US20080202761A1 - Method of functioning and / or monitoring temporarily installed equipment through a Tubing Hanger. - Google Patents

Method of functioning and / or monitoring temporarily installed equipment through a Tubing Hanger. Download PDF

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Publication number
US20080202761A1
US20080202761A1 US11/818,955 US81895506A US2008202761A1 US 20080202761 A1 US20080202761 A1 US 20080202761A1 US 81895506 A US81895506 A US 81895506A US 2008202761 A1 US2008202761 A1 US 2008202761A1
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United States
Prior art keywords
item
tubing hanger
control
production tree
stabs
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
US11/818,955
Inventor
Ross John Trewhella
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DEEPBLUE TECHNOLOGIES LLC
Original Assignee
DEEPBLUE TECHNOLOGIES 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 DEEPBLUE TECHNOLOGIES LLC filed Critical DEEPBLUE TECHNOLOGIES LLC
Priority to US11/818,955 priority Critical patent/US20080202761A1/en
Priority to US11/901,393 priority patent/US20080110633A1/en
Assigned to DEEPBLUE TECHNOLOGIES, L.L.C. reassignment DEEPBLUE TECHNOLOGIES, L.L.C. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: TREWHELLA, ROSS JOHN
Publication of US20080202761A1 publication Critical patent/US20080202761A1/en
Abandoned legal-status Critical Current

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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

Definitions

  • the invention relates to a method of controlling temporarily installed equipment such as Subsea Intervention trees and Retainer Valves using Tubing Hanger access.
  • the method is comprised of the following components:
  • Subsea Test/Intervention Tree and Retainer Valve This equipment is utilized as a temporary part of a completion running string, deployed into wells from offshore floating or anchored vessels. Located within the vessels BOP stack and directly above the production trees Tubing Hanger and Tubing Hanger Running tool. This equipment provides a well isolation and unlatch function as well as hydrocarbon retention allowing the vessel to safely move off location in emergencies. These valves are hydraulically actuated and traditionally rely on application and venting of hydraulic pressures supplied from either an ‘In riser’ control system and/or an umbilical terminated at the uppermost face of each valve.
  • This umbilical is strapped or clamped to the tubing or casing string and sits within the inside diameter of the Drilling/Marine riser, as such a high level of risk exists that movement between these elements due to sea or ocean currents can cause damage to that umbilical.
  • internal porting through the assembly will carry the control fluids or electrical conduits to the various functions within the Retainer Valve, Subsea Intervention Tree, Tubing Hanger Running Tool, Tubing Hanger and ultimately devices within the Completion string.
  • Tubing Hanger Running tool The Tubing Hanger Running tool is located directly below the Subsea Intervention tree and provides a facility to latch and unlatch the upper landing string from the Tubing hanger. This allows the temporary landing string to be removed leaving the production completion installed and locked.
  • the Tubing hanger running tool can be mechanically or hydraulically actuated. Hydraulically actuated Tubing Hanger Running tools receive control pressure via conduits fed through from the Subsea Intervention valve assembly and also provides conduits for controlling the Tubing hanger and devices within the Completion string. These conduits represent multiple potential leak paths for each conduit.
  • the Tubing hanger forms the uppermost part of the permanent completion and facilitates the locking of the Completion into the production tree.
  • the Tubing Hanger is traditionally hydraulically operated; the Tubing Hanger receives control pressure from surface via the conduits passed through the Tubing Hanger Running Tool, the Subsea Intervention valve, the Retainer Valve and the ‘In riser’ umbilical. It can be seen that this supply represents a torturous path with a multitude of potential leak paths.
  • the interface between the Tubing hanger and the Production tree contains a series of stabs; these stabs facilitate the hydraulic or electrical communication between the production tree and Tubing hanger. Control pressures or electrical conduits are received from the production tree and then passed from the stabs down the completion string via a series of small-bore tubing or electrical conduits to control the various devices that make up the completion string.
  • the Production Tree is a valve manifold that directs well effluent to the production facility via a side port.
  • the production tree also acts as a control center for the completion itself; distributing hydraulic or electrical signals to the various down hole completion devices, which monitor, control or inject chemicals into the well.
  • These controls are fed to the production Tree via a production umbilical and Junction or ‘J’ plate, which is deployed open water, from the production facility or the drilling vessel, depending on the phase of operation. Once connected to the production tree the controls are routed through the body and into the Tubing Hanger as described above via sets of stabs.
  • Control System is made up of a power unit comprising a pump and accumulators combined with hydraulic valves and regulators configured to control hydraulic pressures feeding various hydraulically operated devices.
  • a control system can also regulate and supply electrical power to feed various electrically driven devices.
  • a control system will also generally include the means of delivering the hydraulics or electrical power, i.e. an umbilical which is made up of hydraulic control lines or a combination of hydraulic control lines and electrical conduits thereof.
  • Control elements i.e fluids and/or electrical
  • This junction plate is removable and attached to the Production tree (Generally, but not restricted to a Horizontal or spool type trees).
  • This junction plate locks the conduit/umbilical to the production tree and facilitates communication to a series of hydraulic ports/electrical conduits within the production tree wall. These ports will link to a set of stabs/receptacles located within or around the inner wall of the production tree and are isolated until such time as the mating tubing hanger is landed within its bore.
  • the tubing hanger is deployed from the rig floor (Surface), through the bore of the Marine riser, into the BOP stack and landed on a location within the inner bore of the production tree.
  • a completion string will be attached to the lower end of the tubing hanger and a running tool c/w Landing string and well isolation devices (Typically, but not restricted to a Subsea Test/Intervention Tree and Retainer Valve) attached to the upper end.
  • a running tool c/w Landing string and well isolation devices Typically, but not restricted to a Subsea Test/Intervention Tree and Retainer Valve
  • the action of landing the Tubing hanger within the production tree will establish communication between the aforementioned stabs/receptacles and the Tubing hanger. Alternatively these stabs/receptacles may be energized to engage using external forces. These established communications provide monitoring or control to equipment located within the completion part or lower part of the inner assembly.

