode with the running tool-mounted electrode when the running tool-mounted electrode is axially adjacent the blowout preventer- mounted electrode, forming an electric field therebetween to provide the running tool sensor data to the blowout preventer assembly wireless interface through the fluid medium between the respective electrodes.
  • Fig. 1 is a schematic representation of a subsea system according to an embodiment of the present invention.
  • FIG. 2 is a schematic representation of a blowout preventer assembly including a generic wireless BOP assembly interface according to an embodiment of the present invention, shown without a blowout preventer frame.
  • FIG. 3 is a schematic representation of a running tool assembly including a generic running tool assembly wireless interface according to an embodiment of the present invention shown without a blowout preventer frame.
  • Fig. 4A is a schematic representation of a running tool assembly including a running tool wireless interface configured to provide RF communications according to an embodiment of the present invention.
  • FIG. 4B is a schematic representation of a blowout preventer assembly including a blowout preventer wireless interface configured to receive and demodulate RF communications according to an embodiment of the present invention.
  • Fig. 4C is a schematic representation of the running tool wireless interface of the running tool assembly of Fig. 4A in RF communications with the blowout preventer wireless interface of the blowout preventer assembly of Fig. 4B according to an embodiment of the present invention.
  • Fig. 5A is a schematic representation of a running tool including a running tool wireless interface configured to provide for inductive coupling according to an embodiment of the present invention.
  • FIG. 5B is a schematic representation of a blowout preventer assembly including a blowout preventer wireless interface configured to receive and demodulate data provided through inductive coupling according to an embodiment of the present invention.
  • Fig. 5C is a schematic representation of the running tool wireless interface of the running tool assembly of Fig. 5 A in the near field communications (inductive coupling) with the blowout preventer wireless interface of the blowout preventer assembly of Fig. 5B according to an embodiment of the present invention.
  • Fig. 6A is a schematic representation of a running tool including a running tool wireless interface configured to provide for backscatter coupling according to an embodiment of the present invention.
  • FIG. 6B is a schematic representation of a blowout preventer assembly including a blowout preventer wireless interface configured to provide radiowave transmissions and to demodulate a modulated backscatter signal according to an embodiment of the present invention.
  • Fig. 6C is a schematic representation of the running tool wireless interface of the running tool assembly of Fig. 6A in far field (back scatter) communications with the blowout preventer wireless interface of the blowout preventer assembly of Fig. 6B according to an embodiment of the present invention.
  • Fig. 7A is a schematic representation of a running tool including a running tool wireless interface configured to provide for capacitive coupling according to an embodiment of the present invention.
  • FIG. 7B is a schematic representation of a blowout preventer assembly including a blowout preventer wireless interface configured to provide capacitively coupled transmissions and to receive a modulated data signal according to an embodiment of the present invention.
  • Fig. 7C is a schematic representation of the running tool wireless interface of the running tool assembly of Fig. 7A in capacitive communications with the blowout preventer wireless interface of the blowout preventer assembly of Fig. 7B according to an embodiment of the present invention.
  • Fig. 1 illustrates a subsea assembly 11 including a wellbore 13 located at a seafloor 15, and a subsea wellhead 17 position at an upper end of wellbore 13.
  • the wellhead 17 may include both a wellhead and a subsea tree.
  • a blowout preventer (BOP) assembly (stack) 19 is disposed on the wellhead 17.
  • a running string 21 used to run a subsea running tool 23 is shown suspended in/through a riser 26, the wellbore 13, and/or a bore extending through the wellhead 17.
  • the running string 21 extends from the platform 25 located at a sea surface to the subsea running tool 23.
  • the platform 25 may be a drilling rig that may conduct various operations to drill and complete a subsea well.
  • the subsea riser 26 generally extends between the BOP assembly 19 and the platform 25.
  • Other intermediate components as known to those of ordinary skill in the art, however, may be connected therebetween.
  • a central control unit (CCU) 27 is positioned on platform 25 and is communicatively coupled to a driller's control panel 29, a tool pusher's control panel, or other surface communication equipment.
  • CCU 27 is further communicatively coupled to a subsea electronics module (SEM) 31, for example, located on a frame of BOP assembly 19, by a communication umbilical 33 that extends on an exterior of subsea riser 26 to BOP assembly 19 to platform 25.
  • An umbilical reel (not shown) may be used to run communication umbilical 33 with running string 21 during running operations of subsea assembly 11.
