WO2025230427A1 - Subsea cut and pull method - Google Patents

Subsea cut and pull method

Info

Publication number
WO2025230427A1
WO2025230427A1 PCT/NO2025/050077 NO2025050077W WO2025230427A1 WO 2025230427 A1 WO2025230427 A1 WO 2025230427A1 NO 2025050077 W NO2025050077 W NO 2025050077W WO 2025230427 A1 WO2025230427 A1 WO 2025230427A1
Authority
WO
WIPO (PCT)
Prior art keywords
subsea
tubular
jack system
tubing
pulling
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.)
Pending
Application number
PCT/NO2025/050077
Other languages
French (fr)
Inventor
Andreas Fliss
Bjørn Tore TORVESTAD
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.)
Archer Oiltools AS
Original Assignee
Archer Oiltools AS
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 Archer Oiltools AS filed Critical Archer Oiltools AS
Publication of WO2025230427A1 publication Critical patent/WO2025230427A1/en
Pending legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/12—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground specially adapted for underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • 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
    • E21B40/00—Tubing catchers, automatically arresting the fall of oil-well tubing
    • 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
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like

Definitions

  • the present disclosure concerns intervention operations and P&A (plug and abandonment) operations in subsea wells.
  • P&A plug and abandonment
  • P&A operations in subsea wells are costly.
  • the well is plugged off by placing a cement barrier with possibly a plug system before the tubular is cut and the entire tubular removed from the well.
  • Removing entire tubing after cutting is a heavy operation requiring a topside rig. This is very expensive and time-consuming operation.
  • Removing the entire tubing also represent a high-risk operation due to heavy load and complexity of the operation.
  • use of explosives in a P&A operation represent a high risk.
  • Cut and pull operations are today performed with Cat.B drill rigs in a riser-based operation.
  • Use of vessels represents challenges related to vessel size and cost, vessel capability/tower lift capacity, vessel availability & cost and water depth.
  • the invention provides a method for performing a cut and pull operation in a subsea well.
  • the method comprising cutting a tubular in the subsea well below a barrier interval, and pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular, wherein the opening corresponds to the planned barrier of the subsea well.
  • Pulling the tubular may be performed by use of a subsea jack system.
  • a subsea jack system may be installed after cutting the tubular.
  • the method may further comprise before pulling the tubular, engaging the tubular, e.g. with a spear, and releasing a tubing hanger for the tubular.
  • the method may further comprise removing a tubing above the subsea jack system.
  • the method may further comprise after pulling the tubular, placing a barrier or remediate section in the planned barrier interval.
  • the method may further comprise after placing the barrier in the planned barrier, lowering the tubular onto the placed barrier.
  • the method may further comprise removing the subsea jack system after lowering the tubular onto the placed barrier.
  • the method may further comprise arranging a subsea jack system on a horizontal X-mas tree and performing pulling of the tubular by use of the subsea jack system through the horizontal X-mas tree.
  • the invention provides a method for creating an opening in a tubing in a wellbore, the method comprising cutting a tubular in the subsea well; pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular.
  • the method may further comprise pulling the tubular by use of a subsea jack system.
  • the method may further comprise pulling the tubular through an X-mas tree for the subsea well.
  • the method may further comprise pulling the tubular through an intervention module.
  • the method may further comprise pulling the tubular through the subsea jack system.
  • the method may further comprise removing a tubing above the subsea jack system.
  • the method may be performed in a riser-less intervention operation.
  • the method may be performed using an intervention vessel.
  • the invention provides a subsea jack system for a tubular in a wellbore comprising a jacking module for pulling the tubular out of hole; a spear module for engaging the tubular; and a cutter module for cutting the tubular.
  • the jacking module may further comprise a dual slip system or a caterpillar system.
  • the cutter module may be configured to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque.
  • the dual slip system may comprise a reciprocating system, preferably based on an inverted inchworm traction principle.
  • the dual slip system may include a rack and pinion system.
  • the caterpillar system may further comprise gripper blocks for reeled tubing injectors.
  • the subsea jack system may further comprise a lubricator module.
  • the subsea jack system may be configured to pulling the tubular through the subsea jack system.
  • the invention provides a vessel based subsea jack system for a tubular in a wellbore, the subsea jack system comprising a heave compensation system.
  • the vessel based subsea jack system may further comprise a pipe system for reaching the subsea wellhead and connecting to a tubular in the wellbore.
  • the jack system may be adapted to be installed in a moonpool of an intervention vessel.
  • the jack system may comprise a caterpillar system for pulling the pipe system.
  • the vessel based subsea jack system may further comprise a coiled tubing with injector head arranged on the vessel.
  • the invention provides an intervention vessel comprising a jack system according to above.
  • the invention provides use of an intervention vessel in a cut and pull operation according to the method disclosed above.
  • the invention provides use of the cut and pull operation according to the method disclosed above in a plug and abandonment operation.
  • the subsea jack system or the vessel based subsea jack system disclosed above may be used in a plug and abandonment operation.
  • the invention provides a method for performing a cut and pull operation in a subsea well.
  • the method comprising cutting a tubular in the subsea well below a barrier interval and pulling a length of the tubular to create an opening between an upper part of the tubular and a lower part of the tubular, wherein the opening corresponds to a planned barrier interval of the subsea well.
  • the tubular Before pulling the tubular, the tubular may be engaged and a tubing hanger for the tubular released.
  • the tubular may be engaged with a spear.
  • the method may further include pulling the length of the tubular by use of a subsea jack system.
  • the subsea jack system may be installed after cutting the tubular.
  • the method may further include removing a tubing above the subsea jack system.
  • a barrier may be placed in the planned barrier interval or a section may be remediated in the planned barrier interval.
  • the method may further include lowering the tubular onto the placed barrier after placing the barrier in the planned barrier interval.
  • the subsea jack system may be removed after lowering the tubular onto the placed barrier.
  • the subsea jack system may be arranged on a horizontal X-mas tree and pulling of the tubular through the horizontal X-mas tree may be performed by use of the subsea jack system.
  • the invention provides a method for creating an opening in a tubing in a wellbore.
  • the method comprising cutting a tubular in the subsea well and pulling a length of the tubular to create an opening between an upper part of the tubular and a lower part of the tubular.
  • the method may further comprise pulling the length of the tubular by use of a subsea jack system. Pulling the length of the tubular may be performed through an X-mas tree for the subsea well.
  • the method may include pulling the length of the tubular through an intervention module.
  • the method may include pulling the length of the tubular through the subsea jack system.
  • the method includes removing a tubing above the subsea jack system.
  • the method may be performed in a riserless intervention operation.
  • the method may be performed using an intervention vessel.
  • the invention provides a subsea jack system for a tubular in a wellbore.
  • the subsea jack system comprising a jacking module for pulling the tubular out of hole; a spear module for engaging the tubular; and a cutter module for cutting the tubular.
  • the jacking module may include a dual slip system or a caterpillar system.
  • the cutter module may be configured to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque.
  • the dual slip system may include a reciprocating system, preferably based on an inverted inchworm traction principle.
  • the dual slip system may alternatively include a rack and pinion system.
  • the caterpillar system may further comprise gripper blocks for reeled tubing injectors.
  • the subsea jack system may further comprise a lubricator module.
  • the subsea jack system is configured to pulling the tubular through the subsea jack system.
  • the invention provides a vessel based subsea jack system for a tubular in a wellbore.
  • the vessel based subsea jack system comprising a heave compensation system.
  • the vessel based subsea jack system may include a pipe system for reaching the subsea wellhead and connecting to a tubular in the wellbore.
  • the vessel based subsea jack may be configured to be installed in a moonpool of an intervention vessel.
  • the vessel based subsea jack system may comprise a caterpillar system for pulling the pipe system.
  • a coiled tubing with injector head may be arranged on the vessel.
  • the invention provides an intervention vessel comprising a jack system according above.
  • the invention provides use of an intervention vessel in a cut and pull operation according to the method disclosed above.
  • the invention provides use of the cut and pull operation according to the method above in a plug and abandonment operation.
  • the subsea jack system or the vessel based subsea jack system disclosed above may be used in a plug and abandonment operation.
  • the invention provides a method to create «short» windows through cut&pull operation on subsea wells using intervention vessels in a riser or riserless intervention operation.
  • the invention also provides a vessel based pull system or a subsea based pull system.
  • the invention enables P&A operations such as placing rock-to-rock barriers in subsea wells from intervention vessels (riserless operation).
