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US20130168101A1 - Vertical subsea tree assembly control - Google Patents

Vertical subsea tree assembly control Download PDF

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Publication number
US20130168101A1
US20130168101A1 US13/338,792 US201113338792A US2013168101A1 US 20130168101 A1 US20130168101 A1 US 20130168101A1 US 201113338792 A US201113338792 A US 201113338792A US 2013168101 A1 US2013168101 A1 US 2013168101A1
Authority
US
United States
Prior art keywords
subsea
valve block
landing sub
master valve
passages
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
US13/338,792
Other languages
English (en)
Inventor
William Thomas Bryson
Michael Wenham
Paul White
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.)
Vetco Gray LLC
Original Assignee
Vetco Gray 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 Vetco Gray LLC filed Critical Vetco Gray LLC
Priority to US13/338,792 priority Critical patent/US20130168101A1/en
Assigned to VETCO GRAY INC. reassignment VETCO GRAY INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: WHITE, PAUL, BRYSON, WILLIAM THOMAS, WENHAM, MICHAEL
Priority to NO20121507A priority patent/NO20121507A1/no
Priority to GB1222764.1A priority patent/GB2498075B/en
Priority to AU2012268839A priority patent/AU2012268839A1/en
Priority to SG2012094884A priority patent/SG191548A1/en
Priority to BR102012033440A priority patent/BR102012033440A2/pt
Priority to CN2012105824719A priority patent/CN103184845A/zh
Publication of US20130168101A1 publication Critical patent/US20130168101A1/en
Abandoned legal-status Critical Current

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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
    • 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
    • E21B33/038—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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/02—Valve arrangements for boreholes or wells in well heads
    • E21B34/04—Valve arrangements for boreholes or wells in well heads in underwater well heads