  • SEM 31 can be positioned/connected at other locations.
  • the subsea well-to-surface communication can be through other means including various forms of wireless communication to include radiofrequency (RF) and/or acoustic.
  • RF radiofrequency
  • a typical BOP assembly 19 includes at least one shear ram assembly 35, three of which are shown, and at least one annular BOP assembly 37, two of which are shown.
  • the BOP assembly 19 includes a BOP assembly frame 39 that is mounted around the BOP assembly 19.
  • the BOP assembly frame 39 provides a mounting position for the SEM 31 (Fig. 1), as well as additional equipment such as hydraulic accumulators, and the like.
  • Hydraulic accumulators may provide hydraulic power for some subsea hydraulic components such as shear assemblies 35.
  • An operator may send signals from platform 25 through communication umbilical 33 to the SEM 31.
  • the signals may be operation signals that instruct shear assemblies 35, BOPs 37, and/or other subsea operations to operate.
  • the BOP assembly 19 also includes a subsea wellhead connector 43 and at least one wireless interface 45, three of which are shown, individually referred to as BOP assembly wireless interface 45.
  • the subsea wellhead connector 43 mounts to subsea wellhead 13.
  • the BOP assembly wireless interface or interfaces 45 may be mounted in any of the three positions shown in the figure, as well as others as would be known and understood by one of ordinary skill in the art. In the first position, a wireless interface 45 mounts to the wellhead connector 43 through an attachment fitting/connector 47. In the second position, a wireless interface 45 also or alternatively mounts through attachment fitting/connector 47 in a separate tubular member 49 positioned between wellhead connector 43 and the first shear assembly 35.
  • a wireless interface 45 also or alternatively mounts within a ram cavity of the first shear assembly 35.
  • a wireless interface 45 also or alternatively mounts within a ram cavity of the first shear assembly 35.
  • each of the one or more wireless interfaces 45 can be a similar configuration and/or provide different types of configurations to support different running tool configurations.
  • Each BOP assembly wireless interface 45 may be communicatively coupled to the SEM 31 (Fig. 1). In an embodiment, this is done through an electrical cable (not shown) mounted to BOP assembly frame 39 that extends from the mounting location of BOP assembly wireless interface 45 to SEM 31.
  • running string 21 and running tool 23 will be suspended within BOP assembly 19 so that running tool 23 may interact with subsea wellhead 17.
  • portions of interface 45 can be incorporated in one or more modules of the SEM 31 or provided as stand-alone units electrically/optically connected to the SEM 31.
  • running tool 23 is shown suspended by/on running string 21.
  • Running tool 23 can be in the form of a tubing hanger running tool, an internal tree cap running tool, a pressure test tool, a casing hanger running tool, a lead impression tool, a seal retrieval tool, or others as known to those of ordinary skill in the art.
  • the running tool 23 includes a running tool wireless interface 51 shown generically in Fig. 3.
  • Running tool 23 may also include hydraulic accumulators 57 and hydraulic valves 59.
  • running tool 23 may include a plurality of sensors 61.
  • the running tool wireless interface 51 is in communication with the fluid in the BOP assembly 19.
  • running tool wireless interface 51 may both receive data signals through, and transmit data signals into/through the column of fluid in the BOP assembly 19.
  • running tool wireless interface 51 may first receive a data signal transmitted through the column of fluid in the BOP assembly 19 via the BOP assembly wireless interface 45 also in communication with the fluid in the BOP assembly 19.
  • Running tool wireless interface 51 may then demodulate the received signal or provide the received signal to a separate controller, where the signal is processed.
  • the interface 51 or controller may then, in turn, communicate with the various functions of running tool 23 in response to the instructions provided in the received signal.
  • the interface 51 or controller may signal hydraulic valve 59 to allow hydraulic pressure from hydraulic accumulators 57 to flow and operate a function of running tool 23.
  • the interface 51 or controller 53 may also or alternatively receive signals from sensors 61. If the embodiment includes an intermediate controller, the controller may then process the sensor signals and transmit the sensor signals to running tool wireless interface 51.
  • the running tool wireless interface 51 transmits and/or modulates a signal including sensor data into the column of fluid in BOP assembly 19.
  • the sensor data signals provided by the wireless interface 51 is received by/through BOP assembly wireless interface 45.
  • BOP assembly wireless interface 45 may then pass the received signal or a data signal demodulated therefrom, to the appropriate equipment.
