US20110266002A1 - Subsea Control Module with Removable Section - Google Patents

Subsea Control Module with Removable Section Download PDF

Info

Publication number
US20110266002A1
US20110266002A1 US12/816,901 US81690110A US2011266002A1 US 20110266002 A1 US20110266002 A1 US 20110266002A1 US 81690110 A US81690110 A US 81690110A US 2011266002 A1 US2011266002 A1 US 2011266002A1
Authority
US
United States
Prior art keywords
fixed part
removable section
control module
valve
subsea
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US12/816,901
Other languages
English (en)
Inventor
Hardev Singh
David Dietz, JR.
Luis Melendez
Dat Nguyen
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Hydril USA Distribution LLC
Original Assignee
Hydril USA Manufacturing LLC
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 Hydril USA Manufacturing LLC filed Critical Hydril USA Manufacturing LLC
Priority to US12/816,901 priority Critical patent/US20110266002A1/en
Assigned to HYDRIL USA MANUFACTURING LLC reassignment HYDRIL USA MANUFACTURING LLC ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: DIETZ, DAVID, JR., Melendez, Luis, NGUYEN, DAT, SINGH, HARDEV
Priority to SG2013079165A priority patent/SG195600A1/en
Priority to AU2011201784A priority patent/AU2011201784A1/en
Priority to EP11164033.0A priority patent/EP2383427A3/de
Priority to BRPI1101603-5A priority patent/BRPI1101603A2/pt
Publication of US20110266002A1 publication Critical patent/US20110266002A1/en
Abandoned legal-status Critical Current

Links

Images

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
    • E21B33/0355—Control systems, e.g. hydraulic, pneumatic, electric, acoustic, for submerged well heads
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/037—Protective housings therefor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/038—Connectors used on well heads, e.g. for connecting blow-out preventer and riser
    • E21B33/0385—Connectors used on well heads, e.g. for connecting blow-out preventer and riser electrical connectors
    • 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