Definitions

  • This invention relates in general to control of a subsea well completion and, in particular, to a system and method for subsea well control by landing a landing sub on a vertical subsea tree.
  • Subsea wellhead assemblies are typically used in the production of hydrocarbons extracted from subterranean formations below the seafloor.
  • Subsea wellhead assemblies generally comprise a wellhead housing disposed at a wellbore opening, where the wellbore extends through one or more hydrocarbon producing formations.
  • Casing and tubing hangers are landed within the housing for supporting casing and production tubing inserted into the wellbore.
  • the casing lines the wellbore, thereby isolating the wellbore from the surrounding formation.
  • Tubing typically lies concentric within the casing and provides a conduit for producing the hydrocarbons entrained within the formation.
  • Wellhead assemblies also typically include subsea trees, also known as christmas trees, connected to the upper end of the wellhead housing. The subsea trees control and distribute the fluids produced from the wellbore.
  • Subsea trees are installed on the wellhead housing, tubing head, or tubing hanger spool by latching a running tool either within the tree's main mandrel or to the external profile and attaching wire or drill pipe to the running tool for lowering the subsea tree to the wellhead housing.
  • One or more umbilical lines may then be run from a working platform to the subsea tree where the umbilicals may be connected to the subsea tree by remotely operated vehicles.
  • These umbilicals are used to provide power, both hydraulic and electric, to subsea control modules to control functions of subsea trees, such as flow control valves, chokes and other hydraulic devices during tree installation, re-entry, workover, or abandonment of the well.
  • umbilicals may be used to receive information from tree sensors during operation of the subsea tree. Opposite ends of the umbilicals may be connected to devices at the surface platform or alternatively to other subsea devices that provide operational control of valves within the subsea tree. These umbilicals may be disposed at subsea locations that are several miles below the surface of the sea. One or more umbilicals may also be used to function or pressure test the tubing hanger running too and landing string. This system is run through the drilling marine riser into either the wellhead or tree master valve block. Thus, the umbilicals may be constructed to withstand the temperature and pressures at such locations. In turn, this may cause the cost of such umbilicals to be incredibly steep, upwards of multi millions of dollars to construction an umbilical that is strong enough and long enough to be used at subsea locations exterior of a subsea riser.
  • umbilicals may also be subject to spooling damage during operation.
  • a workover umbilical may be lowered from a floating rig or work boat and leads from the workover umbilical are connected to the tree. Additional umbilicals may also be lowered with workover and completion tools and devices. These umbilicals electric or hydraulic power to the tools and devices for operation within the wellhead and tree assemblies. Running of multiple umbilicals for subsea operations adds significantly to the costs of operation as additional spools and equipment are needed at the surface to support the additional umbilicals. Therefore, there is a need for a system or method to control a subsea tree using fewer umbilicals.
  • a method for controlling a subsea completion or workover assembly in a subsea well having a vertical subsea tree communicatively coupled with a subsea control module is disclosed.
  • the method provides the vertical subsea tree with at least one master valve block passage leading from an inner portion of an upper mandrel of a master valve block to an exterior of the vertical subsea tree, wherein the at least one master valve block passage communicatively couples the vertical subsea tree with the subsea control module.
  • the method also provides the master valve block of the vertical subsea tree with at least one penetration on the inner portion of the upper mandrel communicatively coupled to the at least one master valve block passage.
  • the method provides a landing sub having at least one landing sub passage extending from a landing sub penetration on a lower portion of the landing sub and connecting the at least one landing sub passage to an umbilical.
  • the landing sub is run subsea to land the landing sub on the master valve block and register the landing sub penetration with the master valve block penetration.
  • the method then supplies at least one of hydraulic fluid pressure and electric potential to the subsea control module through the umbilical, landing sub passage, and master valve block passage.
  • the method then performs at least one of subsea completion operations and subsea workover operations with at least one of the hydraulic fluid pressure and the electrical potential provided through the passages.
  • a method for controlling a subsea completion or workover assembly in a subsea well having a vertical subsea tree communicatively coupled with a subsea control module provides the vertical subsea tree with a plurality of master valve block passages leading from an inner portion of an upper mandrel of a master valve block to an exterior of the vertical subsea tree wherein the plurality of master valve block passages communicatively couple the vertical subsea tree with the subsea control module.
  • the method also provides the master valve block of the vertical subsea tree with a plurality of penetrations on the inner upper mandrel communicatively coupled a respective passage.
  • the method provides a landing sub having a plurality of landing sub passages extending from a plurality of corresponding landing sub penetrations on a lower portion of the landing sub and connecting the at least one landing sub passage to an umbilical.
  • the method runs the landing sub to land the landing sub on the master valve block and register the landing sub penetrations with the master valve block penetrations and supplies hydraulic fluid pressure, electric potential, and treatment fluids to the subsea control module through the umbilical, landing sub passages, and master valve block passages.