  • the controller can be part of the wireless interface 51 and/or an independent unit operably coupled to the wireless interface 51.
  • An operator located on platform 25 may require operation of a hydraulic function of running tool 23.
  • the operator may interact with DCP 29 (Fig. 1) to send a signal to CCU 27 (Fig. 1).
  • CCU 27 may then send a signal to SEM 31 through electrical umbilical 33.
  • SEM 31 can communicate the signal to BOP assembly wireless interface 45, where the signal may be converted, modulated and/or transmitted into the column of fluid within BOP assembly 19.
  • the running tool wireless interface 51 may then receive and/or demodulate the signal and provide the signal to a controller or provide a control signal for operation of hydraulic valves 59, for example, for release of hydraulic pressure within hydraulic accumulators 57.
  • one or more sensors 61 may transmit a signal corresponding to the amount of rotational movement of running tool 23 either directly to the wireless interface 51 or indirectly through a separate intermediate controller (not shown).
  • the sensor signal is then processed, and a corresponding data signal is transmitted and/or modulated to provide processed or unprocessed sensor data to the wireless BOP assembly interface 45 via the fluid in the BOP assembly 19.
  • the BOP assembly wireless interface 45 receives and/or demodulates the signal.
  • the signal may then be processed and provided to the surface through SEM 31, electrical umbilical 33, and CCU 27, where it may then be displayed to an operator on DCP 29.
  • the operator may then conduct an appropriate action in response. For example, if four rotations of running tool 23 at the subsea location are needed to perform the mechanical operation, the operator may add additional rotations at the surface to compensate for twisting of running string 21 that may have absorbed one of the rotations due to the length of running string 21 based on the information received from running tool 23.
  • sensor or sensors 61 may generate a signal in response to successful completion of a hydraulic operation by running tool 23, and/or sensor readings indicating that a casing hanger seal was successfully set or damaged. If damaged, the operator can forego initiating a pressure test, potentially further damaging seal and/or casing hanger.
  • Figs. 4A-7B various wireless communication schemes and associated components are provided according to various embodiments of the present invention.
  • Figs. 4A-4C illustrate an RF communications scheme.
  • the running tool wireless interface 71 includes a radio frequency (RF) antenna 73 positioned in contact with the fluid medium 75 surrounding the running tool 77, a controller-transceiver 79 operably coupled to the antenna 73 and to sensors 61, and a power supply 80.
  • RF radio frequency
  • Controller-transceiver 79 can take the form of two separate devices, a controller in communication with a transmitter or combination transmitter and receiver, or a single controller- transmitter/transceiver device as understood by those of ordinary skill in the art providing communication functions and/or control functions when so configured.
  • the power supply 80 of the running tool wireless interface can include various types understood by those of ordinary skill in the art. Examples include a battery source having sufficient charge to provide electric potential to the electrically operated devices/functions, negating any need for an additional external power source. In an exemplary embodiment, this includes providing power for operation of running tool RF receiver/controller 71, sensors 61, and/or hydraulic valves 59. A person skilled in the art will understand that these functions and components may comprise integral components of running tool 23. A person skilled in the art will also understand that these functions and components may comprise a separate module coupled to running tool 23. A person skilled in the art will further understand that running tool 23 may include various combinations of the components described above, selected to perform a particular function within subsea wellhead 17.
  • Each operationally functional electrical component may be communicatively coupled with the controller-transceiver 79 to both receive signals from and transmit signals to controller- transceiver 79.
  • receiver/controller 79 may transmit signals to hydraulic valves 59, causing hydraulic valves 59 to open or close in response.
  • sensors 61 may transmit signals to controller-transceiver 79 that provide measurements of selected parameters at the running tool 23.
  • at least one of the sensors 61 may be an azimuth sensor that provides heading information processed by the controller to indicate the number of turns running tool 23 may have undergone in response to rotation of running string 21 at platform 25.
  • Other sensors 61 may provide temperature, external/internal pressure, torque, axial position, tension, hydraulic function positive indicator, wellhead seal engagement pressure, and dog extension data, to the controller-transceiver 79.
  • Fig. 4B shows a complementary BOP assembly wireless interface 81 which includes an RF antenna 83 positioned in contact with the fluid medium 75 adjacent thereto, a controller- transceiver 85, and a power source (not shown).