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

Abstract

The invention covers the method of supplying services to a device such as a Subsea Intervention Tree and Retainer Valve using conduits routed through a tubing Hanger. The method of this invention provides control of equipment sitting within the BOP stack and/or marine riser using control systems located external to the Marine riser. This removes the need for a costly umbilical/conduit to be run alongside the casing or tubing string within the marine riser, thereby reducing cost and risk of damage during deployment of the string. Running time will be significantly reduced saving valuable rig time. Also, in deeper waters complex Electro/Hydraulic or MUX control systems traditionally run within the Marine riser and/or the BOP stack as a part of the Landing string can be replaced by a local control system located outside the Marine riser on or around the Production Tree.

Description

  • The invention relates to a method of controlling temporarily installed equipment such as Subsea Intervention trees and Retainer Valves using Tubing Hanger access. The method is comprised of the following components:
  • (1) Subsea Test/Intervention Tree and Retainer Valve: This equipment is utilized as a temporary part of a completion running string, deployed into wells from offshore floating or anchored vessels. Located within the vessels BOP stack and directly above the production trees Tubing Hanger and Tubing Hanger Running tool. This equipment provides a well isolation and unlatch function as well as hydrocarbon retention allowing the vessel to safely move off location in emergencies. These valves are hydraulically actuated and traditionally rely on application and venting of hydraulic pressures supplied from either an ‘In riser’ control system and/or an umbilical terminated at the uppermost face of each valve. This umbilical is strapped or clamped to the tubing or casing string and sits within the inside diameter of the Drilling/Marine riser, as such a high level of risk exists that movement between these elements due to sea or ocean currents can cause damage to that umbilical. From the uppermost face of the assembly where the umbilical or conduit is terminated, internal porting through the assembly will carry the control fluids or electrical conduits to the various functions within the Retainer Valve, Subsea Intervention Tree, Tubing Hanger Running Tool, Tubing Hanger and ultimately devices within the Completion string. This requirement for a large number of connections and intricate porting within the aforementioned devices particularly the Retainer Valve, Subsea Intervention Tree and Tubing Hanger; this creates multiple potential for leak paths or loss of electrical continuity for each conduit.
  • (2) Tubing Hanger Running tool: The Tubing Hanger Running tool is located directly below the Subsea Intervention tree and provides a facility to latch and unlatch the upper landing string from the Tubing hanger. This allows the temporary landing string to be removed leaving the production completion installed and locked. The Tubing hanger running tool can be mechanically or hydraulically actuated. Hydraulically actuated Tubing Hanger Running tools receive control pressure via conduits fed through from the Subsea Intervention valve assembly and also provides conduits for controlling the Tubing hanger and devices within the Completion string. These conduits represent multiple potential leak paths for each conduit.
  • (3) Tubing Hanger: The Tubing hanger forms the uppermost part of the permanent completion and facilitates the locking of the Completion into the production tree. The Tubing Hanger is traditionally hydraulically operated; the Tubing Hanger receives control pressure from surface via the conduits passed through the Tubing Hanger Running Tool, the Subsea Intervention valve, the Retainer Valve and the ‘In riser’ umbilical. It can be seen that this supply represents a torturous path with a multitude of potential leak paths. The interface between the Tubing hanger and the Production tree contains a series of stabs; these stabs facilitate the hydraulic or electrical communication between the production tree and Tubing hanger. Control pressures or electrical conduits are received from the production tree and then passed from the stabs down the completion string via a series of small-bore tubing or electrical conduits to control the various devices that make up the completion string.