  • the method then performs at least one of subsea completion operations and subsea workover operations with the hydraulic fluid pressure, the electrical potential, and the treatment fluids provided through the passages.
  • a subsea completion or workover assembly in a subsea well having a vertical subsea tree with a master valve block having an inner portion of an upper mandrel for receiving a landing sub is disclosed.
  • the assembly includes at least one master valve block passage leading from the inner portion of the upper mandrel of the master valve block to an exterior of the vertical subsea tree, the at least one master valve block passage further communicatively coupled to a subsea control module.
  • the master valve block includes at least one penetration on the inner portion of the upper mandrel communicatively coupled to the at least one passage.
  • the assembly also includes a landing sub having at least one landing sub passage extending from a landing sub penetration on a lower portion of the landing sub, and an umbilical connected to the landing sub, the at least one landing sub passage in communication with the umbilical.
  • the landing sub lands on the master valve block and registers the landing sub penetration with the master valve block penetration.
  • At least one of hydraulic fluid pressure, electric potential, and treatment fluids are supplied to the subsea control module through the umbilical, landing sub passage, and master valve block passage to perform at least one of subsea completion and workover operations with at least one of the hydraulic fluid pressure, the electrical potential, and the treatment fluids provided through the passages.
  • An advantage of a preferred embodiment is that it provides a means to operate a subsea vertical tree through a subsea control module using a single umbilical run from the surface with a landing sub. This eliminates the need for use of multiple umbilicals, one that runs separately with the landing sub for operation of the landing sub and one run directly to the subsea control module.
  • the disclosed embodiments eliminate the need for additional backup umbilicals associated with the subsea control module umbilical.
  • the disclosed embodiments eliminate the need to have ROVs unhook from other assemblies to install and disconnect a subsea control module umbilical.
  • the disclosed embodiments also reduce the management requirements associated with umbilicals by reducing the total number of umbilicals needed in an intervention or workover operation, thereby reducing installation time and risk. All these factors contribute to a more efficient and safer system that has a reduced capital expenditure for use and a reduced operating expenditure due to the faster and more efficient installation method.
  • FIG. 1 is a schematic representation of a subsea well completion in accordance with an embodiment.
  • FIG. 2 is schematic representation of subsea well completion of FIG. 1 illustrating flow paths through the subsea well completion.
  • FIG. 2A is an alternative embodiment of the flow paths of FIG. 2 .
  • FIG. 3 is a schematic representation of an alternative subsea well completion illustrating flow paths through the subsea well completion in accordance with an embodiment of the invention.
  • a subsea wellhead 11 is disposed within a wellbore 13 located at a sea floor location 15 .
  • the wellbore 13 may be lined or cased with a casing string 17 extending from the wellhead to a location subsurface.
  • a tubing string 19 may be suspended within the wellbore for production of hydrocarbons from wellbore 13 .
  • a vertical subsea tree 21 is landed on wellhead 11 .
  • a subsea riser 23 extends from vertical subsea tree 21 to a platform 25 located on a sea surface.
  • Platform 25 may be a floating rig, a workover vessel, or the like.
  • a landing string 26 may extend from the platform to vertical subsea tree 21 and support a landing sub 27 at vertical subsea tree 21 .
  • vertical subsea tree 21 includes production ports (not shown) and valves (not shown) that connect to subsea flowlines to allow flow of well fluid to additional production apparatuses located on the sea floor.
  • the schematic representation of FIG. 1 may comprise a workover, a well intervention, a well recompletion, or the like.
  • landing sub 27 may comprise a subsea test tree and blowout preventer assembly, an open water installation device, such as a tree running tool, handling device, a lower riser package, an emergency disconnect package, or the like depending on the particular situational conditions under which the well is operating.
  • an open water installation device such as a tree running tool, handling device, a lower riser package, an emergency disconnect package, or the like depending on the particular situational conditions under which the well is operating.
  • riser 23 may not be used.
  • open water operations and devices may be used.
  • vertical subsea tree 21 is schematically shown disposed on wellhead 11 .
  • Vertical subsea tree 21 may include a tubing head spool 29 disposed on wellhead 11 .
  • Tubing head spool 29 will support a tubing hanger 31 on which a master valve block 33 will be disposed.
  • a subsea blowout preventer 35 may be disposed on vertical subsea tree 21 .
  • landing sub 27 will be disposed within blowout preventer 35 to land on master valve block 33 .
  • landing sub 27 may comprise a subsea test tree.
  • the well completion will include a central bore 28 extending through vertical subsea tree 21 , tubing head spool 29 , tubing hanger 31 , master valve block 33 , and subsea blowout preventer 35 .
  • the well completion may include an annulus flow path 30 extending through vertical subsea tree 21 , tubing head spool 29 , tubing hanger 31 , master valve block 33 , and subsea blowout preventer 35 . Fluid flow through central bore 28 and annulus 30 may be controlled by a plurality of valves 32 .
  • Master valve block 33 will include a plurality of flow paths 37 extending from an inner bore (not shown) of master valve block 33 to a location external to the inner bore of vertical subsea tree 21 .