  • Controller-transceiver 85 can take the form of two separate devices, a controller in communication with a receiver or combination transmitter and receiver, or a single device, along with other forms.
  • the RF antenna 83 is typically embedded flush within a recess 87 and is connected to the controller-transceiver 85 via a conductor 88 extending through a bore 89 extending radially through the tubular member 49.
  • Fig. 4C illustrates the running tool wireless interface 71 in RF communication with the BOP wireless interface 81 over/through the fluid medium 75 within the axial bore of the tubular member 49.
  • the controller-transceiver 79 receives sensor data signals from one or more sensors 61.
  • the controller-transceiver 79 can perform various functions with respect to sensor data to provide data indicating if the tool being run was successfully set and/or whether or not proper setting loads were imparted on.
  • Such functions can include, but are not limited to, determining running tool angular position, determining running tool alignment with respect to the wellhead, determining running tool hydraulic operation status, determining running tool setting loads imparted on a wellhead seal, and determining proper running tool dog engagement.
  • Figs. 5A-5C illustrate an inductive coupling communications scheme.
  • a running tool wireless interface 91 includes a running tool- mounted induction loop (i.e., antenna coil) 93 positioned in contact with the fluid medium 75 surrounding the running tool 97, and a controller 99 operably coupled to the induction loop 93.
  • the controller 99 is also operably coupled to the sensors 61 to collect and process the tool engagement and other tool data as described, for example, with respect to the embodiment shown in Fig. 4A and/or to provide control signals to the sensors 61 and/or one or more running tool components.
  • induction loop 93 can be in the form of a more localized coil antenna or set of localized coil antennas.
  • FIG. 5B shows a BOP wireless interface 101 configured to receive and demodulate data provided through inductive coupling.
  • Wireless interface 101 includes an induction loop 103 positioned in contact with the fluid medium 75 adjacent thereto, and a controller 105.
  • the induction loop 103 is typically embedded flush within a recess 107 and is connected to the controller 105 via a conductor 108 extending through a bore 109, itself extending through the tubular member 49.
  • induction loop 103 can be in the form of one or more coil antennas positioned within recess 107 are within a plurality of separate recesses.
  • Fig. 5C illustrates the running tool wireless interface 91 in near field communications (inductive coupling) with the BOP wireless interface 101 over/through the fluid medium 75 within the axial bore of the tubular member 49.
  • running tool wireless interface controller 99 "sends" its data by changing the load on the induction loop 93 which can be detected by the controller 105 of the BOP wireless interface 101.
  • Figs. 6A-6C illustrate a backscatter coupling communications scheme.
  • a running tool wireless interface 121 includes one or more spaced apart antennae (e.g., coils) 123 positioned in contact with the fluid medium 75 surrounding the running tool 127, and a controller 129 operably coupled to the one or more antenna 123.
  • the controller 129 is also operably coupled to the sensors 61 to collect and process the tool engagement and other tool data as described, for example, with respect to the embodiment shown in Fig. 4A and/or to provide control signals to the sensors 61 and/or one or more running tool components.
  • Fig. 6B shows a BOP wireless interface 131 configured to receive and demodulate data provided through backscatter coupling.
  • the wireless interface 131 includes an antenna 133 positioned in contact with the fluid medium 75 adjacent thereto, and a controller 135.
  • the antenna 133 is typically embedded flush within a recess 137 and is connected to the controller 135 via a conductor 138 extending through a bore 139, itself extending radially through the tubular member 49.
  • Fig. 6C illustrates the running tool wireless interface 121 in the far field communications (backscatter coupling) with the BOP wireless interface 131 over/through the fluid medium 75 within the axial bore of the tubular member 49.
  • the running tool wireless interface 121 is passive in that it receives power from the radio waves emanating from the antenna 133, reflecting back a modulated form of the received signal, but modulated or otherwise carrying running tool engagement and/or other sensor data gathered from one or more sensors 61. Active embodiments are, however, within the scope of the present invention.
  • Figs. 7A-7C illustrate a capacitive coupling communications scheme. As shown in Fig.
  • a running tool wireless interface 141 includes one or more spaced apart electrodes 143 positioned in contact with the fluid medium 75 (dielectric medium) surrounding the running tool 147, and a controller 149 operably coupled to the one or more electrodes 143.
  • the controller 149 is also operably coupled to the sensors 61 to collect and process the tool engagement and other tool data as described, for example, with respect to the embodiment shown in Fig. 4A and/or to provide control signals to the sensors 61 and/or one or more running tool components.