  • Intervention vessels have limited capabilities compared to full size mobile rigs and thus require tailored solutions.
  • a customized solution that may be performed by an intervention vessel may be the deployment of a subsea jack system and use of the method to enable a cut & pull operation to open a «short» window in the tubular and place a TT rock-to-rock barrier as part of the P&A operation.
  • the window length will be just enough to place the barrier(s) (single or dual barrier, i.e. 30- 80m).
  • the tubing will be pulled up out of hole and then removed above the jack system.
  • the tubing is lifted/pulled up a length corresponding to the desired window in the tubular.
  • the operation downhole is then performed through the tubing that has been lifted.
  • the TT typically has a tubing size of 4.5" to 7" tubing size. There may potentially be a control line of the outside of tubing.
  • the invention enables reduction of operational steps, risk and uncertainties during planning and execution thus reducing significantly the cost of intervention and P&A operations on subsea wells.
  • Use of ablation downhole for cutting the tubing which represents a significant risk is avoided.
  • Creating a window (a short window) downhole by cutting the tubing will also cut the control line.
  • the control line may be pulled out together with the tubing.
  • the method also provides access to all tubings through a horizontal X-mas tree and/or intervention package on wellhead.
  • a vertical X-mas tree must be removed in order to access the wellhead.
  • the method reduces the complexity of the operation and enable plug-wash- cement operation to be performed through the window created downhole in the tubing.
  • the window has been created by lifting the tubing.
  • the window also enables easy access to 2 nd annulus.
  • the operation is performed through the tubular that has been lifted/pulled up.
  • the method for cutting and pulling a length of the tubular corresponding to a length of the barrier enables performing P&A operations by use of smaller vessels, e.g. a LCV RSUP and a LCV - Light Construction Vessel. Smaller vessels may be without moon pool and crane. BRIEF DESCRIPTION OF DRAWINGS
  • Fig.1 illustrates an exemplary well to be abandoned and with multiple tubulars.
  • An Xmas tree is arranged on top of a wellhead for the subsea well providing access to the well.
  • Fig.2 illustrates an exemplary horizontal subsea Xmas tree for a well.
  • Fig.3 illustrates an exemplary vertical subsea Xmas tree for a well.
  • Fig.4a - 4h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a horizonal Xmas tree.
  • Fig.5a-5h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a vertical Xmas tree.
  • Fig.6a-e illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well.
  • Fig.7a-c illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well under pressure.
  • Fig.8a-e illustrates an exemplary jack system for use in pulling a tubular upwards from a well, where the jack system is based on use of intervention vessel.
  • the subsea jack system is provided with a heave compensation system.
  • Example embodiments are described with reference to the drawings.
  • the example embodiments are not limiting for the disclosure.
  • the same reference numerals are used for the same or similar features in the drawings and the description.
  • the disclosure provides methods enabling performing cut&pull operation on subsea wells using intervention vessels.
  • the intervention vessels may be riser or riserless.
  • the disclosed method creates a window in the tubular downhole for intervention operations and /or P&A operations on the subsea well.
  • the window may be called a short window.
  • the window provides access to the annulus/annuli on the outside of the production tubing.
  • Subsea wells may have a single/dual barrier (min 30/60m length).
  • the length of the window may correspond to about a length of the single or dual barrier.
  • the TT typically has a 4.5" to 7" tubing size.
  • the operation has a number of challenges including:
  • the through tubing has restrictions related to the tubing size restricting the tool to be used in the operation.
  • the tubing size may be a 4.5" to 7" tubing size.
  • An exemplary method for performing a cut and pull operation in a subsea well includes cutting a tubular in the subsea well below a barrier interval. Cutting the tubular provides an upper part of the tubular and a lower part of the tubular. The upper part of the tubular is pulled to create an opening between the upper part of the tubular and the lower part of the tubular. The opening corresponds to a planned barrier interval of the subsea well. The opening may be called a tubing window. The method creates a «short» window in the tubular. The window has a length of minimum 30/60m corresponding to a length of a single/dual barrier in the wellbore.
  • An exemplary sequence of cutting and pulling a tubular in a well to create a window in the tubular downhole may be as follows:
  • Pulling the length of the tubular may be performed by use of a subsea jack system.
  • the subsea jack system may be deployed subsea.
  • the subsea jack system may be installed after cutting the tubular below the barrier interval.
  • the tubular may be engaged with e.g. a spear and a tubing hanger for the tubular released before pulling the tubular.
  • the tubular is pulled up through the subsea jack system.
  • the length of the tubular above the subsea jack system is therefore typically about 30m or about 60m. Only the tubing above the subsea jack system is removed. Use of a subsea jack system and only removing a small part of the tubing (about 30m- 60m) enables use of intervention vessels.
  • Pulling the tubular may also be performed by use of a vessel based pull system.
  • a barrier may be placed or remediate section performed in the planned barrier interval. After placing the barrier in the planned barrier interval, the tubular is lowered onto the placed barrier. The subsea jack system is removed after lowering the tubular onto the placed barrier.
  • the subsea jack system may be arranged on a horizontal X-mas tree. Pulling of the tubular may be performed by use of the subsea jack system through the horizontal X-mas tree.
  • the cut&pull operation on subsea wells may be performed using an intervention vessel in a riser or riserless intervention operation.
  • a further exemplary method for creating an opening in a tubing in a wellbore includes cutting a tubular in the subsea well. Pulling the tubular creates an opening between an upper part of the tubular and a lower part of the tubular. Pulling the length of the tubular may be performed by use of a subsea jack system. It is the upper part of the cut tubular that is pulled. The length of the tubular may be pulled through an X-mas tree for the subsea well. The length of the tubular may be pulled through an intervention module. The length of the tubular may be pulled through the subsea jack system.
  • the tubing above the subsea jack system may be removed.
  • the method may be performed in a riser-less intervention operation.
  • the method may be performed using an intervention vessel.
  • the subsea jack system includes a jacking module for pulling the tubular out of hole.
  • the jacking module creates a pulling force and pulls the tubing upwards and grips and locks the tubing.
  • the subsea jack system further includes a spear module for engaging the tubular.
  • the spear module engages and grips the tubing.
  • the subsea jack system also includes a cutter module for cutting the tubular.
  • the jacking module may further include a dual slip system or a caterpillar system.
  • the dual slip system may include a reciprocating system.
  • the dual slip reciprocating system may be based on an inverted inchworm traction principle.
  • the dual slip system may alternatively include a rack and pinion system.
  • the cutter module may be adapted to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque.
  • the caterpillar system may include gripper blocks for reeled tubing injectors.
  • the subsea jack module may a lubricator module.
  • the subsea jack system is adapted for pulling the tubular through the subsea jack system.
  • a vessel based subsea jack system may be used pulling and cutting the tubular in a wellbore.
  • the subsea jack system includes a heave compensation system.
  • a pipe system is provided for reaching the subsea wellhead and connecting to a tubular in the wellbore.
  • the vessel based jack system is adapted to be installed in a moonpool of an intervention vessel.
  • a caterpillar system may be used for pulling the pipe system connected to the tubular in the wellbore.
  • the heave compensation system compensates for motions of the vessel during the cut and pull operation.
  • a coiled tubing with injector head may be arranged on the vessel.
  • An exemplary sequence of cutting and pulling a tubular in a well including placing a planned barrier may be as follows:
  • An exemplary well 1 with multiple tubulars to be plugged and abandoned is illustrated in Fig.1 .
  • the well is provided with a subsea Xmas tree 5 providing access to the well.
  • An intervention package 6 is arranged on top of the Xmas tree.
  • a control line 4 is arranged on an outside of the production tubing 2.
  • the control line is arranged along the entire production tubing and down to one or more production packers 3. In other embodiments, the control line may be omitted.
  • the exemplary embodiments illustrated in this disclosure have control line present, but a control line may also not be present.
  • the subsea Xmas tree in Fig.1 may be a horizontal or vertical Xmas tree.
  • FIG.2 An exemplary horizontal subsea Xmas tree is illustrated in Fig.2.
  • a horizonal Xmas tree is provided with a central wellbore in which the tubing hanger 22 is arranged.
  • the tubing hanger attaches the production tubing in the well to the X-mas tree.
  • a horizontal Xmas tree provides easy access to tubing in the well.
  • the production tubing may be pulled through the X-mas tree.
  • a debris cap is arranged on top of the X-mas tree. The debris cap is removed to enable access to the tubing hanger and the tubular.
  • the tubing hanger is arranged under the internal isolation valve and crown plug enabling access to the tubular through the top of the Xmas tree through the debris cap as illustrated.