  • Flow paths 37 may comprise any suitable subsea communication lines that may accommodate flow of subsea materials, such as hydraulic fluid, electric potential, or chemical injection fluid. In the illustrated embodiment, there are five flow paths 37 , first and second low pressure flow paths, first and second high pressure flow paths, and a chemical injection flow path.
  • Each flow path 37 will include an isolation valve 39 .
  • Isolation valve 39 may be any suitable valve such that operation of isolation valve may permit and restrict flow through the corresponding flow path 37 .
  • isolation valves 39 may comprise gate valves, ball valves, or the like.
  • Flow paths 37 will terminate at penetrations 41 in an inner portion of an upper mandrel 34 of master valve block 33 .
  • Upper mandrel 34 may be a integral portion of master valve block 33 or, alternatively, upper mandrel 34 may be a separate member coupled to master valve block 33 .
  • penetrations 41 In the illustrated embodiment, penetrations 41 comprise male and female portions. At least one of the male and the female portion of each penetration 41 will be mounted to the inner upper mandrel of master valve block 33 .
  • Landing sub 27 will include landing sub flow paths 43 .
  • Landing sub 27 may be the same landing sub used to install and test tubing hanger 31 in wellhead 11 or a tubing spool or landing sub 27 may have a different orientation method or number of functions.
  • Landing sub flow paths 43 may be formed in any suitable manner within landing sub 27 and will extend from a landing sub umbilical 45 to penetrations 41 at a lower end of landing sub 27 . As shown, each flow path 43 will correspond with a flow path 37 of master valve block 33 . The opposing pair of each penetration 41 will be mounted to a lower end of landing sub 27 so that when landing sub 27 lands on master valve block 33 , each penetration 41 will mate with its respective pair to allow for fluid communication between respective flow paths 37 and 43 .
  • Landing sub umbilical 45 will extend through blowout preventer 35 and riser 23 to platform 25 . There, high and low pressure fluids, along with chemical injection substances may be supplied to landing sub umbilical 45 for communication with respective flow paths 37 through landing sub 27 . In an embodiment, electric power and communication may be supplied through landing sub umbilical 45 to landing sub passages 45 and flow passages 37 .
  • a subsea control module 47 and a subsea tree stab plate 49 may be mounted to subsea vertical tree 21 .
  • Subsea control module 47 may be any suitable apparatus adapted to operate functions of subsea vertical tree 21 and other devices located in and around subsea vertical tree 21 .
  • Subsea tree stab plate 49 may comprise a plurality of hot stabs adapted to allow a remotely operated vehicle (ROV) to interface with and provide hydraulic power and chemical injection to subsea tree 21 and subsea control module 47 .
  • ROV remotely operated vehicle
  • the hydraulic pressure lines of flow paths 37 will be communicatively coupled to both subsea control module 47 and subsea tree stab plate 49 through a plurality of tees 51 .
  • Hydraulic fluid applied at the surface through landing sub umbilical 45 may supply subsea control module 47 with hydraulic power for operation of subsea tree 21 .
  • the necessity of a separate umbilical to be run from the surface to subsea control module 47 will be removed, allowing all control of subsea vertical tree 21 to be conducted from platform 25 through riser 23 and landing sub 27 .
  • tees 51 are not inserted into flow paths 37 .
  • Flow paths 37 are in direct fluid communication with subsea tree stab plate 49 .
  • a hydraulic bridging plate 53 may be coupled to subsea tree stab plate 49 .
  • Hydraulic bridging plate 53 will provide fluid communication between the hydraulic flow paths 37 and corresponding hydraulic flow paths 55 extending from subsea tree stab plate 49 and subsea control module 47 .
  • hydraulic power may be supplied to subsea control module 47 from platform 25 through landing sub umbilical 45 , landing sub flow passages 43 , flow paths 37 , and flow paths 55 .
  • electric power may be supplied to subsea control module 47 from platform 25 through landing sub umbilical 45 , landing sub flow passages 43 , flow paths 37 , and flow paths 55 .
  • landing sub 27 may comprise an open water installation device such as a tree running tool, a handling device, a lower riser package, or an emergency disconnect package. Landing sub 27 may be run on a wire line 57 to the location illustrated in FIG. 3 .
  • landing sub umbilical 45 may supply landing sub flow passages 43 with hydraulic power, electric power, and chemical injection materials. Similar to the embodiment of FIG. 2 , hydraulic power, and electric power may be further supplied to subsea control module 47 through, flow paths 37 .
  • FIG. 3 includes the devices of and operates in a manner similar to the embodiment of FIG. 2 and FIG. 2A .
  • the disclosed embodiments provide a means to operate a subsea vertical tree through a subsea control module using a single umbilical run from the surface with a landing sub. This eliminates the need for use of multiple umbilicals, one that runs separately with the landing sub for operation of the landing sub and one run directly to the subsea control module.
  • the disclosed embodiments eliminate the need for additional backup umbilicals associated with the subsea control module umbilical.
  • the disclosed embodiments eliminate the need to have ROVs unhook from other assemblies to install and disconnect a subsea control module umbilical.
  • the disclosed embodiments also reduce the management requirements associated with umbilicals by reducing the total number of umbilicals needed in an intervention or workover operation, thereby reducing installation time and risk. All these factors contribute to a more efficient and safer system that has a reduced capital expenditure for use and a reduced operating expenditure due to the faster and more efficient installation method.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Other Liquid Machine Or Engine Such As Wave Power Use (AREA)
  • Earth Drilling (AREA)
  • Laying Of Electric Cables Or Lines Outside (AREA)
  • Operation Control Of Excavators (AREA)
US13/338,792 2011-12-28 2011-12-28 Vertical subsea tree assembly control Abandoned US20130168101A1 (en)