  • FIG. 7B shows a BOP wireless interface 151 configured to receive data provided through the capacitive coupling.
  • Wireless interface 151 includes an electrode 153 positioned in contact with the fluid medium 75 adjacent thereto, and a controller 155 operably coupled thereto.
  • the electrode 153 or electrodes is/are typically embedded flush within a recess 157 and is/are connected to the controller 155 via a conductor 158 extending through a bore 159, itself extending through the tubular member 49.
  • Fig. 7C illustrates the running tool wireless interface 141 in communications (capacitive coupling) with the BOP wireless interface 151 over/through the fluid medium 75 within the axial bore of the tubular member 49.
  • the electrodes 143, 157 function as plates of a capacitor positioned on either side of a dielectric medium (i.e., fluid medium 75), to, in essence, form a capacitor through which sensor data signals can be passed.
  • Methods for communicating between a surface platform 25 and a subsea running tool 23 disposed within a subsea wellhead 17, a blowout preventer assembly 39, or a combination thereof are also provided.
  • An example of such a method can include the steps of providing a running tool wireless interface 51 carried by a running tool 23, providing a blowout preventer assembly wireless interface 45 mounted to a member 35, 43, 49 of a blowout preventer assembly 39 or mounted to a subsea wellhead 17 connected with the blowout preventer assembly 39, positioning the running tool 23 within an axial bore of one or more members of the blowout preventer assembly 39, and/or an axial bore of the subsea wellhead 17, and communicating running tool sensor data to the blowout preventer assembly wireless interface 45 through a fluid medium 75 located between the running tool wireless interface 51 and the blowout preventer assembly wireless interface 45.
  • the steps can also include providing the running tool 23 having one or more running tool sensors 61 positioned on the running tool 23.
  • the running tool sensor or sensors 61 can include an azimuth sensor that provides a rotational azimuth of the running tool, a hydraulic function positive indicator sensor, a wellhead seal engagement pressure sensor, and/or a dog extension sensor.
  • the steps can correspondingly include determining running tool angular position, determining running tool alignment with respect to the wellhead, determining running tool hydraulic operation status, determining running tool setting loads imparted on a wellhead seal, and/or determining proper running tool dog engagement.
  • the steps can include providing a running tool 23 having one or more running tool engagement sensors represented by 61 positioned on the running tool 23, determining the running tool's engagement status, and providing the running tool engagement data to the blowout preventer assembly wireless interface 45.
  • the running tool engagement status can include running tool rotational position, running tool alignment with respect to the wellhead, running tool hydraulic operation status, running tool setting loads imparted on a wellhead seal, and/or running tool dog engagement status.
  • the running tool 23 has a hydraulic accumulator 57 mounted to the running tool 23 and at least one hydraulic valve 59 mounted to the running tool 23 to control fluid pressure between the hydraulic accumulator 57 and a hydraulic function of the running tool 23.
  • the blowout preventer wireless interface 45 is communicatively coupled to a subsea electronics module 31 communicatively coupled to an umbilical 33 extending to a surface platform 25 (at central control unit 27), and the one or more tool engagement sensors represented at 61 includes a positive hydraulic function indicator sensor that provides data indicating operation of the hydraulic function of the running tool 23 to a running tool controller.
  • the steps also include providing actuation commands to the at least one hydraulic valve 59 to provide hydraulic pressure to the hydraulic function of the running tool 23 responsive to control instructions provided by a platform operator and relayed through the subsea electronic module 31, blowout preventer wireless interface 45, and one or more components of the running tool wireless interface 51, to the running tool controller.
  • the running tool assembly includes an azimuth sensor 61 that provides a rotational position of the running tool 23.
  • the step of communicating running tool sensor data to the blowout preventer assembly wireless interface 45 includes communicating the rotational position of the running tool 23 to the blowout preventer assembly wireless interface 45.
  • the steps can also include communicating the rotational position of the running tool 23 to a surface platform operator control or monitoring unit 29 through utilization of a subsea control module 31 communicatively coupled to an umbilical 33 extending to the central control unit 27 on the surface platform 27.
  • the running tool wireless interface 45 is configured to communicate the running tool sensor data to the blowout preventer wireless interface via RF communications through the fluid medium 75 between antenna components thereof, mutual inductive coupling, backscatter coupling, and capacitive coupling.