  • FIG.3 An exemplary vertical subsea Xmas tree is illustrated in Fig.3.
  • a vertical Xmas tree must be removed to enable access to the tubing hanger from above, as there is no access directly from above to engage the tubular on the tubing hanger.
  • the valves of the vertical X-mas tree are arranged in a vertical configuration blocking access to the tubing hanger and the tubular from above.
  • the vertical X-mas tree in Fig.3 has a production lower master valve a production upper valve and a production swab valve arranged above the tubing hanger. Also, an annulus master valve, an annulus swab valve are arranged above the tubing hanger.
  • a high-pressure cap is arranged on top of the vertical X-mas tree.
  • the vertical X-mas tree is also provided with an annulus wing valve, a production wing valve that may provide well fluid flow to the flowline.
  • a cross-over valve may also be provided after the production wing valve.
  • the vertical Xmas tree is removable and still allowing the flow lines to be connected.
  • the vertical Xmas tree may be removed by use of a vessel.
  • a vertical subsea X-mas tree has a number of advantages including:
  • a disadvantage of the vertical X-mas tree may be if workover operations such as recompletion, changing tubing, installing extra downhole tools etc. are required, a vertical tree must be removed in order to install BOP on top of the well.
  • Completion string must be removed if replacement of a tree is needed.
  • Example 1 The exemplary embodiments are examples only and not limiting for the disclosure.
  • Example 1
  • Fig.4a - 4h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a horizonal Xmas tree.
  • a horizontal X-mas tree enables easy access to tubing and tubing may be pulled through Xmas tree.
  • Fig.4a illustrates a subsea well 1 with production tubing 2, production packer(s) 3 and a control line 4 in a first annulus behind the production tubing.
  • the control line is attached to the outside of the production tubing with clamps.
  • the control line is illustrated in Fig.4a but the subsea well may also be without control line.
  • a horizontal X-mas tree 5 is arranged on the seafloor.
  • An intervention package 6 is arranged on top of the X-mas tree.
  • the production tubing is connected to the X- mas tree via a tubing hanger inside the X-mas tree.
  • An intervention vessel 7 is arranged above the subsea well. The intervention operation may be performed through the X-mas tree 5. Any debris cap is removed before accessing the subsea well.
  • Fig.4b the subsea well has been accessed through the intervention package and the Xmas tree.
  • the tubing is cut 10 below a planned barrier interval.
  • the cut may be called a deep tubing cut.
  • a subsea jack system 8 is installed as part of the intervention package as illustrated in Fig 4c.
  • the subsea jack system engages 11 the tubing through the intervention package and the Xmas tree.
  • the jack system engages the tubing in the well head.
  • the tubing is attached to the tubing hanger on the Xmas tree before engagement with the subsea jack system.
  • the subsea jack system may engage the tubing and release the tubing hanger.
  • the tubing may be engaged with a spear.
  • the spear is a part of the subsea jack system.
  • the subsea jack system pulls 13 the tubing (upwards) through the Xmas tree and intervention package and also through the subsea jack system itself.
  • the tubular is visible above the subsea jack system.
  • the tubular is pulled a tubing length equivalent to a barrier length to open a window 9 in the tubing as illustrated in Fig.4d.
  • a length of the planned barrier is typically about 30m or 60m.
  • the length of the tubular above the subsurface jack system is therefore typically about 30m or about 60m.
  • the tubing is locked 12 in this position during the next operational steps. The locking is performed by the subsea jack system.
  • the pulled tubing length may not be exactly the barrier length, but about the barrier length.
  • the purpose of opening a window in the tubing downhole is to be able to access the annulus/annuli outside of the tubular. Access of annulus/annuli enables the possibility to place a rock-to-rock barrier or perform another operation in the annulus/annuli as e.g. remediate section over tubing window.
  • the part of the tubing above the subsea jack system is removed 17 as illustrated in Fig. 4e.
  • the tubing is cut above jack system either in one or several sections.
  • the cut off tubing may be hoisted onto an intervention vessel. Hoisting of the cut off tubing may be performed using a lifting clamp or coil tubing.
  • the rock-to-rock barrier 14 may be placed in the window 9 downhole as illustrated in Fig.4f. Placing the rock-to-rock barrier may involve milling and plug-wash- cement operations. Placing of the rock-to-rock barrier is performed through the subsea jack system, the intervention package, the X-mas tree and through the tubing in the wellhead and through the tubing down to the open window subsea. Place barrier or remediate section over tubing window. The other operations involved in placing the barrier is also performed through the subsea jack system, the intervention package, the X-mas tree and through the tubing in the wellhead and through the tubing down to the open window subsea.
  • the tubing is lowered onto the newly placed rock-to-rock barrier 14 as illustrated in Fig.4g.
  • the tubing is unlocked 15 before lowered.
  • the tubing is lowered by the subsea jack system.
  • the subsea jack system As the part of the tubular corresponding to the barrier length above the subsea jack system has been cut off, the remaining tubular after being lowered down to the placed rock-to- rock barrier 14, will fit inside the wellbore and may be hung off at the tubing hanger in the Xmas tree.
  • the subsea jack system is removed as illustrated in Fig.4h.
  • Fig.5a - 5h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a vertical Xmas tree.
  • Fig.5a illustrates a subsea well 1 with production tubing 2, production packer(s) 3 and a control line 4 in a first annulus behind the production tubing.
  • the control line is attached to the outside of the production tubing with clamps.
  • the control line is illustrated in Fig.5a but the subsea well may also be without control line.
  • An intervention package 6 is arranged on the seafloor connected to the well tubing.
  • a vertical X-mas tree is arranged on top of the intervention package. The intervention operation cannot be performed through the vertical X-mas tree.
  • the vertical X-mas tree 16 is removed by an intervention vessel to provide access to the well through the intervention package 6.
  • Fig.5b the subsea well has been accessed through the intervention package.
  • the tubing is cut 10 below a planned barrier interval.
  • the cut may be called a deep tubing cut.
  • a subsea jack system 8 is installed on the intervention package as illustrated in Fig 5c.
  • the subsea jack system engages 11 the tubing through the intervention package.
  • the jack system engages the tubing in the well head.
  • the subsea jack system may engage the tubing with a spear and release the tubing hanger.
  • the subsea jack system pulls 13 the tubing (upwards) through the intervention package and also through the subsea jack system itself.
  • the tubular is visible above the subsea jack system.
  • the tubular is pulled a tubing length equivalent to a barrier length to open a window 9 in the tubing as illustrated in Fig.5d.
  • the window in the tubing may be called a tubing window.
  • a length of the planned barrier is typically about 30m or 60m.
  • the length of the tubing window is thus typically about 30m or 60m.
  • the length of the tubular above the subsea jack system is therefore also typically about 30m or about 60m.
  • the tubing is locked in this position during the next operational steps.
  • the locking is performed by the subsea jack system.
  • the pulled tubing length may not be exactly the barrier length, but about the barrier length.
  • the purpose of opening a window in the tubing downhole is to be able to access the annulus/annuli outside of the tubular. Access of annulus/annuli enables the possibility to place a rock-to-rock barrier 14 or perform another operation in the annulus/annuli as e.g. remediate section over tubing window.
  • the part of the tubing above the subsea jack system is removed as illustrated in Fig. 5e.
  • the tubing is cut above jack system either in one or several sections.
  • the cut off tubing may be hoisted onto an intervention vessel. Hoisting of the cut off tubing may be performed using a lifting clamp or coil tubing.
  • the rock-to-rock barrier 14 may be placed in the window 9 downhole as illustrated in Fig.5f. Placing the rock-to-rock barrier may involve milling and plug-wash- cement operations. Placing of the rock-to-rock barrier is performed through the subsea jack system, the intervention package and through the tubing in the wellhead and through the tubing down to the tubular window downhole.
  • the planned rock-to-rock barrier is placed in the tubular window.
  • Other operations involved in placing the planned rock-to-rock barrier is also performed through the subsea jack system, the intervention package, and through the tubing in the wellhead and through the tubing down to the open window downhole.
  • other operations like remediate section over tubing window may be performed.
  • the tubing is lowered onto the newly placed rock-to-rock barrier as illustrated in Fig.5g.
  • the tubing is unlocked 15 before lowered.
  • the tubing is lowered by the subsea jack system.
  • the subsea jack system As the part of the tubular corresponding to the barrier length above the subsea jack system has been cut off, the remaining tubular after being lowered down onto the placed rock- to-rock barrier 14, will fit inside the wellbore and may be hung off at the tubing hanger.