Definitions

  • Embodiments of the subject matter disclosed herein generally relate to methods and systems and, more particularly, to mechanisms and techniques for removing and/or replacing a section of a subsea control module.
  • FIG. 1 illustrates a lower blowout preventer stack (“lower BOP stack”) 10 that may be rigidly attached to a wellhead 12 upon the sea floor 14 , while a Lower Marine Riser Package (“LMRP”) 16 is retrievably disposed upon a distal end of a marine riser 18 , extending from a drill ship 20 or any other type of surface drilling platform or vessel.
  • the LMRP 16 may include a stinger 22 at its distal end configured to engage a receptacle 24 located on a proximal end of the lower BOP stack 10 .
  • the lower BOP stack 10 may be rigidly affixed atop the subsea wellhead 12 and may include (among other devices) a plurality of ram-type blowout preventers 26 useful in controlling the well as it is drilled and completed.
  • the flexible riser provides a conduit through which drilling tools and fluids may be deployed to and retrieved from the subsea wellbore.
  • the LMRP 16 may include (among other things) one or more ram-type blowout preventers 28 at its distal end, an annular blowout preventer 30 at its upper end, and a MUX pod (in reality two, which are referred to in the industry as blue and yellow pods) 32 .
  • the ram-type blowout preventers of the LMRP 16 and the lower BOP stack 10 may be closed and the LMRP 16 may be detached from the lower BOP stack 10 and retrieved to the surface, leaving the lower BOP stack 10 atop the wellhead.
  • a conventional MUX pod system 40 is shown in FIG. 2 and may provide between 50 and 100 different functions to the lower BOP stack and/or the LMRP and these functions may be initiated and/or controlled from or via the LMRP.
  • the MUX pod 40 is fixedly attached to a frame (not shown) of the LMRP and may include hydraulically activated valves 50 (called in the art sub plate mounted (SPM) valves) and solenoid valves 52 that are fluidly connected to the hydraulically activated valves 50 .
  • the solenoid valves 52 are provided in an electronic section 54 and are designed to be actuated by sending an electrical signal from an electronic control board (not shown). Each solenoid valve 52 is configured to activate a corresponding hydraulically activated valve 50 .
  • the MUX pod 40 may include pressure sensors 56 also mounted in the electronic section 54 .
  • the hydraulically activated valves 50 are provided in a hydraulic section 58 and are fixedly attached to the MUX pod 40 (i.e., a ROV vehicle cannot remove them when the same is disposed on the seafloor).
  • multiplex (“MUX”) cables electrical
  • lines hydroaulic
  • transport control signals via the MUX pod and the pod wedge
  • MUX multiplex
  • subsea control valves are activated and (in most cases) high-pressure hydraulic lines are directed to perform the specified tasks.
  • a multiplexed electrical or hydraulic signal may operate a plurality of “low-pressure” valves to actuate larger valves to communicate the high-pressure hydraulic lines with the various operating devices of the wellhead stack.
  • a bridge between the LMRP 16 and the lower BOP stack 10 is formed that matches the multiple functions from the LMRP 16 to the lower BOP stack 10 , e.g., fluidly connects the SMP valves 50 from the MUX pod provided on the LMRP to dedicated components on the BOP stack or the LMRP.
  • the MUX pod system is used in addition to choke and kill line connections (not shown) or lines that ensure pressure supply to, for example, the shearing function of the BOPs.
  • the bridge is shown in FIG. 3 and may include a pod wedge 42 configured to engage a receiver 44 on the BOP stack.
  • the pod wedge 42 has plural holes (not shown), depending on the number of functions provided, that provide various hydraulic and/or electrical signals from the LMRP 16 to the lower BOP stack 10 .
  • the pod wedge 42 is designed with a given number of functions (holes) and after being deployed, the MUX pod system cannot be modified to handle more functions.
  • Examples of communication lines bridged between LMRPs and lower BOP stacks through feed-thru components include, but are not limited to, hydraulic choke lines, hydraulic kill lines, hydraulic multiplex control lines, electrical multiplex control lines, electrical power lines, hydraulic power lines, mechanical power lines, mechanical control lines, electrical control lines, and sensor lines.
  • subsea wellhead stack feed-thru components include at least one MUX pod connection whereby a plurality of hydraulic control signals are grouped together and transmitted between the LMRP 16 and the lower BOP stack 10 in a single mono-block feed-thru component as shown, for example, in FIG. 3 .
  • U.S. Pat. No. 7,216,714 uses a control module 60 (shown in FIG. 4 , which corresponds to FIG. 5 of U.S. Pat. No. 7,216,714) that combines a pilot valve (solenoid valve) 62 with a hydraulically activated valve 64 , both disposed in a single casing 66 .
  • the control module 60 has a connector 68 that connects to a receiver 70 that is fixedly attached to the BOP stack.
  • the entire control module 60 may be detached from receiver 70 and brought to the surface for repair by use of a Remotely Operated Vehicle (ROV).
  • ROV Remotely Operated Vehicle
  • a subsea device that is configured to control a subsea well.
  • the subsea device includes a frame; a blowout preventer connected to the frame and configured to close a bore that fluidly communicates with the subsea well; a pressure supply line connected to the frame and configured to provide a fluid under pressure; a control module connected to the frame and configured to receive the fluid from the pressure supply line and to control a distribution of the fluid to various functions, the control module including a fixed part and a removable section.
  • the fixed part has a valve manifold that houses a hydraulic activated valve and the removable section is configured to detachably attach to the fixed part and includes an electrically activated valve.
  • the hydraulic activated valve of the fixed part is configured to be actuated by the electrically activated valve when the removable section is mated to the fixed part.
  • control module configured to control various elements of a subsea device attached to a subsea well.
  • the control module includes a fixed part attached to a frame of the subsea device, the fixed part having a valve manifold that includes a hydraulic activated valve; and a removable section being configured to be removably attached to the fixed part and including an electrically activated valve.
  • the fixed part is configured to receive a fluid under pressure from a pressure supply line and to distribute the fluid under pressure to the hydraulic activated valve and the electrically activated valve.
  • the hydraulic activated valve of the fixed part is configured to be actuated by the electrically activated valve when the removable section is mated to the fixed part.
  • the removable section is configured to receive electrical signals for controlling the electrically activated valve.