  • a running tool wireless interface 71 can include a running tool-mounted radiofrequency (RF) antenna 73 positioned in contact with the fluid medium 75 surrounding the running tool 23 and the blowout preventer assembly wireless interface 81 can include a blowout preventer member-mounted RF antenna 83 positioned in contact with the fluid medium 75 adjacent thereto.
  • the step of communicating running tool sensor data can include transmitting a data signal between the running tool-mounted RF antenna 73 and the blowout preventer assembly member-mounted RF antenna 83 through the fluid medium 75 located therebetween.
  • a running tool wireless interface 91 can include a running tool-mounted induction loop 93 positioned in contact with the fluid medium 75 surrounding the running tool 23 and the blowout preventer assembly wireless interface 101 can include a blowout preventer assembly member-mounted induction loop 103 positioned in contact with the fluid medium 75 adjacent thereto.
  • the step of communicating running tool sensor data can include positioning the running tool 97 so that the running tool-mounted induction loop 93 is axially positioned adjacent the blowout preventer assembly member-mounted induction loop 103, and inductively coupling the blowout preventer assembly member-mounted induction loop 103 with the running tool-mounted induction loop 93 when the running tool-mounted induction loop 93 is axially adjacent the blowout preventer assembly member-mounted induction loop 103 to provide the running tool sensor data to the blowout preventer assembly wireless interface 101.
  • the running tool wireless interface 121 can include a running tool-mounted antenna or antennae 123 positioned in contact with the fluid medium 75 surrounding the running tool 127 and the blowout preventer assembly wireless interface 131 can include a blowout preventer assembly member-mounted antenna 133 or antennae positioned in contact with the fluid medium 75 adjacent thereto.
  • the step of communicating running tool sensor data can include reflecting, by the running tool wireless interface 121, a signal provided by the blowout preventer assembly wireless interface 131 performed through the fluid medium 75 between the running tool-mounted antenna or antennae 123 and the blowout preventer assembly member-mounted antenna 133 or antennae.
  • the running tool wireless interface 141 can include a running tool-mounted electrode or electrodes 143 positioned in contact with the fluid medium 75 surrounding the running tool 147 and the blowout preventer assembly wireless interface 151 can include a blowout preventer assembly member-mounted electrode 153 or electrodes positioned in contact with the fluid medium 75 adjacent thereto.
  • the step of communicating running tool sensor data can include positioning the running tool 147 so that at least one of the running tool-mounted electrodes 143 is axially positioned adjacent the blowout preventer assembly member-mounted electrode 153, and capacitive ly coupling the blowout preventer-mounted electrode 153 with the respective running tool-mounted electrode 143 when the running tool-mounted electrode 143 is axially adjacent the blowout preventer-mounted electrode 153, forming an electric field therebetween to provide the running tool sensor data to the blowout preventer assembly wireless interface 151 through the fluid medium 75 between the respective electrodes 143, 153.
  • the disclosed embodiments provide numerous advantages.
  • the disclosed embodiments provide a system for wireless communication between a running tool located subsea and an operator located on a sea surface. This allows communication of instructions downhole to the running tool for operation of hydraulic functions without the need for a hydraulic or electric umbilical.
  • the system provides a means to communicate information from the subsea location to the surface with sufficient speed to allow the operator to adjust running tool operations/positioning at the surface to account for conditions at the subsea location.
  • the communication system employs existing umbilicals and subsea electronics modules to operate and/or monitor the functions of the running tool. This allows operators to gain additional functionality out of these apparatuses that are typically only used to control the subsea BOP.
  • the existing umbilicals and subsea electronics modules can be used to operate the subsea BOP, and a subsea running tool disposed within and adjacent the BOP assembly.
  • Various embodiments of the present invention advantageously employ an RF, inductive (near field), backscatter (far field), and/or capacitive communications scheme or schemes to provide data from running tools that run in/through the bore of the BOP or adjacent members, to the BOP communication system.
  • the running tool is equipped with technology to transmit or otherwise transfer the data either via an RF or RF-backscatter signal that goes across the space between running tool and BOP or with an inductive or capacitive type coupler, to span the gap.
  • the gap between tool and BOP or other tubular member is generally filled with mud or fluid.
  • the BOP or adjacent components of the BOP assembly can include the communication interface (e.g., RF antenna, induction loop/antenna, electrodes, etc.) to receive the data from the tool.