  • the subsea jack system is then removed as illustrated in Fig.5h.
  • Fig.6a-e illustrates an exemplary subsea jack system 60.
  • the subsea jack system is adapted for pulling a tubular upwards from a well.
  • the subsea jack system is also adapted for lowering the tubular into the well.
  • the subsea jack system enables cut&pull operation on subsea wells using and intervention vessel.
  • the subsea jack system comprising a jacking module 62 that creates a pulling force and pulls the tubing upwards.
  • the jacking module is also adapted for gripping/locking the tubing.
  • the subsea jack system also comprises a spear module 63 adapted for engaging the tubular.
  • the spear module is adapted for gripping the tubing.
  • the spear module is arranged under the jacking module.
  • the subsea jack system also comprises a cutter module 61 for cutting the tubing. The cutter module is arranged above the jack module.
  • the jacking module may be based on a dual slip system for creating the pulling force.
  • the dual slip system may be a dual slip reciprocating system.
  • the reciprocating system may operate according to an inverted inchworm traction principle.
  • the dual slip system may alternatively be a rack and pinion system.
  • the jacking module may be based on a caterpillar system for creating the pulling force.
  • the caterpillar system may include gripper blocks for reeled tubing injectors.
  • the spear module 63 is provided with a spear for engaging the tubing.
  • the spear for engaging the tubular is connected through a pipe to the jacking module as illustrated in Fig. 6b.
  • the size if the spear is adapted to the tubing size.
  • the cutter module is adapted to perform cutting of the tubular. As illustrated in Fig.6c the tubular is cut by the cutting module. The part of the tubular above the subsea jack system is lifted onto vessel by use of hoist or on coiled tubing (CT).
  • CT coiled tubing
  • the cutting of the tubular may be based on e.g. abrasive jetting, mechanical cutting, laser or torque. Use of laser may be performed as an underwater laser operation. Use of torque may e.g. include disconnect tubing joints by rotation with no cutting.
  • Fig.6d illustrates the subsea jack system with the part of the tubular above the jacking system removed.
  • Fig. 6e illustrates the subsea jacking module with tubing lowered onto placed barrier.
  • the subsea jacking system is provided with a lubricator module.
  • the lubricator module is arranged on top of the cutter module.
  • the lubricator module also has a function of sealing off the jacking system and the well after cutting the tubular.
  • Fig.7a illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well under pressure.
  • Fig.7a-c illustrates an exemplary subsea jack system for use in a cut and pull operation on a pressurized/live well. If the well is under pressure and pressure control equipment (PCE) needed a pressure tight system with a lubricator section is provided on top of the cutter module. The pressure tight system with a lubricator section is part of the lubricator module as explained above. The lubricator module has a seal function after cutting the tubular.
  • PCE pressure and pressure control equipment
  • Fig.7a illustrates pulling of the tubing upwards into the lubricator module.
  • the lubricator module is adapted for holding the tubing when pulled upwards.
  • the tubing is cut by the cutter module and a seal is provided between the cutter and the lubricator in the lubricator module.
  • the tubing is removed by the intervention vessel. The sequence is performed until the tubing has been cut off a length corresponding to a length of the tubular window required for the planned barrier.
  • lubricator module will hold the tubing when pulled upwards.
  • Fig.8a-e illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well.
  • the jack system is used together with an intervention vessel.
  • the vessel based jack system enable cut&pull operation on subsea wells using an intervention vessel.
  • the subsea jack system in Fig.8a-e is provided with a heave compensation system.
  • the heave compensation system is arranged on the intervention vessel.
  • a hydraulic jack system may be installed in a moon pool on the intervention vessel. When the hydraulic jack system is installed on the intervention vessel a pipe is used for reaching down to the subsea wellhead. This might not be practical in greater water depths, but may still be possible.
  • the jack system may utilize a «high capacity» coiled tubing setup (HD injector head, 100k lbs) or coiled tubing (CT) injector in combination with a pulling unit.
  • a «high capacity» coiled tubing setup HD injector head, 100k lbs
  • CT coiled tubing
  • the use of a coiled tubing setup may have the advantage of lowering complexity of equipment. Equipment limitations should however be considered.
  • Fig.8a illustrates an intervention vessel with a jack system installed in the moonpool of the intervention vessel.
  • the well is provided with a horizontal X-mas tree and with an intervention package on top.
  • the subsea well is provided with a control line on the outside of the production tubing down to the production packer, but as mentioned, the subsea well may also be without a control line.
  • the pipe of the subsea jack system has reached down to the subsea wellhead and engaged the tubing through the intervention package and the X-mas tree.
  • Fig.8c, 8d, 8e illustrates different exemplary embodiments of the jack system.
  • the jack system providing a pulling force for pulling the tubing free.
  • the jack system 80 is arranged on the vessel.
  • the jack system is provided with a caterpillar system providing the pulling force for pulling the tubing free.
  • the jack system 80 comprising a coiled tubing injector head 81 arranged on the vessel.
  • the coiled tubing injector head on the vessel run in / run out with coiled tubing within the operational limits.
  • the jack system in Fig.8d is provided with two caterpillar systems providing the pulling force for pulling the tubing free.
  • the jack system comprising a HD CT (coiled tubing) injector head 82 arranged on the vessel.
  • the HD CT (coiled tubing) injector head on the vessel run in I run out with coiled tubing within the operational limits.
  • the jack system is provided with a caterpillar system providing the pulling force for pulling the tubing free.

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Abstract

Method for performing a cut and pull operation in a subsea well The method comprising cutting a tubular in the subsea well below a barrier interval and pulling a length of the tubular to create an opening between an upper part of the tubular and a lower part of the tubular. The opening corresponds to a planned barrier interval of the subsea well. Methods enabling cut&pull operations on subsea wells using intervention vessels and/or in a riserless operation.

Description

SUBSEA CUT AND PULL METHOD
INTRODUCTION
The present disclosure concerns intervention operations and P&A (plug and abandonment) operations in subsea wells. In particular, methods and systems to enable cut&pull operations on subsea wells using intervention vessels and/or in a riserless operation.
BACKGROUND
P&A operations in subsea wells are costly. The well is plugged off by placing a cement barrier with possibly a plug system before the tubular is cut and the entire tubular removed from the well. Removing entire tubing after cutting is a heavy operation requiring a topside rig. This is very expensive and time-consuming operation. Removing the entire tubing also represent a high-risk operation due to heavy load and complexity of the operation. Also, use of explosives in a P&A operation represent a high risk.
Cut and pull operations are today performed with Cat.B drill rigs in a riser-based operation. Use of vessels represents challenges related to vessel size and cost, vessel capability/tower lift capacity, vessel availability & cost and water depth.
SUMMARY OF THE INVENTION
The invention provides a method for performing a cut and pull operation in a subsea well. The method comprising cutting a tubular in the subsea well below a barrier interval, and pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular, wherein the opening corresponds to the planned barrier of the subsea well.
Pulling the tubular may be performed by use of a subsea jack system. A subsea jack system may be installed after cutting the tubular. The method may further comprise before pulling the tubular, engaging the tubular, e.g. with a spear, and releasing a tubing hanger for the tubular. The method may further comprise removing a tubing above the subsea jack system. The method may further comprise after pulling the tubular, placing a barrier or remediate section in the planned barrier interval. The method may further comprise after placing the barrier in the planned barrier, lowering the tubular onto the placed barrier. The method may further comprise removing the subsea jack system after lowering the tubular onto the placed barrier. The method may further comprise arranging a subsea jack system on a horizontal X-mas tree and performing pulling of the tubular by use of the subsea jack system through the horizontal X-mas tree.
In a further aspect, the invention provides a method for creating an opening in a tubing in a wellbore, the method comprising cutting a tubular in the subsea well; pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular.
The method may further comprise pulling the tubular by use of a subsea jack system. The method may further comprise pulling the tubular through an X-mas tree for the subsea well. The method may further comprise pulling the tubular through an intervention module. The method may further comprise pulling the tubular through the subsea jack system. The method may further comprise removing a tubing above the subsea jack system. The method may be performed in a riser-less intervention operation. The method may be performed using an intervention vessel.
In a further aspect, the invention provides a subsea jack system for a tubular in a wellbore comprising a jacking module for pulling the tubular out of hole; a spear module for engaging the tubular; and a cutter module for cutting the tubular.