  • a method for assembling a control module having a fixed part and a removable section includes attaching the control module to a frame; connecting the fixed part of the control module to a pressure supply line for receiving a fluid under pressure; providing a valve manifold that houses a hydraulic activated valve in the fixed part; detachably attaching the removable section of the control module to the fixed part; fluidly connecting an electrically activated valve of the removable section to the hydraulic activated valve such that the electrically activated valve controls the hydraulic activated valve; and electrically connecting the electrically activated valve to a control system.
  • a subsea blowout preventer stack that is configured to control a subsea well.
  • the stack includes a frame; plural blowout preventers connected to the frame and configured to close a bore that fluidly communicates with the subsea well; a pressure supply line connected to the frame and configured to provide a fluid under pressure; a control module connected to the frame and configured to receive the fluid from the pressure supply line and to distribute the fluid to control various functions of the subsea device, the control module including a fixed part and a removable section; the fixed part having a valve manifold that houses a hydraulic activated valve; and the removable section being configured to detachably attach to the fixed part and including an electrically activated valve.
  • the hydraulic activated valve of the fixed part is configured to be actuated by the electrically activated valve when the removable section is mated to the fixed part.
  • FIG. 1 is a schematic diagram of a conventional offshore rig
  • FIG. 2 is a schematic diagram of a MUX pod
  • FIG. 3 is a schematic diagram of a feed-thru connection of a MUX pod attached to a subsea structure
  • FIG. 4 is a schematic diagram of a conventional control module that includes both hydraulic and solenoid retrievable valves
  • FIG. 5 is a schematic diagram of a BOP stack having a control module according to an exemplary embodiment
  • FIG. 6 is a schematic diagram of an LMRP having a MUX pod
  • FIG. 7 is a schematic diagram of a control module having a removable section according to an exemplary embodiment
  • FIG. 8 is a schematic diagram of a removable section of a control module according to an exemplary embodiment
  • FIG. 9 is a schematic diagram of a control module according to an exemplary embodiment.
  • FIG. 10 is a schematic diagram of a control module provided on a BOP stack according to an exemplary embodiment
  • FIG. 11 is an overall view of a control module according to an exemplary embodiment
  • FIG. 12 is an overall view of a fixed part of a control module according to an exemplary embodiment
  • FIG. 13 is an overall view of a removable section of a control module according to an exemplary embodiment
  • FIG. 14 is a schematic diagram of a control module according to an exemplary embodiment
  • FIG. 15 is a schematic diagram of a control module having a detachable part according to an exemplary embodiment.
  • FIG. 16 is a flow chart illustrating a method for assembling a control module according to an exemplary embodiment.
  • a subsea structure is operated by providing a first predetermined number of functions. These functions are achieved by actuating hydraulically activated valves (SPM valves).
  • a hydraulically activated valve is controlled by a pilot valve, which may be an electrically activated valve.
  • a fixed part of a control module is configured to include the hydraulically activated valves while a removable section is configured to include the electrically activated valves. The fixed part is fixedly attached to the subsea structure while the removable section is detachably attached to the fixed part.
  • the separation of the two types of valves may offer the operator of the subsea structure the possibility to remove with a ROV only the electrically activated valves (the removable section) and not the hydraulically activated valves (the fixed part).
  • control module discussed above is capable of augmenting the number of functions already provided by a dedicated MUX pod.
  • a MUX pod may be a standard piece of equipment for an LMRP.
  • the MUX pod has a dedicated number of functions that are customized for each user. After being deployed on the subsea structure, the MUX pod ability to increase the provided number of functions is limited because of the connection between the BOP stack and the LMRP (see FIG. 3 ).
  • the above discussed control module is also capable of extending the number of functions to be implemented at the subsea structure.
  • FIG. 5 shows a BOP stack 80 .
  • the BOP stack 80 includes a frame 82 to which one or more BOPs ( 84 and 86 ) are attached.
  • a BOP stack may include other elements, e.g., hydraulic accumulators, hydraulic filters, electronic vessels, communication lines, power supply lines, pressure sensors, position sensors, choke and kill valves, shear valves, etc.
  • the LMRP may also include the elements noted above.
  • An LMRP 88 is shown in FIG. 6 .
  • the LMRP 88 may include a MUX pod 89 that is fixed to a frame 91 of the LMRP 88 .
  • the LMRP 88 includes two MUX pods.
  • the MUX pod 89 is configured to receive hydraulic pressure at an inlet 90 and electric power/communication signals at a connection 92 .
  • Various functions are controlled by the MUX pod 89 , which acts as the brain of the BOP 80 stack and/or LMRP 88 .
  • a new control module 94 may be added to the BOP stack 80 .
  • the BOP stack is used to describe the exemplary embodiments, but it should be understood that the same applies to the LMRP or other structures.
  • FIG. 5 shows two new control modules 94 and 96 being added to the BOP stack 80 .
  • the number of control modules to be added depends on the desired number of functions to be added and also on the number of functions available at the new control module. In one application, the control module 94 has 8 new functions. However, this number can be smaller or larger depending on the needs of the BOP stack operator, the space available, etc.
  • the control modules 94 and 96 may be fixed to their own frame 98 that is attached to the BOP stack's frame 82 as shown in FIG. 5 .
  • FIG. 7 shows in more details the control module 94 .
  • Control module 94 includes a fixed part 100 that is fixedly attached to the frames 82 or 98 .
  • the fixed part 100 may include a valve manifold 102 having plural hydraulic fluid ports 104 that connect to the various functions that are desired to be implemented and controlled.
  • the valve manifold 102 is configured to house a predetermined number of hydraulically activated valves (SPM valves) 106 .
  • FIG. 7 shows 8 SPM valves 106 but a different number may be used.
  • the SPM valves 106 are fixedly attached to the valve manifold 102 and they are configured to control a fluid flow to the fluid ports 104 .
  • a SPM valve 106 is hydraulically activated, e.g., it needs a supply of a fluid under pressure to open or close the valve.
  • the SPM valve controls the flow of a fluid under pressure there through by receiving the supply of a hydraulic fluid under pressure at a gate of the SPM valve.
  • the supply of fluid under pressure is provided by a corresponding pilot valve 108 , which is better seen in FIG. 8 .
  • the pilot valve 108 may be an electrically activated valve.
  • An electrically activated valve is a valve that controls a fluid flow based on electrical signals.
  • An example of an electrically activated valve is a solenoid valve.
  • the pilot valves 108 are located in a removable section 110 that is configured to be detachably attached to the fixed part 100 .