  • the BOP communication system can then communicate the data to the surface via the subsea-surface communication network.
  • the running tool can advantageously incorporate sensors to detect desired data, such as, for example, data indicating if the tool being run was successfully set and/or whether or not proper setting loads were imparted on hanger seals. If not, then the well owner can be informed that he/she should forgo pressure testing, saving time and money. If the running tool is one that is configured to reset the seal, then the running tool can be instructed to perform such tasks, negating the need for a separate trip in and out of the well hole, saving additional time and money. With the combination of sensors on the running tool recording real-time tool conditions, and the above described subsea communications technology, the rig operator can advantageously receive virtually instant feedback on the success of the running operation.
  • desired data such as, for example, data indicating if the tool being run was successfully set and/or whether or not proper setting loads were imparted on hanger seals. If not, then the well owner can be informed that he/she should forgo pressure testing, saving time and money. If the running tool is one that is configured to reset the seal,
  • the rig operator has to pull the string and inspect the lead indicators on the running tool, which can take hours and cost thousands of dollars, just to determine what has happened or whether or not a malfunction has occurred.
  • the quicker feedback can enable the rig operator to more expeditiously respond to the success or failure, saving time and money.
  • one or more embodiments of the present invention can provide for employment of a direct contact between a communication components of the running tool and corresponding communication components of the BOP assembly and/or inner surface portions of a member of the BOP assembly to form a contact-based communication circuit to provide for data communications therebetween. Data could then be transmitted acoustically, electronically, electrically, or inductively through the solid connection between the running tool and the BOP.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Remote Sensing (AREA)
  • Geophysics (AREA)
  • Electromagnetism (AREA)
  • Earth Drilling (AREA)
  • Arrangements For Transmission Of Measured Signals (AREA)

Abstract

La présente invention se rapporte à des systèmes et à des procédés permettant une communication entre un outil de pose sous-marin disposé dans une tête de puits sous-marine, un ensemble bloc d'obturation de puits et/ou une tête de production sous-marine, et une plate-forme en surface. Un exemple d'un tel système comprend un ensemble outil de pose. L'ensemble outil de pose peut comprendre un outil de pose et une interface sans fil d'outil de pose supportée par l'outil de pose. L'interface sans fil est configurée pour communiquer des données de capteur d'outil de pose à une interface sans fil d'ensemble bloc d'obturation de puits à travers un milieu fluide situé entre l'interface sans fil d'outil de pose et une interface sans fil d'ensemble bloc d'obturation de puits lorsque l'outil de pose est positionné de manière fonctionnelle dans un alésage qui s'étend à travers un composant de l'ensemble bloc d'obturation de puits ou un alésage qui s'étend à travers la tête de puits sous-marine. Le schéma de communication sans fil destiné à communiquer des données avec un capteur peut comprendre des communications radiofréquences à travers le milieu fluide entre des composants d'antenne de ce dernier, un couplage inductif mutuel, un couplage par rétrodiffusion et/ou un couplage capacitif.
PCT/US2013/067934 2012-11-16 2013-11-01 Système intelligent de pose de tête de puits et outil de pose WO2014078094A2 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
SG11201503530SA SG11201503530SA (en) 2012-11-16 2013-11-01 Intelligent wellhead running system and running tool
GB1508484.1A GB2523680A (en) 2012-11-16 2013-11-01 Intelligent wellhead running system and running tool
NO20150546A NO20150546A1 (en) 2012-11-16 2015-05-05 Intelligent wellhead running system and running tool

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/679,789 2012-11-16
US13/679,789 US20130088362A1 (en) 2011-09-29 2012-11-16 Intelligent wellhead running system and running tool

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WO2014078094A2 true WO2014078094A2 (fr) 2014-05-22
WO2014078094A3 WO2014078094A3 (fr) 2014-12-31

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US10253582B2 (en) 2012-05-14 2019-04-09 Dril-Quip, Inc. Riser monitoring and lifecycle management system and method
US11414937B2 (en) 2012-05-14 2022-08-16 Dril-Quip, Inc. Control/monitoring of internal equipment in a riser assembly

Also Published As

Publication number Publication date
SG11201503530SA (en) 2015-06-29
WO2014078094A3 (fr) 2014-12-31
GB201508484D0 (en) 2015-07-01
NO20150546A1 (en) 2015-05-05
GB2523680A (en) 2015-09-02

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