The jacking module may further comprise a dual slip system or a caterpillar system. The cutter module may be configured to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque. The dual slip system may comprise a reciprocating system, preferably based on an inverted inchworm traction principle. The dual slip system may include a rack and pinion system.
The caterpillar system may further comprise gripper blocks for reeled tubing injectors. The subsea jack system may further comprise a lubricator module. The subsea jack system may be configured to pulling the tubular through the subsea jack system. In a further aspect, the invention provides a vessel based subsea jack system for a tubular in a wellbore, the subsea jack system comprising a heave compensation system.
The vessel based subsea jack system may further comprise a pipe system for reaching the subsea wellhead and connecting to a tubular in the wellbore.
The jack system may be adapted to be installed in a moonpool of an intervention vessel. The jack system may comprise a caterpillar system for pulling the pipe system. The vessel based subsea jack system may further comprise a coiled tubing with injector head arranged on the vessel.
In a further aspect, the invention provides an intervention vessel comprising a jack system according to above.
In a further aspect, the invention provides use of an intervention vessel in a cut and pull operation according to the method disclosed above.
In a further aspect, the invention provides use of the cut and pull operation according to the method disclosed above in a plug and abandonment operation.
The subsea jack system or the vessel based subsea jack system disclosed above may be used in a plug and abandonment operation.
The invention provides a method for performing a cut and pull operation in a subsea well. The method comprising cutting a tubular in the subsea well below a barrier interval and pulling a length of the tubular to create an opening between an upper part of the tubular and a lower part of the tubular, wherein the opening corresponds to a planned barrier interval of the subsea well.
Before pulling the tubular, the tubular may be engaged and a tubing hanger for the tubular released. The tubular may be engaged with a spear.
The method may further include pulling the length of the tubular by use of a subsea jack system. The subsea jack system may be installed after cutting the tubular. The method may further include removing a tubing above the subsea jack system. After pulling the length of the tubular, a barrier may be placed in the planned barrier interval or a section may be remediated in the planned barrier interval. The method may further include lowering the tubular onto the placed barrier after placing the barrier in the planned barrier interval. The subsea jack system may be removed after lowering the tubular onto the placed barrier.
The subsea jack system may be arranged on a horizontal X-mas tree and pulling of the tubular through the horizontal X-mas tree may be performed by use of the subsea jack system.
In a further aspect, the invention provides a method for creating an opening in a tubing in a wellbore. The method comprising cutting a tubular in the subsea well and pulling a length of the tubular to create an opening between an upper part of the tubular and a lower part of the tubular.
The method may further comprise pulling the length of the tubular by use of a subsea jack system. Pulling the length of the tubular may be performed through an X-mas tree for the subsea well. The method may include pulling the length of the tubular through an intervention module. The method may include pulling the length of the tubular through the subsea jack system. The method includes removing a tubing above the subsea jack system. The method may be performed in a riserless intervention operation. The method may be performed using an intervention vessel.
In a further aspect, the invention provides a subsea jack system for a tubular in a wellbore. The subsea jack system comprising a jacking module for pulling the tubular out of hole; a spear module for engaging the tubular; and a cutter module for cutting the tubular.
The jacking module may include a dual slip system or a caterpillar system. The cutter module may be configured to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque. The dual slip system may include a reciprocating system, preferably based on an inverted inchworm traction principle. The dual slip system may alternatively include a rack and pinion system. The caterpillar system may further comprise gripper blocks for reeled tubing injectors. The subsea jack system may further comprise a lubricator module. The subsea jack system is configured to pulling the tubular through the subsea jack system.
In a further aspect, the invention provides a vessel based subsea jack system for a tubular in a wellbore. The vessel based subsea jack system comprising a heave compensation system. The vessel based subsea jack system may include a pipe system for reaching the subsea wellhead and connecting to a tubular in the wellbore. The vessel based subsea jack may be configured to be installed in a moonpool of an intervention vessel. The vessel based subsea jack system may comprise a caterpillar system for pulling the pipe system. A coiled tubing with injector head may be arranged on the vessel.
In a further aspect, the invention provides an intervention vessel comprising a jack system according above.
In an even further aspect, the invention provides use of an intervention vessel in a cut and pull operation according to the method disclosed above.
In an even further aspect, the invention provides use of the cut and pull operation according to the method above in a plug and abandonment operation.
The subsea jack system or the vessel based subsea jack system disclosed above may be used in a plug and abandonment operation.
The invention provides a method to create «short» windows through cut&pull operation on subsea wells using intervention vessels in a riser or riserless intervention operation. The invention also provides a vessel based pull system or a subsea based pull system.
The invention enables P&A operations such as placing rock-to-rock barriers in subsea wells from intervention vessels (riserless operation).
Intervention vessels have limited capabilities compared to full size mobile rigs and thus require tailored solutions. A customized solution that may be performed by an intervention vessel may be the deployment of a subsea jack system and use of the method to enable a cut & pull operation to open a «short» window in the tubular and place a TT rock-to-rock barrier as part of the P&A operation. The window length will be just enough to place the barrier(s) (single or dual barrier, i.e. 30- 80m). The tubing will be pulled up out of hole and then removed above the jack system. The tubing is lifted/pulled up a length corresponding to the desired window in the tubular. The operation downhole is then performed through the tubing that has been lifted. The TT typically has a tubing size of 4.5" to 7" tubing size. There may potentially be a control line of the outside of tubing.
The invention enables reduction of operational steps, risk and uncertainties during planning and execution thus reducing significantly the cost of intervention and P&A operations on subsea wells. Use of ablation downhole for cutting the tubing which represents a significant risk is avoided. Creating a window (a short window) downhole by cutting the tubing will also cut the control line. The control line may be pulled out together with the tubing.
The method also provides access to all tubings through a horizontal X-mas tree and/or intervention package on wellhead. A vertical X-mas tree must be removed in order to access the wellhead.
The method reduces the complexity of the operation and enable plug-wash- cement operation to be performed through the window created downhole in the tubing. The window has been created by lifting the tubing. The window also enables easy access to 2nd annulus. The operation is performed through the tubular that has been lifted/pulled up.
The method for cutting and pulling a length of the tubular corresponding to a length of the barrier enables performing P&A operations by use of smaller vessels, e.g. a LCV RSUP and a LCV - Light Construction Vessel. Smaller vessels may be without moon pool and crane. BRIEF DESCRIPTION OF DRAWINGS
Example embodiments are described with reference to the following drawings, where:
Fig.1 illustrates an exemplary well to be abandoned and with multiple tubulars. An Xmas tree is arranged on top of a wellhead for the subsea well providing access to the well.
Fig.2 illustrates an exemplary horizontal subsea Xmas tree for a well.
Fig.3 illustrates an exemplary vertical subsea Xmas tree for a well.
Fig.4a - 4h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a horizonal Xmas tree.
Fig.5a-5h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a vertical Xmas tree.
Fig.6a-e illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well.
Fig.7a-c illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well under pressure.
Fig.8a-e illustrates an exemplary jack system for use in pulling a tubular upwards from a well, where the jack system is based on use of intervention vessel. The subsea jack system is provided with a heave compensation system.
DETAILED DESCRIPTION
Example embodiments are described with reference to the drawings. The example embodiments are not limiting for the disclosure. The same reference numerals are used for the same or similar features in the drawings and the description.
The disclosure provides methods enabling performing cut&pull operation on subsea wells using intervention vessels. The intervention vessels may be riser or riserless. The disclosed method creates a window in the tubular downhole for intervention operations and /or P&A operations on the subsea well. The window may be called a short window. The window provides access to the annulus/annuli on the outside of the production tubing. Subsea wells may have a single/dual barrier (min 30/60m length). The length of the window may correspond to about a length of the single or dual barrier. The TT typically has a 4.5" to 7" tubing size.
Potentially (CL) control line on outside of the production tubing.
The operation has a number of challenges including:
• Operational complexity.
• Geometric challenges (restrictions). The through tubing has restrictions related to the tubing size restricting the tool to be used in the operation. The tubing size may be a 4.5" to 7" tubing size.
• Conveyance limitations.
• Vessel capabilities as e.g. circulation and pull capacity.
• Vessel space i.e. limited deck space on intervention vessel, fluid volumes etc. Limited contingencies
• Unknown downhole conditions (old wells).
An exemplary method for performing a cut and pull operation in a subsea well, includes cutting a tubular in the subsea well below a barrier interval. Cutting the tubular provides an upper part of the tubular and a lower part of the tubular. The upper part of the tubular is pulled to create an opening between the upper part of the tubular and the lower part of the tubular. The opening corresponds to a planned barrier interval of the subsea well. The opening may be called a tubing window. The method creates a «short» window in the tubular. The window has a length of minimum 30/60m corresponding to a length of a single/dual barrier in the wellbore.