  • (4) Production Tree: The Production Tree is a valve manifold that directs well effluent to the production facility via a side port. The production tree also acts as a control center for the completion itself; distributing hydraulic or electrical signals to the various down hole completion devices, which monitor, control or inject chemicals into the well. These controls are fed to the production Tree via a production umbilical and Junction or ‘J’ plate, which is deployed open water, from the production facility or the drilling vessel, depending on the phase of operation. Once connected to the production tree the controls are routed through the body and into the Tubing Hanger as described above via sets of stabs.
  • (5) Control System: The Control system is made up of a power unit comprising a pump and accumulators combined with hydraulic valves and regulators configured to control hydraulic pressures feeding various hydraulically operated devices. A control system can also regulate and supply electrical power to feed various electrically driven devices. A control system will also generally include the means of delivering the hydraulics or electrical power, i.e. an umbilical which is made up of hydraulic control lines or a combination of hydraulic control lines and electrical conduits thereof.
  • During completion running/pulling or workover operations Control elements (i.e fluids and/or electrical) are transferred from a floating offshore installation via a single or series of conduits to a junction plate. This junction plate is removable and attached to the Production tree (Generally, but not restricted to a Horizontal or spool type trees).
  • This junction plate locks the conduit/umbilical to the production tree and facilitates communication to a series of hydraulic ports/electrical conduits within the production tree wall. These ports will link to a set of stabs/receptacles located within or around the inner wall of the production tree and are isolated until such time as the mating tubing hanger is landed within its bore. The tubing hanger is deployed from the rig floor (Surface), through the bore of the Marine riser, into the BOP stack and landed on a location within the inner bore of the production tree. Typically a completion string will be attached to the lower end of the tubing hanger and a running tool c/w Landing string and well isolation devices (Typically, but not restricted to a Subsea Test/Intervention Tree and Retainer Valve) attached to the upper end.
  • The action of landing the Tubing hanger within the production tree will establish communication between the aforementioned stabs/receptacles and the Tubing hanger. Alternatively these stabs/receptacles may be energized to engage using external forces. These established communications provide monitoring or control to equipment located within the completion part or lower part of the inner assembly.
  • While the present invention has been described in terms of specific embodiments, it is to be understood that the invention is not limited to the disclosed embodiments. The invention may be embodied in many different forms and should not be construed as being limited to the embodiments set forth herein: rather, these embodiments are provided by way of illustration only and so that this disclosure will be thorough, complete and will fully convey the full scope of the invention to those skilled in the art. Indeed, many modifications and other embodiments of the invention will come to mind to those skilled in the art to which the invention pertains, and which are intended to be, and are covered by this disclosure, the drawings and the claims.