  • the removable section 110 may include a connecting device 112 (see FIG. 7 ) that is configured to be handled by the ROV vehicle when the removable section 110 needs to be removed.
  • the shape and size of the connecting device 112 depends on an existing tool on the ROV vehicle or other considerations of the operator.
  • the connecting device is a bucket as shown in FIG. 14 .
  • the removable section 110 may include guides 113 that mate with corresponding guides 114 on the fixed part 100 . The guides may be used by the ROV vehicle when mating the removable section 110 to the fixed part 100 .
  • the removable section 110 may also include a fitting 116 (as shown in FIG. 8 ) that connects the pilot valve 108 to the SPM valve 106 , a power and communication board 118 that is configured to receive the electric communications and/or a power supply and a communication connection 122 , e.g., a wet-mate electrical connector that is configured to communicate to the MUX pod 60 and to distribute the power and/or signals to corresponding pilot valves 108 and pressure sensing devices (not shown).
  • FIG. 8 also shows a ROV handle port 120 corresponding to the connecting device 112 and the wet-mate electrical connector 122 that is configured to connect to a corresponding wet-mate connector on the fixed part for receiving the electrical signals and/or power supply from the MUX pod 60 .
  • a cavity 124 may be present inside the removable section 110 that accommodates the power and communication board 118 .
  • the cavity 124 may be maintained at a pressure around atmospheric pressure so as to protect the electrical components when the high pressures undersea are exerted on the removable section.
  • cavity 124 may be filled with a non-conducting fluid maintained at ambient subsea pressure (using, for example, a compensator) at a given subsea depth at which the control module is installed.
  • the pilot valves 108 and the associated electronics may be separated from the SPM valves 106 and thus, in case of failure of a pilot valve or an electronic component, only these elements are retrieved and not the SPM valves. For this reason, the weight and size of the removed part is considerable less than the weight and size of the entire unit, which makes the replacement more feasible.
  • FIG. 9 shows an implementation of the fixed part 100 and the removable section 110 on the LMRP 130 . That means that the MUX pod 60 and the fixed part 100 are fixed to the LMRP 130 .
  • the removable section 110 is removably attached to the fixed part 100 .
  • the fixed part 100 includes one or more SPM valves 106 (only one is shown for simplicity).
  • the high pressure fluid is received via conduit 132 to a first input 106 a of the SPM valve 106 .
  • SPM valve 106 has inputs and outputs 106 a to 106 f. SPM valves 106 with other configurations may be used.
  • SPM valve 106 is activated by receiving the fluid under high pressure at gate 106 g. This fluid is controlled by pilot valve 108 provided in the removable section 110 . Pilot valve 108 may have a similar structure as the SPM valve 106 except that an electrical gate 108 a is used to activate the valve. The pilot valve 108 may receive the fluid under pressure from the same conduit 132 used by the SPM valve 106 or another hydraulic source. Thus, connections 134 a and 134 b are implemented on the fixed part 100 and the removable section 110 , respectively, for bringing the fluid under pressure to the pilot valve 108 .
  • connections 136 a and 136 b are used for providing the fluid under pressure from the pilot valve 108 to the SPM valve 106 when a corresponding electrical signal is received at gate 108 a.
  • the pilot valve 108 when the pilot valve 108 is activated, the fluid from conduit 132 flows via the pilot valve 108 to the gate 106 g to activate the SPM valve 106 .
  • the SPM valve gate 106 g After the SPM valve gate 106 g is activated, fluid from conduit 132 flows via SPM valve 106 to outlet 138 and to the desired function to be controlled.
  • the fluid under pressure entering conduit 132 may be provided either directly from MUX pod 60 along a conduit or from another source, e.g., hot line 144 .
  • the fluid may be regulated internally at the MUX pod 60 .
  • the hot line 144 may be connected to accumulators or to a conduit that communicates with the ship (not shown) manning the operation of the LMRP.
  • the removable section 110 may include more than one pilot valve 108 .
  • the removable section 110 also includes an electronic part 118 that is electrically connected to the pilot valves for transmitting various commands to them.
  • the electronic part 118 may be connected to power supply lines 140 a and 140 b that are connected to the MUX pod 60 via the fixed part 100 .
  • the electronic part 118 may include one or more lines 142 (e.g., RS 485 cables) for transmitting various commands from the MUX pod 60 to the corresponding solenoid valves 108 via the fixed part 100 .
  • Corresponding wet-mateable electric connectors 145 may be mounted on the fixed part 100 and the removable section 110 for transmitting the electric power and the commands from one module to the other.
  • Multiple fixed parts 100 and corresponding removable sections 110 may be used on the same subsea structure.
  • each pilot valve 148 would have its own output 150 fluidly communicating with a corresponding SPM valve 152 .
  • the conduit 146 may be connected to another source of fluid under pressure instead of the MUX pod 60 or conduit 144 .
  • the removable section 110 may include other elements than those shown in the figures.
  • the removable section 110 may include one or more filtration devices, pressure sensing devices, etc.
  • the fixed part may include other devices, e.g., pressure regulators.
  • the power supply and the communication supply may stay the same, e.g., from MUX pod 60 , but the hydraulic supply may provided by a hot line that provides the fluid under high pressure for operating the BOPs of the BOP stack.
  • FIG. 10 illustrates a possible hydraulic and electrical arrangement for the fixed part 100 and the removable section 110 when the control module is provided on the BOP stack.
  • a 5,000 psi yellow line 160 and a 5,000 psi blue line 162 are provided from the LMRP part to the BOP stack.
  • the received fluid may be filtered in a filtration unit 164 prior to being provided as the hydraulic supply for the removable section 110 .
  • Various pressure regulators 166 devices for changing the pressure of the fluid from, for example, 5,000 psi to 3,000 psi or another desired value may be used either to change the pressure of the fluid.
  • Both lines are provided to the fixed part 100 at inlets 168 and 170 .
  • the pilot hydraulic pressure at inlet 170 is provided via conduit 146 to the removable section 110 while the hydraulic pressure at inlet 168 is provided to SPM valves 106 .
  • the pilot valves 108 via commands received at the electronic part 118 along a power and communication line 172 , corresponding SPM valves 106 are opened or closed as required to provide the desired functions.
  • the pressure values illustrated in FIG. 10 are for exemplary purposes and not intended to limit the applicability of the novel features. Other pressure values may be used depending on the BOP stack and other factors.