An exemplary sequence of cutting and pulling a tubular in a well to create a window in the tubular downhole may be as follows:
1 . Deep tubing cut below planned barrier interval.
2. Pull barrier length equivalent to tubing length to open window.
Pulling the length of the tubular may be performed by use of a subsea jack system. The subsea jack system may be deployed subsea. The subsea jack system may be installed after cutting the tubular below the barrier interval. The tubular may be engaged with e.g. a spear and a tubing hanger for the tubular released before pulling the tubular. The tubular is pulled up through the subsea jack system. The length of the tubular above the subsea jack system is therefore typically about 30m or about 60m. Only the tubing above the subsea jack system is removed. Use of a subsea jack system and only removing a small part of the tubing (about 30m- 60m) enables use of intervention vessels.
Pulling the tubular may also be performed by use of a vessel based pull system.
After pulling the length of the tubular, a barrier may be placed or remediate section performed in the planned barrier interval. After placing the barrier in the planned barrier interval, the tubular is lowered onto the placed barrier. The subsea jack system is removed after lowering the tubular onto the placed barrier.
The subsea jack system may be arranged on a horizontal X-mas tree. Pulling of the tubular may be performed by use of the subsea jack system through the horizontal X-mas tree.
The cut&pull operation on subsea wells may be performed using an intervention vessel in a riser or riserless intervention operation.
A further exemplary method for creating an opening in a tubing in a wellbore, includes cutting a tubular in the subsea well. Pulling the tubular creates an opening between an upper part of the tubular and a lower part of the tubular. Pulling the length of the tubular may be performed by use of a subsea jack system. It is the upper part of the cut tubular that is pulled. The length of the tubular may be pulled through an X-mas tree for the subsea well. The length of the tubular may be pulled through an intervention module. The length of the tubular may be pulled through the subsea jack system.
The tubing above the subsea jack system may be removed. The method may be performed in a riser-less intervention operation. The method may be performed using an intervention vessel.
The subsea jack system includes a jacking module for pulling the tubular out of hole. The jacking module creates a pulling force and pulls the tubing upwards and grips and locks the tubing. The subsea jack system further includes a spear module for engaging the tubular. The spear module engages and grips the tubing. The subsea jack system also includes a cutter module for cutting the tubular. The jacking module may further include a dual slip system or a caterpillar system. The dual slip system may include a reciprocating system. The dual slip reciprocating system may be based on an inverted inchworm traction principle. The dual slip system may alternatively include a rack and pinion system. The cutter module may be adapted to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque. The caterpillar system may include gripper blocks for reeled tubing injectors. The subsea jack module may a lubricator module. The subsea jack system is adapted for pulling the tubular through the subsea jack system.
A vessel based subsea jack system may be used pulling and cutting the tubular in a wellbore. The subsea jack system includes a heave compensation system. A pipe system is provided for reaching the subsea wellhead and connecting to a tubular in the wellbore. The vessel based jack system is adapted to be installed in a moonpool of an intervention vessel. A caterpillar system may be used for pulling the pipe system connected to the tubular in the wellbore. The heave compensation system compensates for motions of the vessel during the cut and pull operation. A coiled tubing with injector head may be arranged on the vessel.
An exemplary sequence of cutting and pulling a tubular in a well including placing a planned barrier may be as follows:
1 . Deep tubing cut below planned barrier interval.
2. Install subsea jack system.
3. Engage tubing with spear and release tubing hanger.
4. Pull barrier length equivalent tubing length to open window using jack system.
5. Remove tubing above subsea jack system (cut & lift tubing).
6. Place barrier or remediate section over tubing window.
7. Lower tubing onto newly placed barrier.
8. Remove jack system.
The disclosed methods enable use intervention vessels and light construction vessels without moon pool and crane. An exemplary well 1 with multiple tubulars to be plugged and abandoned is illustrated in Fig.1 . The well is provided with a subsea Xmas tree 5 providing access to the well. An intervention package 6 is arranged on top of the Xmas tree. A control line 4 is arranged on an outside of the production tubing 2. The control line is arranged along the entire production tubing and down to one or more production packers 3. In other embodiments, the control line may be omitted. The exemplary embodiments illustrated in this disclosure have control line present, but a control line may also not be present.
The subsea Xmas tree in Fig.1 may be a horizontal or vertical Xmas tree.
An exemplary horizontal subsea Xmas tree is illustrated in Fig.2. A horizonal Xmas tree is provided with a central wellbore in which the tubing hanger 22 is arranged. The tubing hanger attaches the production tubing in the well to the X-mas tree. A horizontal Xmas tree provides easy access to tubing in the well. The production tubing may be pulled through the X-mas tree. A debris cap is arranged on top of the X-mas tree. The debris cap is removed to enable access to the tubing hanger and the tubular. In the exemplary embodiment in Fig.2, the tubing hanger is arranged under the internal isolation valve and crown plug enabling access to the tubular through the top of the Xmas tree through the debris cap as illustrated.
An exemplary vertical subsea Xmas tree is illustrated in Fig.3. A vertical Xmas tree must be removed to enable access to the tubing hanger from above, as there is no access directly from above to engage the tubular on the tubing hanger. The valves of the vertical X-mas tree are arranged in a vertical configuration blocking access to the tubing hanger and the tubular from above. The vertical X-mas tree in Fig.3 has a production lower master valve a production upper valve and a production swab valve arranged above the tubing hanger. Also, an annulus master valve, an annulus swab valve are arranged above the tubing hanger. A high-pressure cap is arranged on top of the vertical X-mas tree. The vertical X-mas tree is also provided with an annulus wing valve, a production wing valve that may provide well fluid flow to the flowline. A cross-over valve may also be provided after the production wing valve. The vertical Xmas tree is removable and still allowing the flow lines to be connected. The vertical Xmas tree may be removed by use of a vessel. A vertical subsea X-mas tree has a number of advantages including:
• Vertical trees require only on time BOP nipple down.
• No wireline plug to be removed from a tree for a well intervention program.
• Better for fields that do not expect to do workover or have small chance of doing workover.
• Simpler and cheaper to change a vertical tree than compared with a horizontal tree.
A disadvantage of the vertical X-mas tree may be if workover operations such as recompletion, changing tubing, installing extra downhole tools etc. are required, a vertical tree must be removed in order to install BOP on top of the well.
A horizontal subsea X-mas tree has a number of advantages including:
• Better for field that expect to do workover quite often because a tree does not need to be removed.
• May have a larger bore tubing for a horizontal tree than a vertical tree.
• A lower total height of a tree compared to a vertical tree.
A horizontal X-mas tree may also have a number of disadvantages including:
• Less flexibility for operation if the delivery of a tree is delayed.
• Two runs for subsea BOP and riser are required.
• Completion string must be removed if replacement of a tree is needed.
• Two wireline plugs (crown plugs) must be removed before starting any well intervention program. There have been several cases when people have faced a lot of difficulties for removing the plugs. This can lead to extra time and cost for the operation.
Exemplary embodiments
The exemplary embodiments are examples only and not limiting for the disclosure. Example 1
Horizontal X-mas Trees
Enable cut&pull operation on subsea wells using intervention vessels.
Fig.4a - 4h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a horizonal Xmas tree.
As explained above a horizontal X-mas tree enables easy access to tubing and tubing may be pulled through Xmas tree.
Fig.4a illustrates a subsea well 1 with production tubing 2, production packer(s) 3 and a control line 4 in a first annulus behind the production tubing. The control line is attached to the outside of the production tubing with clamps. The control line is illustrated in Fig.4a but the subsea well may also be without control line. A horizontal X-mas tree 5 is arranged on the seafloor. An intervention package 6 is arranged on top of the X-mas tree. The production tubing is connected to the X- mas tree via a tubing hanger inside the X-mas tree. An intervention vessel 7 is arranged above the subsea well. The intervention operation may be performed through the X-mas tree 5. Any debris cap is removed before accessing the subsea well.
In Fig.4b the subsea well has been accessed through the intervention package and the Xmas tree. As illustrated in Fig. 4b, the tubing is cut 10 below a planned barrier interval. The cut may be called a deep tubing cut.