Priority Applications (7)

Application Number Priority Date Filing Date Title
US13/338,792 US20130168101A1 (en) 2011-12-28 2011-12-28 Vertical subsea tree assembly control
NO20121507A NO20121507A1 (no) 2011-12-28 2012-12-13 Vertikal undervannstresammenstillings-styring
GB1222764.1A GB2498075B (en) 2011-12-28 2012-12-18 Vertical subsea tree assembly control
AU2012268839A AU2012268839A1 (en) 2011-12-28 2012-12-19 Vertical subsea tree assembly control
SG2012094884A SG191548A1 (en) 2011-12-28 2012-12-21 Vertical subsea tree assembly control
BR102012033440A BR102012033440A2 (pt) 2011-12-28 2012-12-27 método para controlar uma construção submarina de conclusão ou workover em um poço submarino e construção submarina
CN2012105824719A CN103184845A (zh) 2011-12-28 2012-12-28 立式水下采油树组件控制

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US13/338,792 US20130168101A1 (en) 2011-12-28 2011-12-28 Vertical subsea tree assembly control

Publications (1)

Publication Number Publication Date
US20130168101A1 true US20130168101A1 (en) 2013-07-04

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ID=47630890

Family Applications (1)

Application Number Title Priority Date Filing Date
US13/338,792 Abandoned US20130168101A1 (en) 2011-12-28 2011-12-28 Vertical subsea tree assembly control

Country Status (7)

Country Link
US (1) US20130168101A1 (no)
CN (1) CN103184845A (no)
AU (1) AU2012268839A1 (no)
BR (1) BR102012033440A2 (no)
GB (1) GB2498075B (no)
NO (1) NO20121507A1 (no)
SG (1) SG191548A1 (no)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9458689B2 (en) * 2014-02-21 2016-10-04 Onesubsea Ip Uk Limited System for controlling in-riser functions from out-of-riser control system
CN107253161A (zh) * 2017-05-08 2017-10-17 哈尔滨工程大学 一种水下控制模块安装工具
US20210396107A1 (en) * 2020-06-23 2021-12-23 Onesubsea Ip Uk Limited Distributed control system for a well string
US11268332B2 (en) 2019-02-21 2022-03-08 Weatherford Technology Holdings, Llc Self-aligning, multi-stab connections for managed pressure drilling between rig and riser components
US11629559B2 (en) 2019-02-21 2023-04-18 Weatherford Technology Holdings, Llc Apparatus for connecting drilling components between rig and riser

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO342043B1 (en) * 2015-12-08 2018-03-19 Aker Solutions As Workover Safety System
US11828140B2 (en) 2019-08-02 2023-11-28 Fmc Technologies, Inc. System and methods of use for a blind plug
CN112593888B (zh) * 2020-12-08 2022-07-05 重庆前卫科技集团有限公司 脐带缆部署及水下对接装置
CN112799335B (zh) * 2021-04-09 2021-07-06 美钻深海能源科技研发（上海）有限公司 水下采油树安全再利用测试系统及方法

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US3918485A (en) * 1973-09-18 1975-11-11 Exxon Production Research Co Multiport subsea connector
US7331396B2 (en) * 2004-03-16 2008-02-19 Dril-Quip, Inc. Subsea production systems
US20100025044A1 (en) * 2008-07-31 2010-02-04 Bp Corporation North America Inc. Subsea well intervention systems and methods

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GB0517905D0 (en) * 2004-09-02 2005-10-12 Vetco Gray Inc Tubing running equipment for offshore rig with surface blowout preventer
AU2007317276B2 (en) * 2006-11-07 2011-07-28 Halliburton Energy Services, Inc. Offshore universal riser system
WO2009146206A2 (en) * 2008-04-18 2009-12-03 Schlumberger Canada Limited Subsea tree safety control system
BRPI0919198A2 (pt) * 2008-10-10 2015-12-15 Cameron Int Corp sistema integrado de instalação e controle de workover
CN201778730U (zh) * 2010-08-09 2011-03-30 宝鸡石油机械有限责任公司 一种海洋水下立式采油树

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3918485A (en) * 1973-09-18 1975-11-11 Exxon Production Research Co Multiport subsea connector
US7331396B2 (en) * 2004-03-16 2008-02-19 Dril-Quip, Inc. Subsea production systems
US20100025044A1 (en) * 2008-07-31 2010-02-04 Bp Corporation North America Inc. Subsea well intervention systems and methods

Cited By (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9458689B2 (en) * 2014-02-21 2016-10-04 Onesubsea Ip Uk Limited System for controlling in-riser functions from out-of-riser control system
CN107253161A (zh) * 2017-05-08 2017-10-17 哈尔滨工程大学 一种水下控制模块安装工具
US11268332B2 (en) 2019-02-21 2022-03-08 Weatherford Technology Holdings, Llc Self-aligning, multi-stab connections for managed pressure drilling between rig and riser components
US11629559B2 (en) 2019-02-21 2023-04-18 Weatherford Technology Holdings, Llc Apparatus for connecting drilling components between rig and riser
US20210396107A1 (en) * 2020-06-23 2021-12-23 Onesubsea Ip Uk Limited Distributed control system for a well string
US11713657B2 (en) * 2020-06-23 2023-08-01 Onesubsea Ip Uk Limited Distributed control system for a well string

Also Published As

Publication number Publication date
BR102012033440A2 (pt) 2015-10-20
CN103184845A (zh) 2013-07-03
NO20121507A1 (no) 2013-07-01
GB2498075A (en) 2013-07-03
GB201222764D0 (en) 2013-01-30
GB2498075B (en) 2014-07-16
AU2012268839A1 (en) 2013-07-18
SG191548A1 (en) 2013-07-31

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