  • the LMRP 88 is shown detached from the BOP stack 80 . However, after the fluid connection is achieved between the two parts, the yellow and blue lines are active and fluid under high pressure is available to the BOP stack from the LMRP.
  • a stack of accumulators 180 may be present on the BOP stack and connected to the blue and/or yellow lines to be recharged.
  • Pressure regulator 166 reduces the pressure to 4,000 psi for the shearing function at conduit 182 while the same fluid is provided along conduit 184 either to the fixed part 100 or via another pressure regulator 186 to the fixed part 100 .
  • the fixed part 100 and the removable section 110 may be connected to a frame 98 that has multiple slots for accommodating these elements.
  • FIG. 11 shows an empty slot 187 for receiving another control module 94 .
  • Frame 98 also may include a docking receptacle 188 (e.g., a hole in the frame, a stab or other elements) for helping the ROV device to dock in order to access the removable section 110 .
  • a docking receptacle 188 e.g., a hole in the frame, a stab or other elements
  • FIG. 12 shows in more details the fixed part 100 associated with the embodiment illustrated in FIG. 11 .
  • the fixed part includes guiding elements 114 that are configured to mate with corresponding elements on the removable section 110 .
  • the wet-mate connector 122 is provided on the fixed part 100 for providing power supply and/or communication signals to the removable section 110 .
  • a hydraulic fluid under pressure is provided to the removable section 110 through an outlet 143 .
  • the SPM valves 106 are attached to a base 191 of the fixed part 100 . Hydraulic stabs 136 a are connected to the SPM valves 106 and are configured to connect to the pilot valves of the removable section.
  • a hydraulic supply 193 provides the fluid under pressure to the fixed part 100 and part of this supply is provided to the desired functions along ports 195 when corresponding SPM valves 106 are actuated.
  • FIG. 13 shows an overall view of the control module 94 in which the removable section 110 is coupled to the fixed part 100 .
  • FIG. 13 shows the connecting element 112 including a low torque handle 112 a. By rotating the handle 112 a in one direction the removable section 110 is locked to the fixed part 100 and by rotating the handle 112 a in the opposite direction the two components are unlocked.
  • Another handle 112 b may be provided for transporting the removable section.
  • handle 112 is optional and a same handle may be used to lock/unlock and transport the removable section.
  • FIG. 13 also shows a wet-mate electrical connector 123 configured to connect to wet-mate connector 122 on the fixed part 100 .
  • the cavity 124 of the removable section 110 accommodates the electronics 118 . Pilot valves 108 are also visible in this figure.
  • a compensator 196 (to be discussed later) is provided in communication with a port 197 that fluidly communicates with the ambient.
  • the removable section 110 has a bucket as the connecting element 112 .
  • Bucket 112 is configured to mate with a ROV vehicle for removing or attaching the removable section 110 to the fixed part 100 .
  • the removable section 110 may include a locking device 190 for locking the removable section 110 to the fixed part 100 .
  • the fixed part may have a receiving part 192 for receiving the locking device 190 .
  • the locking device 190 includes a screw.
  • a compensator 196 may be added to the removable section 110 for negating a differential pressure between an ambient subsea pressure (e.g., pressure generated at the ocean floor by the water above) and a pressure inside cavity 124 (when the cavity 124 is filled with a non-conducting fluid, e.g., a dielectric fluid).
  • an ambient subsea pressure e.g., pressure generated at the ocean floor by the water above
  • a pressure inside cavity 124 when the cavity 124 is filled with a non-conducting fluid, e.g., a dielectric fluid.
  • the removable section 110 may be located on the ocean floor without endangering the integrity of the electronic components provided inside cavity 124 , e.g., power and communication part 118 .
  • some of the electronic components may trap inside air at atmospheric pressure and exposing these components to the high pressure undersea might cause damage.
  • FIG. 15 illustrates an exemplary embodiment in which the removable section 110 does not have such a mechanism.
  • the removable section 110 is still removable from the fixed part 100 but not by an ROV vehicle.
  • FIG. 15 shows a hydraulic supply 200 providing the fluid under pressure to the fixed part 100 .
  • the fluid under pressure is provided from the fixed part 100 to the removable section 110 when the two parts are mated.
  • the solenoid valves 108 are shown grouped together on the removable section 110 while the SPM valves 106 are shown grouped together on the fixed part 100 .
  • Conduits 202 are shown connecting the solenoid valves 108 to corresponding stubs 204 that fluidly communicate with the SPM valves 106 .
  • the pressure compensator 196 is shown mounted on the removable section 110 .
  • This exemplary embodiment differs from other embodiments discussed above in that an electrical bulkhead connector 206 is provided on the removable section 110 to be connected to, for example, the MUX pod (not shown in this figure) without passing through the fixed part 100 .
  • An advantage of this exemplary removable section 110 is as discussed next. Assuming that at least a solenoid valve 108 is faulty, the entire control module 208 needs to be brought to the surface for maintenance. The control module 208 may have a weight of approximately 800 kg while the removable section 110 may have a weight of approximately 200 kg. However, because only the removable section 110 needs to be handled as the solenoid valve 108 is provided in the removable section 110 , a crane for removing the removable section 110 may be smaller and/or the effort and human involvement in manipulating the removable section 110 may be reduced.
  • the method includes a step 1600 of attaching a control module to a frame, a step 1602 of connecting a fixed part of the control module to a high pressure supply line for receiving a fluid under high pressure, a step 1604 of providing a valve manifold that houses plural hydraulic activated valves in the fixed part, a step 1606 of detachably attaching a removable section of the control module to the fixed part, a step 1608 of fluidly connecting plural electrically activated valves of the removable section to the plural hydraulic activated valves such that the plural electrically activated valves control the plural hydraulic activated valves, and a step 1610 of electrically connecting the plural electrically activated valves to a control system.
  • the disclosed exemplary embodiments provide a system and a method for assembling a control module. It should be understood that this description is not intended to limit the invention. On the contrary, the exemplary embodiments are intended to cover alternatives, modifications and equivalents, which are included in the spirit and scope of the invention as defined by the appended claims. Further, in the detailed description of the exemplary embodiments, numerous specific details are set forth in order to provide a comprehensive understanding of the claimed invention. However, one skilled in the art would understand that various embodiments may be practiced without such specific details.