A subsea jack system 8 is installed as part of the intervention package as illustrated in Fig 4c. The subsea jack system engages 11 the tubing through the intervention package and the Xmas tree. The jack system engages the tubing in the well head. The tubing is attached to the tubing hanger on the Xmas tree before engagement with the subsea jack system. The subsea jack system may engage the tubing and release the tubing hanger. The tubing may be engaged with a spear. The spear is a part of the subsea jack system. The subsea jack system pulls 13 the tubing (upwards) through the Xmas tree and intervention package and also through the subsea jack system itself. As illustrated in Fig.4d, the tubular is visible above the subsea jack system. The tubular is pulled a tubing length equivalent to a barrier length to open a window 9 in the tubing as illustrated in Fig.4d. A length of the planned barrier is typically about 30m or 60m. The length of the tubular above the subsurface jack system is therefore typically about 30m or about 60m. The tubing is locked 12 in this position during the next operational steps. The locking is performed by the subsea jack system.
The pulled tubing length may not be exactly the barrier length, but about the barrier length. The purpose of opening a window in the tubing downhole is to be able to access the annulus/annuli outside of the tubular. Access of annulus/annuli enables the possibility to place a rock-to-rock barrier or perform another operation in the annulus/annuli as e.g. remediate section over tubing window.
The part of the tubing above the subsea jack system is removed 17 as illustrated in Fig. 4e. The tubing is cut above jack system either in one or several sections. The cut off tubing may be hoisted onto an intervention vessel. Hoisting of the cut off tubing may be performed using a lifting clamp or coil tubing.
The rock-to-rock barrier 14 may be placed in the window 9 downhole as illustrated in Fig.4f. Placing the rock-to-rock barrier may involve milling and plug-wash- cement operations. Placing of the rock-to-rock barrier is performed through the subsea jack system, the intervention package, the X-mas tree and through the tubing in the wellhead and through the tubing down to the open window subsea. Place barrier or remediate section over tubing window. The other operations involved in placing the barrier is also performed through the subsea jack system, the intervention package, the X-mas tree and through the tubing in the wellhead and through the tubing down to the open window subsea.
After the rock-to-rock barrier is placed, the tubing is lowered onto the newly placed rock-to-rock barrier 14 as illustrated in Fig.4g. The tubing is unlocked 15 before lowered. The tubing is lowered by the subsea jack system. As the part of the tubular corresponding to the barrier length above the subsea jack system has been cut off, the remaining tubular after being lowered down to the placed rock-to- rock barrier 14, will fit inside the wellbore and may be hung off at the tubing hanger in the Xmas tree. The subsea jack system is removed as illustrated in Fig.4h.
Example sequence for horizontal X-mas tree
1 . Deep tubing cut below planned barrier interval.
2. Install subsea jack system.
3. Engage tubing with spear and release tubing hanger.
4. Pull barrier length equivalent tubing length to open window using jack system. Tubing can be pulled through horizontal X-mas tree.
5. Remove tubing above subsea jack system. a) Cut tubing above jack system either in one or several sections b) Hoist onto intervention vessel using lifting clamp or use coil tubing
6. Place barrier or remediate section over tubing window.
7. Lower tubing onto newly placed barrier.
8. Remove subsea jack system.
Example 2
Vertical X-mas Trees
Enable cut&pull operation on subsea wells using intervention vessel.
Vertical X-mas tree is to be removed before pulling tubing (can be done from vessel).
Fig.5a - 5h illustrates an exemplary sequence of cutting and pulling a tubular in a well with a vertical Xmas tree.
Fig.5a illustrates a subsea well 1 with production tubing 2, production packer(s) 3 and a control line 4 in a first annulus behind the production tubing. The control line is attached to the outside of the production tubing with clamps. The control line is illustrated in Fig.5a but the subsea well may also be without control line. An intervention package 6 is arranged on the seafloor connected to the well tubing. A vertical X-mas tree is arranged on top of the intervention package. The intervention operation cannot be performed through the vertical X-mas tree. The vertical X-mas tree 16 is removed by an intervention vessel to provide access to the well through the intervention package 6.
In Fig.5b the subsea well has been accessed through the intervention package. As illustrated in Fig. 5b, the tubing is cut 10 below a planned barrier interval. The cut may be called a deep tubing cut.
A subsea jack system 8 is installed on the intervention package as illustrated in Fig 5c. The subsea jack system engages 11 the tubing through the intervention package. The jack system engages the tubing in the well head. The subsea jack system may engage the tubing with a spear and release the tubing hanger.
The subsea jack system pulls 13 the tubing (upwards) through the intervention package and also through the subsea jack system itself. As illustrated in Fig.5d, the tubular is visible above the subsea jack system. The tubular is pulled a tubing length equivalent to a barrier length to open a window 9 in the tubing as illustrated in Fig.5d. The window in the tubing may be called a tubing window. A length of the planned barrier is typically about 30m or 60m. The length of the tubing window is thus typically about 30m or 60m. The length of the tubular above the subsea jack system is therefore also typically about 30m or about 60m. The tubing is locked in this position during the next operational steps. The locking is performed by the subsea jack system. The pulled tubing length may not be exactly the barrier length, but about the barrier length. The purpose of opening a window in the tubing downhole is to be able to access the annulus/annuli outside of the tubular. Access of annulus/annuli enables the possibility to place a rock-to-rock barrier 14 or perform another operation in the annulus/annuli as e.g. remediate section over tubing window.
The part of the tubing above the subsea jack system is removed as illustrated in Fig. 5e. The tubing is cut above jack system either in one or several sections. The cut off tubing may be hoisted onto an intervention vessel. Hoisting of the cut off tubing may be performed using a lifting clamp or coil tubing. The rock-to-rock barrier 14 may be placed in the window 9 downhole as illustrated in Fig.5f. Placing the rock-to-rock barrier may involve milling and plug-wash- cement operations. Placing of the rock-to-rock barrier is performed through the subsea jack system, the intervention package and through the tubing in the wellhead and through the tubing down to the tubular window downhole. As earlier explained the planned rock-to-rock barrier is placed in the tubular window. Other operations involved in placing the planned rock-to-rock barrier is also performed through the subsea jack system, the intervention package, and through the tubing in the wellhead and through the tubing down to the open window downhole. Instead of placing a rock-to-rock barrier, other operations like remediate section over tubing window may be performed.
After the rock-to-rock barrier is placed, the tubing is lowered onto the newly placed rock-to-rock barrier as illustrated in Fig.5g. The tubing is unlocked 15 before lowered. The tubing is lowered by the subsea jack system. As the part of the tubular corresponding to the barrier length above the subsea jack system has been cut off, the remaining tubular after being lowered down onto the placed rock- to-rock barrier 14, will fit inside the wellbore and may be hung off at the tubing hanger. The subsea jack system is then removed as illustrated in Fig.5h.
Example sequence vertical X-mas tree.
1 . Remove vertical X-mas tree.
2. Deep tubing cut below planned barrier interval.
3. Install subsea jack system.
4. Engage tubing with spear and release tubing hanger.
5. Pull barrier length equivalent tubing length to open window using jack system.
6. Remove tubing above subsea jack system. a) Cut tubing above jack system either in one or several sections. b) Hoist onto intervention vessel using lifting clamp or use coil tubing.
7. Place barrier or remediate section over tubing window.
8. Lower tubing onto newly placed barrier 9. Remove subsea jack system.
Subsea Jack system
Fig.6a-e illustrates an exemplary subsea jack system 60. The subsea jack system is adapted for pulling a tubular upwards from a well. The subsea jack system is also adapted for lowering the tubular into the well. The subsea jack system enables cut&pull operation on subsea wells using and intervention vessel.
An exemplary subsea jack system is illustrated in Fig.6a. The subsea jack system comprising a jacking module 62 that creates a pulling force and pulls the tubing upwards. The jacking module is also adapted for gripping/locking the tubing. The subsea jack system also comprises a spear module 63 adapted for engaging the tubular. The spear module is adapted for gripping the tubing. The spear module is arranged under the jacking module. The subsea jack system also comprises a cutter module 61 for cutting the tubing. The cutter module is arranged above the jack module.
The jacking module may be based on a dual slip system for creating the pulling force. The dual slip system may be a dual slip reciprocating system. The reciprocating system may operate according to an inverted inchworm traction principle. The dual slip system may alternatively be a rack and pinion system.
The jacking module may be based on a caterpillar system for creating the pulling force. The caterpillar system may include gripper blocks for reeled tubing injectors.
The spear module 63 is provided with a spear for engaging the tubing. The spear for engaging the tubular is connected through a pipe to the jacking module as illustrated in Fig. 6b. The size if the spear is adapted to the tubing size.