Claims (6)

1. Method of functioning and/or monitoring temporarily installed equipment through a Tubing Hanger. Comprising: Control System (Item 1), Subsea Production Tree (Item 13) & Tubing Hanger (Item 9). Delivering hydraulic or electrical controls from the vessel (Item 15) through a control system umbilical (Item 1), terminating at a junction plate (Item 11) mated to the Production Tree (Item 13). The Production Tree (Item 13) providing internal conduits communicating controls through a series of stabs (Item 10). Control of the Tubing Hanger (Item 9) and other equipment is established by landing the completion (Item 12) within the production Tree (Item 13) this has the effect of enabling the stabs (Item 10) and establishing communications with the completion equipment (Item 17) typically SCSSV, Electrical gauges and Chemical injection mandrels. Reconfiguring and adding stabs (Item 10) diverts controls up the assembly into the THRT (Item 7) and ultimately to other equipment. Establishing communication and control this way provides full functional control of the said devices. In order to maintain status of any unlatched elements of the system during disconnect activities the disconnection points will require hydraulic checking stabs, these will trap hydraulic pressure allowing the latch to reconnect and re-establish communications. This method of control requires that during the initial deployment prior to landing the Tubing hanger (Item 9) the operator will have no control over device functionality, and as such it will be necessary to trap control fluids within some chambers to lock components in preset positions, control will be regained subsequent to landing the Tubing Hanger (Item 9). Also, the operator may insist on monitoring pressure status, in this instance a pressure transducer could be fitted to transmit data to surface either by electrical conduit or other form of data transmission.
2. As per claim 1, data is being transmitted as opposed to hydraulics or electrical power.
3. As per claim 1, Chemicals or gas is being transmitted as opposed to hydraulics or electrical power.
4. As per claim 1, Hydraulic stabs or electrical connectors could be replaced by other methods of establishing communication such as spheriseals, sliding sleeves or seal gallery arrangements.
5. As per claim 1, The hydraulically operated Tubing Hanger may be replaced by a mechanically actuated hanger.
6. As per claim 1, communication between the Production Tree (Item 13) and the Tubing Hanger is established using pressure applied in the annulus below the BOP pipe rams or by applied pressure within the casing/tubing bore.
US11/818,955 2006-09-20 2006-09-20 Method of functioning and / or monitoring temporarily installed equipment through a Tubing Hanger. Abandoned US20080202761A1 (en)

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Application Number Priority Date Filing Date Title
US11/818,955 US20080202761A1 (en) 2006-09-20 2006-09-20 Method of functioning and / or monitoring temporarily installed equipment through a Tubing Hanger.
US11/901,393 US20080110633A1 (en) 2006-09-20 2007-09-17 Method of controlling landing strings in offshore operations

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Application Number Priority Date Filing Date Title
US11/818,955 US20080202761A1 (en) 2006-09-20 2006-09-20 Method of functioning and / or monitoring temporarily installed equipment through a Tubing Hanger.

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US11/901,393 Abandoned US20080110633A1 (en) 2006-09-20 2007-09-17 Method of controlling landing strings in offshore operations

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WO2011041550A2 (en) * 2009-10-02 2011-04-07 Schlumberger Canada Limited Subsea control system with interchangeable mandrel
WO2011041525A2 (en) * 2009-10-02 2011-04-07 Schlumberger Canada Limited Method and system for running subsea test tree and control system without conventional umbilical
US20110137471A1 (en) * 2009-12-09 2011-06-09 Schlumberger Technology Corporation Dual path subsea control system
US20110297387A1 (en) * 2008-10-10 2011-12-08 Cameron International Corporation Integrated Installation Workover Control System
WO2011159925A2 (en) * 2010-06-16 2011-12-22 Schlumberger Canada Limited Use of wired tubulars for communications/power in an in-riser application
US9556685B2 (en) * 2015-04-14 2017-01-31 Oceaneering International, Inc. Inside riser tree controls adapter and method of use
US10683721B2 (en) 2014-06-30 2020-06-16 Interventek Subsea Engineering Limited Test tree and actuator
US10890043B2 (en) 2015-05-08 2021-01-12 Fmc Kongsberg Subsea As System for remote operation of downhole well equipment

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US20110297387A1 (en) * 2008-10-10 2011-12-08 Cameron International Corporation Integrated Installation Workover Control System
US9062512B2 (en) * 2008-10-10 2015-06-23 Onesubsea Ip Uk Limited Integrated installation workover control system
GB2488054A (en) * 2009-10-02 2012-08-15 Schlumberger Holdings Method and system for running subsea test free and control system without conventional umbilical
GB2488256A (en) * 2009-10-02 2012-08-22 Schlumberger Holdings Subsea control system with interchangeable mandrel
WO2011041525A2 (en) * 2009-10-02 2011-04-07 Schlumberger Canada Limited Method and system for running subsea test tree and control system without conventional umbilical
WO2011041550A3 (en) * 2009-10-02 2011-06-30 Schlumberger Canada Limited Subsea control system with interchangeable mandrel
WO2011041525A3 (en) * 2009-10-02 2011-07-07 Schlumberger Canada Limited Method and system for running subsea test tree and control system without conventional umbilical
US20110079395A1 (en) * 2009-10-02 2011-04-07 Schlumberger Technology Corporation Method and system for running subsea test tree and control system without conventional umbilical
GB2488256B (en) * 2009-10-02 2015-04-01 Schlumberger Holdings Subsea control system with interchangeable mandrel
GB2488054B (en) * 2009-10-02 2015-02-18 Schlumberger Holdings Method and system for running subsea test free and control system without conventional umbilical
WO2011041550A2 (en) * 2009-10-02 2011-04-07 Schlumberger Canada Limited Subsea control system with interchangeable mandrel
US20110120722A1 (en) * 2009-10-02 2011-05-26 Schlumberger Technology Corporation Subsea control system with interchangeable mandrel
US8336629B2 (en) * 2009-10-02 2012-12-25 Schlumberger Technology Corporation Method and system for running subsea test tree and control system without conventional umbilical
US8839868B2 (en) * 2009-10-02 2014-09-23 Schlumberger Technology Corporation Subsea control system with interchangeable mandrel
US8708054B2 (en) * 2009-12-09 2014-04-29 Schlumberger Technology Corporation Dual path subsea control system
US20110137471A1 (en) * 2009-12-09 2011-06-09 Schlumberger Technology Corporation Dual path subsea control system
WO2011159925A3 (en) * 2010-06-16 2012-04-05 Schlumberger Canada Limited Use of wired tubulars for communications/power in an in-riser application
WO2011159925A2 (en) * 2010-06-16 2011-12-22 Schlumberger Canada Limited Use of wired tubulars for communications/power in an in-riser application
US10683721B2 (en) 2014-06-30 2020-06-16 Interventek Subsea Engineering Limited Test tree and actuator
US9556685B2 (en) * 2015-04-14 2017-01-31 Oceaneering International, Inc. Inside riser tree controls adapter and method of use
US10890043B2 (en) 2015-05-08 2021-01-12 Fmc Kongsberg Subsea As System for remote operation of downhole well equipment

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Owner name: DEEPBLUE TECHNOLOGIES, L.L.C., LOUISIANA

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Effective date: 20080426

Owner name: DEEPBLUE TECHNOLOGIES, L.L.C.,LOUISIANA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:TREWHELLA, ROSS JOHN;REEL/FRAME:020896/0149

Effective date: 20080426

STCB Information on status: application discontinuation

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