Landscapes

  • 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)
  • Fluid-Pressure Circuits (AREA)
US12/816,901 2010-04-30 2010-06-16 Subsea Control Module with Removable Section Abandoned US20110266002A1 (en)

Priority Applications (5)

Application Number Priority Date Filing Date Title
US12/816,901 US20110266002A1 (en) 2010-04-30 2010-06-16 Subsea Control Module with Removable Section
SG2013079165A SG195600A1 (en) 2010-04-30 2011-04-19 Subsea control module with removable section
AU2011201784A AU2011201784A1 (en) 2010-04-30 2011-04-19 Subsea control module with removable section
EP11164033.0A EP2383427A3 (de) 2010-04-30 2011-04-28 Unterwassersteuermodul mit abnehmbarem Abschnitt
BRPI1101603-5A BRPI1101603A2 (pt) 2010-04-30 2011-04-29 dispositivo submarino, módulo de controle e conjunto de preventores

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US32988310P 2010-04-30 2010-04-30
US12/816,901 US20110266002A1 (en) 2010-04-30 2010-06-16 Subsea Control Module with Removable Section

Publications (1)

Publication Number Publication Date
US20110266002A1 true US20110266002A1 (en) 2011-11-03

Family

ID=44170093

Family Applications (1)

Application Number Title Priority Date Filing Date
US12/816,901 Abandoned US20110266002A1 (en) 2010-04-30 2010-06-16 Subsea Control Module with Removable Section

Country Status (5)

Country Link
US (1) US20110266002A1 (de)
EP (1) EP2383427A3 (de)
AU (1) AU2011201784A1 (de)
BR (1) BRPI1101603A2 (de)
SG (1) SG195600A1 (de)