The cutter module is adapted to perform cutting of the tubular. As illustrated in Fig.6c the tubular is cut by the cutting module. The part of the tubular above the subsea jack system is lifted onto vessel by use of hoist or on coiled tubing (CT). The cutting of the tubular may be based on e.g. abrasive jetting, mechanical cutting, laser or torque. Use of laser may be performed as an underwater laser operation. Use of torque may e.g. include disconnect tubing joints by rotation with no cutting.
Fig.6d illustrates the subsea jack system with the part of the tubular above the jacking system removed. Fig. 6e illustrates the subsea jacking module with tubing lowered onto placed barrier.
If the well is under pressure, the subsea jacking system is provided with a lubricator module. The lubricator module is arranged on top of the cutter module. The lubricator module also has a function of sealing off the jacking system and the well after cutting the tubular. Fig.7a illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well under pressure.
Subsea Jack System (pressurized / «live» wells)
Fig.7a-c illustrates an exemplary subsea jack system for use in a cut and pull operation on a pressurized/live well. If the well is under pressure and pressure control equipment (PCE) needed a pressure tight system with a lubricator section is provided on top of the cutter module. The pressure tight system with a lubricator section is part of the lubricator module as explained above. The lubricator module has a seal function after cutting the tubular.
Fig.7a illustrates pulling of the tubing upwards into the lubricator module. The lubricator module is adapted for holding the tubing when pulled upwards.
In Fig.7b, the tubing is cut by the cutter module and a seal is provided between the cutter and the lubricator in the lubricator module. In Fig.7c, the tubing is removed by the intervention vessel. The sequence is performed until the tubing has been cut off a length corresponding to a length of the tubular window required for the planned barrier.
1 . Pull tubing upwards into lubricator, lubricator module will hold the tubing when pulled upwards.
2. Cut tubing and seal between cutter and lubricator with cut tubing.
3. Remove tubing.
4. Redo above steps to complete window. Vessel Based Jack system
Fig.8a-e illustrates an exemplary subsea jack system for use in pulling a tubular upwards from a well. The jack system is used together with an intervention vessel. The vessel based jack system enable cut&pull operation on subsea wells using an intervention vessel.
The subsea jack system in Fig.8a-e is provided with a heave compensation system. The heave compensation system is arranged on the intervention vessel. A hydraulic jack system may be installed in a moon pool on the intervention vessel. When the hydraulic jack system is installed on the intervention vessel a pipe is used for reaching down to the subsea wellhead. This might not be practical in greater water depths, but may still be possible.
The jack system may utilize a «high capacity» coiled tubing setup (HD injector head, 100k lbs) or coiled tubing (CT) injector in combination with a pulling unit. The use of a coiled tubing setup may have the advantage of lowering complexity of equipment. Equipment limitations should however be considered.
Fig.8a illustrates an intervention vessel with a jack system installed in the moonpool of the intervention vessel. The well is provided with a horizontal X-mas tree and with an intervention package on top. The subsea well is provided with a control line on the outside of the production tubing down to the production packer, but as mentioned, the subsea well may also be without a control line. The pipe of the subsea jack system has reached down to the subsea wellhead and engaged the tubing through the intervention package and the X-mas tree.
In Fig.8b the tubular is pulled upwards by the jack system through the X-mas tree and intervention package.
Fig.8c, 8d, 8e illustrates different exemplary embodiments of the jack system. The jack system providing a pulling force for pulling the tubing free.
In Fig. 8c, the jack system 80 is arranged on the vessel. The jack system is provided with a caterpillar system providing the pulling force for pulling the tubing free.
In Fig.8d the jack system 80 comprising a coiled tubing injector head 81 arranged on the vessel. The coiled tubing injector head on the vessel run in / run out with coiled tubing within the operational limits. The jack system in Fig.8d is provided with two caterpillar systems providing the pulling force for pulling the tubing free. In Fig.8e the jack system comprising a HD CT (coiled tubing) injector head 82 arranged on the vessel. The HD CT (coiled tubing) injector head on the vessel run in I run out with coiled tubing within the operational limits. The jack system is provided with a caterpillar system providing the pulling force for pulling the tubing free.
Having described example embodiments of the invention it will be apparent to those skilled in the art that other embodiments incorporating the concepts may be used. These and other examples illustrated above are intended by way of example only and the actual scope of the invention is to be determined from the following claims.

Claims

1 . Method for performing a cut and pull operation in a subsea well, the method comprising:
- cutting a tubular in the subsea well below a barrier interval;
- pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular, wherein the opening corresponds to the planned barrier of the subsea well.
2. Method according to claim 1 , further comprising pulling the tubular by use of a subsea jack system.
3. Method according to claim 1 , further comprising installing a subsea jack system after cutting the tubular.
4. Method according to claim 1 , further comprising before pulling the tubular, engaging the tubular, e.g. with a spear, and releasing a tubing hanger for the tubular.
5. Method according to claim 1 , further comprising removing a tubing above the subsea jack system.
6. Method according to claim 1 , further comprising after pulling the tubular, placing a barrier or remediate section in the planned barrier interval.
7. Method according to claim 6, further comprising after placing the barrier in the planned barrier, lowering the tubular onto the placed barrier.
8. Method according to claim 7, further comprising removing the subsea jack system after lowering the tubular onto the placed barrier.
9. Method according to one of claims 1-8, the method comprising arranging a subsea jack system on a horizontal X-mas tree and performing pulling of the tubular by use of the subsea jack system through the horizontal X-mas tree.
10. Method for creating an opening in a tubing in a wellbore, the method comprising:
- cutting a tubular in the subsea well;
- pulling the tubular to create an opening between an upper part of the tubular and a lower part of the tubular.
11 . Method according to claim 10, further comprising pulling the tubular by use of a subsea jack system.
12. Method according to claim 10 or claim 11 , further comprising pulling the tubular through an X-mas tree for the subsea well.
13. Method according to claim 11 , further comprising pulling the tubular through an intervention module.
14. Method according to one of claims 10-13, further comprising pulling the tubular through the subsea jack system.
15. Method according to one of claims 10-14, further comprising removing a tubing above the subsea jack system.
16. Method according to one of claims 1-15, wherein the method is performed in a riser-less intervention operation.
17. Method according to one of claims 1-15, wherein the method is performed using an intervention vessel.
18. Subsea jack system for a tubular in a wellbore comprising:
- a jacking module for pulling the tubular out of hole;
- a spear module for engaging the tubular; and
- a cutter module for cutting the tubular.
19. Subsea jack system according to claim 18, wherein the jacking module further comprising a dual slip system or a caterpillar system.
20. Subsea jack system according to one of claims 18-19, wherein the cutter module is configured to perform cutting by use of at least one of abrasive jetting, mechanical cutting, laser or torque.
21 . Subsea jack system according to one of claims 19-20, wherein the dual slip system comprising a reciprocating system, preferably based on an inverted inchworm traction principle.
22. Subsea jack system according to one of claims 19-21 , wherein the dual slip system includes a rack and pinion system.
23. Subsea jack system according to one of claims 19-22, wherein the caterpillar system further comprising gripper blocks for reeled tubing injectors.
24. Subsea jack system according to one of claims 18-24, further comprising a lubricator module.
25. Subsea jack system according to one of claims 18-24, wherein the subsea jack system is configured to pulling the tubular through the subsea jack system.
26. Vessel based subsea jack system for a tubular in a wellbore, the subsea jack system comprising a heave compensation system.
27. Vessel based subsea jack system according to claim 26, further comprising a pipe system for reaching the subsea wellhead and connecting to a tubular in the wellbore.
28. Vessel based subsea jack system according to claim 26 or 27, wherein the jack system is adapted to be installed in a moonpool of an intervention vessel.
29. Vessel based subsea jack system according to one of claims 26-28, wherein the jack system comprises a caterpillar system for pulling the pipe system.
30. Vessel based subsea jack system according to one of claims 26-29, further comprising a coiled tubing with injector head arranged on the vessel.
31 . Intervention vessel comprising a jack system according to one of claims 18- 30.
32. Use of an intervention vessel in a cut and pull operation according to the method in one of claims 1 -17.
33. Use of the cut and pull operation according to the method in one of claims 1-17 in a plug and abandonment operation.
34. Use of the subsea jack system according to one of claims 18-25 or the vessel based subsea jack system according to one of claims 26-30 in a plug and abandonment operation.
PCT/NO2025/050077 2024-05-03 2025-05-05 Subsea cut and pull method Pending WO2025230427A1 (en)

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