Cited By (19)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20120175125A1 (en) * 2010-11-15 2012-07-12 Oceaneering International, Inc. Subsea pod pump
US20120324876A1 (en) * 2011-04-26 2012-12-27 Bp Corporation North America Inc. Subsea accumulator system
US20140305656A1 (en) * 2011-09-02 2014-10-16 Subc Solutions As Subsea control modules and methods related thereto
US8939215B2 (en) 2010-05-28 2015-01-27 The Subsea Company Gasless pilot accumulator
WO2016054221A1 (en) * 2014-09-30 2016-04-07 Hydril USA Distribution LLC Safety integrity levels (sil) rated system for blowout preventer control
US20160138358A1 (en) * 2008-04-24 2016-05-19 Cameron International Corporation Subsea Pressure Delivery System
CN105756600A (zh) * 2016-05-11 2016-07-13 中国石油大学(华东) 一种深水井喷应急井控设备及其作业方法
US20160319622A1 (en) * 2015-05-01 2016-11-03 Hydril Usa Distribution, Llc Hydraulic Re-configurable and Subsea Repairable Control System for Deepwater Blow-out Preventers
US9528340B2 (en) * 2014-12-17 2016-12-27 Hydrill USA Distribution LLC Solenoid valve housings for blowout preventer
US9759018B2 (en) 2014-12-12 2017-09-12 Hydril USA Distribution LLC System and method of alignment for hydraulic coupling
US9879504B1 (en) * 2014-01-22 2018-01-30 Pacseal Group, Inc. Modular controller apparatus with integral adjustable pressure regulator for oil well blow-out preventers
US9989975B2 (en) 2014-11-11 2018-06-05 Hydril Usa Distribution, Llc Flow isolation for blowout preventer hydraulic control systems
US10048673B2 (en) 2014-10-17 2018-08-14 Hydril Usa Distribution, Llc High pressure blowout preventer system
US20180283110A1 (en) * 2017-03-31 2018-10-04 Schlumberger Technology Corporation Multi-level deck system for blowout preventers
US10196871B2 (en) 2014-09-30 2019-02-05 Hydril USA Distribution LLC Sil rated system for blowout preventer control
US10202839B2 (en) 2014-12-17 2019-02-12 Hydril USA Distribution LLC Power and communications hub for interface between control pod, auxiliary subsea systems, and surface controls
US10876369B2 (en) 2014-09-30 2020-12-29 Hydril USA Distribution LLC High pressure blowout preventer system
CN113006732A (zh) * 2021-02-26 2021-06-22 河北华北石油荣盛机械制造有限公司 一种水下设备储能控制装置
RU2753893C1 (ru) * 2021-01-27 2021-08-24 Общество с ограниченной ответственностью "Газпром 335" Гидравлическая плита подводного модуля управления

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2520258B (en) * 2013-11-12 2015-12-30 Subsea 7 Ltd Connection and disconnection of hydraulic equipment in hyperbaric environments
GB201918323D0 (en) * 2019-12-12 2020-01-29 Siemens Ag Subsea connector

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5456313A (en) * 1993-06-04 1995-10-10 Cooper (Great Britain) Limited Modular control system
US6068427A (en) * 1995-12-22 2000-05-30 Abb Offshore Technology As System and method for replacement of components on sea bottom-based installations
US6161618A (en) * 1998-08-06 2000-12-19 Dtc International, Inc. Subsea control module
US6484806B2 (en) * 2001-01-30 2002-11-26 Atwood Oceanics, Inc. Methods and apparatus for hydraulic and electro-hydraulic control of subsea blowout preventor systems
US6644410B1 (en) * 2000-07-27 2003-11-11 Christopher John Lindsey-Curran Modular subsea control system
US20100307761A1 (en) * 2009-06-04 2010-12-09 Dtc International, Inc. Subsea Control Module with Interchangeable Segments
US8020623B2 (en) * 2007-08-09 2011-09-20 Dtc International, Inc. Control module for subsea equipment
US20110266003A1 (en) * 2010-04-30 2011-11-03 Hydril Usa Manufacturing Llc Subsea Control Module with Removable Section Having a Flat Connecting Face

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0943050B1 (de) * 1996-12-09 2002-07-03 Hydril Company Kontrollsystem für einen blowoutpreventer
US7216714B2 (en) * 2004-08-20 2007-05-15 Oceaneering International, Inc. Modular, distributed, ROV retrievable subsea control system, associated deepwater subsea blowout preventer stack configuration, and methods of use

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5456313A (en) * 1993-06-04 1995-10-10 Cooper (Great Britain) Limited Modular control system
US6068427A (en) * 1995-12-22 2000-05-30 Abb Offshore Technology As System and method for replacement of components on sea bottom-based installations
US6161618A (en) * 1998-08-06 2000-12-19 Dtc International, Inc. Subsea control module
US6644410B1 (en) * 2000-07-27 2003-11-11 Christopher John Lindsey-Curran Modular subsea control system
US6484806B2 (en) * 2001-01-30 2002-11-26 Atwood Oceanics, Inc. Methods and apparatus for hydraulic and electro-hydraulic control of subsea blowout preventor systems
US8020623B2 (en) * 2007-08-09 2011-09-20 Dtc International, Inc. Control module for subsea equipment
US20100307761A1 (en) * 2009-06-04 2010-12-09 Dtc International, Inc. Subsea Control Module with Interchangeable Segments
US20110266003A1 (en) * 2010-04-30 2011-11-03 Hydril Usa Manufacturing Llc Subsea Control Module with Removable Section Having a Flat Connecting Face

Cited By (24)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20160138358A1 (en) * 2008-04-24 2016-05-19 Cameron International Corporation Subsea Pressure Delivery System
US8939215B2 (en) 2010-05-28 2015-01-27 The Subsea Company Gasless pilot accumulator
US20120175125A1 (en) * 2010-11-15 2012-07-12 Oceaneering International, Inc. Subsea pod pump
US20120324876A1 (en) * 2011-04-26 2012-12-27 Bp Corporation North America Inc. Subsea accumulator system
US20140305656A1 (en) * 2011-09-02 2014-10-16 Subc Solutions As Subsea control modules and methods related thereto
US9303489B2 (en) * 2011-09-02 2016-04-05 Subc Solutions As Subsea control modules and methods related thereto
US9879504B1 (en) * 2014-01-22 2018-01-30 Pacseal Group, Inc. Modular controller apparatus with integral adjustable pressure regulator for oil well blow-out preventers
US9803448B2 (en) 2014-09-30 2017-10-31 Hydril Usa Distribution, Llc SIL rated system for blowout preventer control
CN107002481A (zh) * 2014-09-30 2017-08-01 海德里尔美国配送有限责任公司 用于防喷器控制的安全性完整性等级(sil)评级系统
WO2016054221A1 (en) * 2014-09-30 2016-04-07 Hydril USA Distribution LLC Safety integrity levels (sil) rated system for blowout preventer control
US10876369B2 (en) 2014-09-30 2020-12-29 Hydril USA Distribution LLC High pressure blowout preventer system
US10196871B2 (en) 2014-09-30 2019-02-05 Hydril USA Distribution LLC Sil rated system for blowout preventer control
US10048673B2 (en) 2014-10-17 2018-08-14 Hydril Usa Distribution, Llc High pressure blowout preventer system
US9989975B2 (en) 2014-11-11 2018-06-05 Hydril Usa Distribution, Llc Flow isolation for blowout preventer hydraulic control systems
US9759018B2 (en) 2014-12-12 2017-09-12 Hydril USA Distribution LLC System and method of alignment for hydraulic coupling
US10202839B2 (en) 2014-12-17 2019-02-12 Hydril USA Distribution LLC Power and communications hub for interface between control pod, auxiliary subsea systems, and surface controls
US9528340B2 (en) * 2014-12-17 2016-12-27 Hydrill USA Distribution LLC Solenoid valve housings for blowout preventer
US20160319622A1 (en) * 2015-05-01 2016-11-03 Hydril Usa Distribution, Llc Hydraulic Re-configurable and Subsea Repairable Control System for Deepwater Blow-out Preventers
US9828824B2 (en) * 2015-05-01 2017-11-28 Hydril Usa Distribution, Llc Hydraulic re-configurable and subsea repairable control system for deepwater blow-out preventers
CN105756600A (zh) * 2016-05-11 2016-07-13 中国石油大学(华东) 一种深水井喷应急井控设备及其作业方法
US10494890B2 (en) * 2017-03-31 2019-12-03 Schlumberger Technology Corporation Multi-level deck system for blowout preventers
US20180283110A1 (en) * 2017-03-31 2018-10-04 Schlumberger Technology Corporation Multi-level deck system for blowout preventers
RU2753893C1 (ru) * 2021-01-27 2021-08-24 Общество с ограниченной ответственностью "Газпром 335" Гидравлическая плита подводного модуля управления
CN113006732A (zh) * 2021-02-26 2021-06-22 河北华北石油荣盛机械制造有限公司 一种水下设备储能控制装置

Also Published As

Publication number Publication date
EP2383427A3 (de) 2015-06-24
SG195600A1 (en) 2013-12-30
BRPI1101603A2 (pt) 2012-10-02
AU2011201784A1 (en) 2011-11-17
EP2383427A2 (de) 2011-11-02

Similar Documents

Publication Publication Date Title
US8464797B2 (en) Subsea control module with removable section and method
US20110266002A1 (en) Subsea Control Module with Removable Section
US20110266003A1 (en) Subsea Control Module with Removable Section Having a Flat Connecting Face
US8393399B2 (en) Blowout preventer with intervention, workover control system functionality and method
US8820410B2 (en) Control system for blowout preventer stack
US7690433B2 (en) Modular, distributed, ROV retrievable subsea control system, associated deepwater subsea blowout preventer stack configuration, and methods of use
US10787877B2 (en) Blowout preventer control system and methods for controlling a blowout preventer
US9458689B2 (en) System for controlling in-riser functions from out-of-riser control system
WO2006099316A1 (en) Riserless modular subsea well intervention, method and apparatus
NO316870B1 (no) Utblasingssikring-styresystem samt en fremgangsmate for styring av utblasningssikringen
US20140048274A1 (en) Modular, Distributed, ROV Retrievable Subsea Control System, Associated Deepwater Subsea Blowout Preventer Stack Configuration, and Methods of Use

Legal Events

Date Code Title Description
AS Assignment

Owner name: HYDRIL USA MANUFACTURING LLC, TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:SINGH, HARDEV;DIETZ, DAVID, JR.;MELENDEZ, LUIS;AND OTHERS;REEL/FRAME:024585/0938

Effective date: 20100614

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION