EP4062029B1 - Distribution de fluide à une tête de puits sous-marine - Google Patents

Distribution de fluide à une tête de puits sous-marine Download PDF

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Publication number
EP4062029B1
EP4062029B1 EP20889513.6A EP20889513A EP4062029B1 EP 4062029 B1 EP4062029 B1 EP 4062029B1 EP 20889513 A EP20889513 A EP 20889513A EP 4062029 B1 EP4062029 B1 EP 4062029B1
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EP
European Patent Office
Prior art keywords
fluid
connector
subsea
hose
per minute
Prior art date
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Application number
EP20889513.6A
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German (de)
English (en)
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EP4062029A4 (fr
EP4062029A1 (fr
Inventor
Leif KVARME
John Spence
Birger HEIGRE
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ConocoPhillips Co
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ConocoPhillips Co
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Priority claimed from PCT/US2020/061534 external-priority patent/WO2021102277A1/fr
Publication of EP4062029A1 publication Critical patent/EP4062029A1/fr
Publication of EP4062029A4 publication Critical patent/EP4062029A4/fr
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
    • E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells
    • E21B33/076—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations

Definitions

  • This invention relates to the delivery of fluid, such as pressurized fluid, for example acid, to a hydrocarbon well via a wellhead installed on the seabed.
  • fluid such as pressurized fluid, for example acid
  • high rate acid stimulation pumping is normally performed via a workover riser from a jack-up rig or semi-submersible rig.
  • a specialized vessel is brought to the jack up rig and a hose from the vessel inserted into a suitable connector on the rig to supply fluid from the vessel to the subsea well via the workover riser between the jack up and the subsea Xmas tree.
  • a workover riser is a riser that provides a conduit from the upper connection on the subsea tree to the surface, and which allows the passage of wireline tools and fluids into the wellbore.
  • a workover riser can be run in open water without a drilling marine riser and therefore it shall be able to withstand the applied environmental forces, i.e. wind, waves and currents, or can be used in combination with drilling marine riser or a high pressure riser system.
  • a workover riser is typically used during the installation of the upper completion tubing hanger were wireline operations will be required during installation and testing of the upper completion and during wellbore re-entries which require full bore wireline tool access, it can also be used for the retrieval of the tubing hanger and production tubing.
  • a workover riser typically consists of the following: the tubing hanger running tool; intermediate riser joints; lubricator valve(s) to isolate the riser during loading/unloading of long wireline tool strings; a surface tree for pressure control of the wellbore and to provide a connection point for a surface wireline lubricator system; and a means of tensioning the riser, so that it does not buckle under its own weight; a wireline or coiled-tubing BOP, capable of gripping, cutting and sealing coiled tubing or wireline.
  • a Subsea Test Tree for use on semi-submersible rigs it may also include a Subsea Test Tree and an emergency-disconnect package capable of high-angle release; retainer valve to retain the fluid contents of the riser during an emergency disconnect; a stress joint to absorb the higher riser bending stresses at the point of fixation to the Subsea Test Tree.
  • a workover riser is thus a complicated and heavy-duty piece of equipment which is designed to be used for a wide variety of operations, including the relatively simple process of injection of fluids into the production bore of a well.
  • the daily cost of a jack up rig is very high. It would be preferable to be able to avoid the use of both a jack up rig and a workover riser and be able to inject fluid directly from the specialized vessel to the subsea well.
  • the inventors are not aware of any existing equipment which could be used for acid stimulation by direct connection between a vessel (a so-called "stim vessel”) and a subsea Xmas tree.
  • the terms “comprises,” “comprising,” “includes,” “including,” “has,” “having” or any other variation thereof, are intended to cover a non-exclusive inclusion.
  • a process, product, article, or apparatus that comprises a list of elements is not necessarily limited only those elements but can include other elements not expressly listed or inherent to such process, process, article, or apparatus.
  • "or” refers to an inclusive or and not to an exclusive or. For example, a condition A or B is satisfied by any one of the following: A is true (or present) and B is false (or not present), A is false (or not present) and B is true (or present), and both A and B are true (or present).
  • substantially is defined to be essentially conforming to the particular dimension, shape or other word that substantially modifies, such that the component need not be exact.
  • substantially cylindrical means that the object resembles a cylinder, but can have one or more deviations from a true cylinder.
  • any examples or illustrations given herein are not to be regarded in any way as restrictions on, limits to, or express definitions of, any term or terms with which they are utilized. Instead these examples or illustrations are to be regarded as being described with respect to one particular example and as illustrative only. Those of ordinary skill in the art will appreciate that any term or terms with which these examples or illustrations are utilized encompass other examples as well as implementations and adaptations thereof which can or cannot be given therewith or elsewhere in the specification and all such examples are intended to be included within the scope of that term or terms. Language designating such non-limiting examples and illustrations includes, but is not limited to: “for example,” “for instance,” “e.g.,” “In some examples,” and the like.
  • the system further includes an inlet to provide hydraulic pressure to the hydraulic actuator and open the valve and an outlet to vent hydraulic pressure from the hydraulic actuator and close the valve.
  • US2015/0292229 discloses an apparatus and system for accessing a flow system (such as a subsea tree) in a subsea oil and gas production system, and method of use.
  • the apparatus comprises a body defining a conduit therethrough and a first connector for connecting the body to the flow system.
  • a second connector is configured for connecting the body to an intervention apparatus, such as an injection or sampling equipment.
  • the conduit provides an intervention path from the intervention apparatus to the flow system.
  • aspects of the invention relate to combined injection and sampling units, and have particular application to well scale squeeze operations.
  • US2016/0362956 discloses a subsea chemical injection system having a subsea structure, a manifold connected by jumper to the subsea structure, a coiled tubing, a disconnect mechanism affixed to the coiled tubing, and a hose extending from the disconnect mechanism to the manifold such that the chemical flowing through the coil tubing can selectively flow through the disconnect mechanism and through the hose to the subsea structure.
  • the disconnect mechanism is adapted to selectively release from the hose.
  • the disconnect mechanism has a connector affixed thereto. A hydraulic fluid supply is connected to the connector so as to selectively release the connector from the hose.
  • Control lines can extend from a surface location to a control module and the disconnect mechanism for selectively delivering for receiving signals from the subsea structure.
  • US2018/0038190 discloses an apparatus for effecting injection of fluids into a subsea horizontal tree including a fluid injection tree cap having a body with a bore extending therethrough so as to open at one end to a top of the body. An isolation valve is cooperative with the bore of the body so as to open or close fluid flow through the bore.
  • the fluid injection tree cap is connected to the horizontal subsea tree.
  • the horizontal subsea tree has only a single crown plug therein.
  • the bore of the fluid injection tree cap communicates with an annulus of the horizontal subsea tree.
  • the horizontal subsea tree has valving therein so as to selectively direct fluid from the bore of the tree cap to the annulus of the well or to the horizontal subsea tree.
  • the invention more particularly includes a pressurized fluid (e.g. acid) injection assembly as described in the appended claims, for example for delivery of fluid at rates detailed below.
  • a pressurized fluid e.g. acid
  • the invention is suitable for, but not limited to, an apparatus and method for delivery of acid to a formation (acid stimulation). Acid is normally delivered at a high rate in comparison to other fluid.
  • the apparatus is therefore, optionally, suitable for delivery of fluid at a rate of up to 15,000 liters per minute (or between 5,000 and 15,000 liters per minute), such as up to 15,000 liters per minute (or between 8,000 and 12,000 liters per minute), such as up to about 10,000 liters per minute.
  • the method may include the step of delivering fluid, such as acid for acid stimulation, at a rate in these ranges.
  • a fail-safe close valve is a valve which is biased by some means to the closed position and requires active control, e.g. hydraulic pressure or an electric signal, to open it.
  • a hose is a flexible conduit suitable for delivering fluid.
  • the second conduit and fail-safe close valve may have an unobstructed internal diameter of at least 102mm (4"), such as 102mm to 152mm (4" to 6"), to allow a ball of 76-102mm (3-4") diameter, e.g. 89mm (3.5") or 95mm (3.75”) diameter, to be dropped.
  • This size is an industry standard, but the exact dimensions of the ball and unobstructed pathway are not central to the invention and a range of diameters for the pathway and ball are possible, e.g. from 51mm to 254mm (2" to 10"), such as from 76mm to 203mm (3" to 8").
  • the connector at the second end of the hose may be a quick release connector.
  • the hose may include a weak link and/or swivel assembly and/or buoyancy modules.
  • the template may include a support bracket for the hose.
  • the invention also provides a method of delivering pressurized fluid to a subsea hydrocarbon wellhead, as described in the appended claims.
  • a subsea wellhead 1, part of a subsea template 2 and Xmas tree 3 is shown.
  • the template 2 serves more than one well (normally four), and a corresponding number of Xmas trees are mounted on the template one being shown at reference 3.
  • the Xmas tree 3 is an assembly of conduits and valves, as is well known in the oil and gas field.
  • an internal conduit 4 of the Xmas tree is connected via a seal sub assembly to the production tubing 5 of the well.
  • a downhole safety valve 6 In the production tubing is a downhole safety valve 6 and further up in the Xmas tree conduit is a production master valve 7.
  • Both of these valves are operable via a subsea control module 8 which is in turn connected via a service umbilical and jumpers cables to the control room of a production platform from which the well is operated; this platform could be many kilometers away.
  • the service umbilical and jumpers, and platform are not shown but are conventional, and include, e.g., electrical and/or optical fiber communications 42 and hydraulic supply 41.
  • the production master valve is the production swab valve 9, which is manually operated.
  • the valve would normally be opened or closed by a work class subsea remote operated vehicle (WROV).
  • WROV work class subsea remote operated vehicle
  • At the top of the Xmas tree there would normally be a Tree cap, which provides protection to the Xmas tree re-entry hub and provides an additional mechanical well barrier; this is not shown in Figure 1 but is entirely conventional.
  • Xmas trees may incorporate further valves, for example a second production master valve, but this is not relevant to the invention.
  • connection to the production platform for the production of hydrocarbons from the well is not shown but is conventional: hydrocarbons that come up the production tubing are routed through the production bore of the Xmas tree and the flow control module, then leave the Xmas tree via a manifold hub pipework and are then routed into the manifold pipelines which feed into the production line to the platform.
  • Figure 1 shows a pressurized fluid injection assembly 20 at the top of the Xmas tree.
  • a re-entry hub 35 onto which an "H4 connector" (conventional in this art) locks; there is also an internal stinger (also conventional in this art).
  • the assembly is lowered onto the Xmas tree by crane and guided into position by a WROV, using the standard connections.
  • the assembly 20 comprises a fail-safe close valve 21 and a gooseneck 22 to support the female hub 23 and to provide the correct angle and elevation to allow the complimentary male hub 25 of the hose 28 to be connected to the female hub 23 above the ITS structure (conventional in this art).
  • the female connector 23 includes a guide funnel 24 to assist in attachment of the male connector fitting 25.
  • the hose is standard, flexible, high pressure hose, able to withstand pressures of up to 68948 kPa (10,000psi) and to withstand acid and other chemicals which may be delivered down the hose.
  • the hose 28 and male hub 25 are lowered into position using a crane (not shown).
  • the production master valve (PMV) and downhole safety valve(s) (DHSV) are shut by signals from the production platform central control room (CCR).
  • the production swab valve (PSV) is shut by direct manipulation by a WROV or potentially by divers using an ROV torque tool.
  • the connection between the hose and fluid injection assembly is then made by WROV, and the PMV, DHSV(s) and PSV opened.
  • the communication between production tubing and the hose is controlled via the fail-safe close (FSC) valve 21 on the fluid injection assembly 20 installed on the Xmas tree.
  • the FSC valve has a hydraulic control line 31 running up to a control unit 32 on the vessel 33. This valve is thereby controlled exclusively from the vessel.
  • the fail-safe valve is of a standard gate valve design, incorporating a spring actuator to provide the means for the valve to move_to the closed position if the hydraulic supply pressure is removed,_as is well known in the oil and gas field.
  • the other end of the hose 28 is connected via a quick release connection 29 of known type to fluid supply apparatus 30 on board the vessel 33.
  • a fail-safe valve is a valve which will be in a closed configuration (thereby blocking/sealing a fluid channel) unless actively maintained in an open configuration by some means, e.g. hydraulic pressure or a applied electric voltage.
  • a typical fail-safe valve is shown.
  • the valve is inserted in a fluid line having an open channel 50.
  • the valve comprises a housing 51 defining a bore 52 perpendicular to and communicating with the channel 50.
  • a valve member 53 is movable in the bore to block the channel 50.
  • the valve is shown with the valve member 53 in an open configuration where it is retracted into the bore and does not block the channel 50.
  • the valve member 53 is connected to a hydraulic actuator 54.
  • a supply of hydraulic fluid (not shown) is connected to the actuator via hydraulic connector 55.
  • a spring 56 is arranged concentrically around the actuator 54 and biases the valve member into the closed position.
  • the hydraulic actuator 54 when energized by pressurized hydraulic fluid, works against the force of the spring 56 in order to open the valve.
  • the FSC valve When fluid, such as acid, is to be delivered to the well, the FSC valve is opened from the vessel via a hydraulic control line 31, the PMV, PSV and DHSV(s) having all been opened previously.
  • the connection between the hose 28 and the fluid supply reel on the vessel is a quick release connector 29 and is designed such that if the vessel cannot remain in the correct position, e.g. due to weather conditions or a Drive off/Drift off scenario, an accumulator supplied, high pressure hydraulic fluid will be directed to the quick release connector and the hose quickly released and dropped from the hose reel.
  • the FSC valve on the fluid injection assembly 20 on the Xmas tree will also be closed as part of a programmed Emergency Quick Disconnect (EQD) logic sequence from the vessel.
  • EQD Emergency Quick Disconnect
  • the system can safely shut in the production bore and release the hose from the hose reel independent from the production platform.
  • the Well Intervention Supervisor located on the production platform who controls the PMV and DHSV(s) will be in full time communication with the vessel throughout the fluid pumping operations.
  • the vessel may be a specialized "stim vessel” carrying acid for acid stimulation, and a suitable pump.
  • acid stimulation it is required to be able to drop one or more dissolvable balls from the stim vessel through the hose and through the production tubing to activate the injection assemblies installed in the reservoir liner which controls where the acid is finally delivered to the formation. This would normally be done via a workover riser which has sufficient clearance throughout the riser for balls to be dropped.
  • the use of a fail-safe close valve controlled by the stim vessel obviates the need for check valves which would otherwise obstruct the passage of a ball and potentially damage to the valves and the dissolvable balls preventing effective use.
  • the invention provides a means of pumping acid from a stimulation vessel on surface via a pressure rated subsea hose directly into the vertical production bore of a vertical Xmas tree (VXT) and into the reservoir via the stim cap (or fluid injection assembly).
  • VXT vertical Xmas tree
  • stim cap or fluid injection assembly
  • FSC fail-safe close
  • a manual production swab valve operated by an ROV torque tool
  • a production master valve controlled from the host platform central control room (CCR)
  • DHSV down hole safety valves
  • the purpose of this operation is to allow acid to be pumped at high pressure and at a high flow rate into the formation rock via the production bore (first conduit) of the VXT and production tubing and reservoir liner, to acid frac and dissolve the formation rock to increase to the flow rate of hydrocarbons back into the reservoir liner during production.
  • the pre-installed internal tree cap is first recovered to surface from the VXT and replaced with an external H4 connector/stim cap assembly, an interface VX gasket installed between the H4 connector, and then the VXT re-entry hub is pressure tested.
  • the stim hose assembly (minimum 102mm (4") ID with no restrictions or check valves in-line) is connected to a swivel 27 using a grayloc connector (conventional in this art).
  • the swivel is complete with a weak link sub 26 and male connector; this is lowered subsea and locked onto the SeAlign female hub of the pre-installed stim cap assembly.
  • the FSC is opened from the vessel, the PSV is opened using an ROV torque tool, the PMV and DHSV's are opened from the Production platform CCR via a subsea control module (SCM) installed on the VXT.
  • SCM subsea control module
  • a dissolvable ball up to 3.75" diameter is inserted into a stim hose manifold located upstream of a stim hose reel on the vessel, the ball is then pumped through the stim hose, stim cap, VXT production bore, production tubing and reservoir liner onto the ball seat of a sliding sleeve assembly that has been pre-installed in the reservoir liner.
  • Acid is then pumped under high pressure (up to 51711 kPa (7,500psi)) to push on the ball seat, which in turn pushes the sliding sleeve to an open position, allowing the acid to be pumped through open ports into the formation rock.
  • Acid stimulation pumping operations can then commence (min. flow rate of 60 Barrels/min required for these stim operations.)
  • the well is shut-in from the platform CCR, by closing the DHSV & PMV, then closing the PSV using the ROV Torque Tool.
  • the stim hose and stim cap are then disconnected and recovered to surface, the internal tree cap is then reinstalled into the VXT and pressure tested, in accordance with equipment manufacturers procedures.
  • the components of the stim. cap include the following:
  • H4 Connector upper assembly is an RLWI adaptor, with a 346mm (13 5/8") 10k SL-215 connector, which provides an interface for the FSC valve to be connected to the top of the RLWI adaptor installed on top of the H4 Connector;
  • H4 Connector internal lower connection is a production seal stab, used to guide a dropped ball directly into the production bore of the VXT; the production seal stab also provides a pressure retaining connection between the production bore of the VXT and the Stim hose via the stim cap assembly;
  • Fail safe closed valve to provide a means to shut-in and seal the well bore independently from the platform control, this valve is controlled directly from various locations onboard the stim vessel;
  • the FSC valve also acts as an adaptor crossover assembly from SL-215 speedlok - API flange;
  • the female SeAlign hub is complete with a primary guidance funnel to assist with the alignment of the stim hose male hub and incorporates the connector locking mechanism and retention pins to be used during installation of the male hub.
  • Male SeAlign connector hub provides an interface between the stim hose and the female hub mounted on the gooseneck on the preinstalled Stim cap assembly, it also carries a changeable seal ring that is located between the male and female hubs;
  • Male SeAlign connector does not have a quick release function, as it is not required for this application since the quick release system is provided at the hose reel;
  • a weak link assy To provide a pressure balanced weak link to reduce the potential for damage to the subsea asset in the event of the vessel not keeping station and the hose reel connector not releasing the hose.
  • Buoyancy modules 34 to assist with installation of male hub into female hub and to protect the paintwork of the ITS structure
  • EQD Hydraulic connector
  • Ball drop pressure retaining manifold to allow for the insertion of various sized dissolvable balls when required.
  • FIG. 2 A second embodiment in accordance with the invention is shown in Figure 2 .
  • the second and first embodiments work in the same way, but the second embodiment involves an improved design of system for lifting the fluid injection cap assembly into place and subsequently connecting the hose to the cap assembly.
  • the principal difference between the first and second embodiments is that the fluid injection assembly ("stim cap") 20 of Figure 1 , including gooseneck 22, is replaced by a fluid injection assembly 100 which has an upwardly oriented female hub/connector 101 and no gooseneck feature.
  • This has two advantages: (i) the vertically upward orientation of the hub 101 means that it is considerably easier to attach the hose connector 102, and (ii) during installation of the stim cap assembly 100 on the Xmas tree, a lifting point apparatus (not shown) can be locked into the hub to allow the stim cap assembly to be lowered by crane onto the Xmas tree.
  • the stim cap assembly is shown in place on the Xmas tree, after having been installed by a floating crane 103 using lifting point apparatus (not shown) locked into the hub 101.
  • the lifting point apparatus has been removed from the hub, and the floating crane 103 is shown in the process of installing the hose 104.
  • the crane cable is attached to the hose 104 at a single lifting point 105.
  • the hose 104 is fitted with a series of bend restrictor elements 106 which prevent the hose from kinking.
  • the lifting point 105 is at one end of the bend restrictors 106 with the end connector 102 hanging down on one side, and the remainder of the hose 104 on the other side.
  • the crane and the hose reel 107 can be worked together to ensure that the hose connector 102 is hanging vertically when it is brought into engagement with the hub 101.
  • the connection with the hub 101 is then locked using known means (not shown) by an ROV (also not shown).
  • the hose 104 is then placed into a supporting bracket 108 on the template structure, and the weight of the remainder of the hose trailing on the seafloor is sufficient to keep the hose from moving and stressing the connection.
  • the fluid injection (e.g. acid stimulation) operation is then conducted in exactly the same way as described in relation to the first embodiment.
  • a third embodiment in accordance with the invention is shown in Figures 4 and 5 .
  • the third embodiment works in the same way as the second and first embodiments, but the third embodiment involves an improved design of system for connecting the hose to the fluid injection cap assembly.
  • the principal difference between the second and third embodiments is that the hose 204 is attached to the supporting bracket 208 such that the open end of the hose faces upwardly in the bracket 208.
  • the connection between the secured end of the hose 204 and the hub 201 of the stim cap assembly 200 is then achieved by means of a rigid connector pipe 250 (shown in Figure 5 ).
  • the connector pipe 250 has two 90 degree bends enabling it to attach between the upwardly directed connector of the stim cap assembly and the upwardly directed end of the hose.
  • the exact distance between the secured hose end and the hub 201 is measured using a measuring device 251 which is brought up to the hose end and hub 201 by R.O.V. 252 (see Figure 4 ).
  • the bracket 208 of the third embodiment has a different design to that of the second embodiment, that allows the bracket 208 to be adjusted (by R.O.V.) to alter the position of the hose end so that the distance between hose end and hub 201 can be set.
  • the measuring device 251 is then removed and the rigid connector 250 lifted into position using the crane 203 in combination with R.O.V. 252.
  • a buoyancy element 254 is attached to a point or points along the length of the hose 204 to reduce stresses on the hose 204 and bracket 208.

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  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
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  • Physics & Mathematics (AREA)
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Claims (15)

  1. Ensemble (20) d'injection d'un fluide sous pression (par ex. de l'acide) pour le montage sur un arbre de Noël sous-marin (3), l'arbre de Noël (3) ayant un premier conduit (4) communiquant avec un tubing de production (5) d'un puits d'hydrocarbures sous-marin, l'ensemble (20) d'injection de fluide comprenant :
    a. un second conduit (22) destiné à la distribution d'un fluide (par ex. de l'acide) par l'intermédiaire de l'arbre de Noël (3) vers le puits d'hydrocarbures ;
    b. un connecteur au niveau d'une première extrémité du second conduit (22), destiné à connecter le second conduit (22) au premier conduit (4) de l'arbre de Noël ;
    c. une soupape fermée à sécurité intégrée (21) dans le second conduit (22) ;
    d. un connecteur de distribution de fluide (23, 24, 25) destiné au raccordementà un tuyau de distribution de fluide (28) afin d'alimenter en fluide l'ensemble (20) d'injection, le connecteur de distribution de fluide (23, 24, 25) étant situé au niveau d'une seconde extrémité du second conduit (22),
    éventuellement, dans lequel le système d'injection de fluide est conçu pour l'injection de fluide à un débit choisi parmi : entre 5000 et 15 000 litres par minute ; jusqu'à 15 000 litres par minute ; entre 8000 et 12 000 litres par minute ; jusqu'à 12 000 litres par minute ; et jusqu'à 10 000 litres par minute ;
    caractérisé en ce que
    la soupape fermée à sécurité intégrée (21) a une conduite de commande hydraulique (31) destinée à la connexion à une unité de commande (32) sur un vaisseau marin (33), de sorte que la soupape fermée à sécurité intégrée (21) puisse être commandée exclusivement depuis le vaisseau marin (33).
  2. Ensemble d'injection de fluide selon la revendication 1, dans lequel le second conduit (22) et la soupape fermée à sécurité intégrée (21) ont un diamètre interne non obstrué choisi parmi : au moins 102 mm (4"), au moins 127 mm (5"), entre 102 mm et 152 mm (4" à 6").
  3. Ensemble d'injection de fluide selon la revendication 1 ou 2, dans lequel le second conduit (22) comporte une section de tuyauterie rigide ayant un ou plusieurs coudes de 90 degrés ou plus, selon lequel le connecteur de distribution de fluide (23, 24, 25) est prévu au niveau d'une extrémité de la section de tuyauterie rigide.
  4. Ensemble d'injection de fluide selon la revendication 1 ou la revendication 2, dans lequel, lorsque l'ensemble (100) est fixé par rapport au plancher océanique, le connecteur de distribution de fluide (101) est dirigé vers le haut, éventuellement dans lequel le connecteur de distribution de fluide est également conçu pour recevoir un élément de point de levage, selon lequel un point de levage pour l'ensemble est prévu.
  5. Ensemble d'injection de fluide selon l'une quelconque des revendications 1 à 4, comprenant en outre un entonnoir de guidage (24) destiné à guider un tuyau de distribution de fluide (28) ou un élément de point de levage en position pour le raccordement au connecteur de fluide (20).
  6. Système d'injection d'un fluide sous pression (par ex. de l'acide) dans un puits d'hydrocarbures sous-marin, comprenant :
    a. un arbre de Noël sous-marin (3) ayant un premier conduit (4) communiquant avec un tubing de production (5) d'un puits d'hydrocarbures sous-marin ;
    f. un ensemble (20) d'injection de fluide selon l'une quelconque des revendications 1 à 5 ;
    g. un vaisseau marin (33) comportant une alimentation en fluide (30) (par ex. en acide) et une unité de commande (32) ;
    h. un tuyau de distribution de fluide (28) comportant un connecteur (23, 24, 25) sous-marin au niveau d'une première extrémité destiné au raccordement à l'ensemble (20) d'injection de fluide et un connecteur (29) au niveau d'une seconde extrémité destiné au raccordement à l'alimentation en fluide (30) (par ex. en acide), éventuellement par l'intermédiaire d'un dévidoir ;
    dans lequel la conduite de commande hydraulique (31) s'étend entre l'ensemble (20) d'injection de fluide et l'unité de commande (32), destinée à commander exclusivement la soupape fermée à sécurité intégrée (21) de l'ensemble (20) d'injection de fluide, éventuellement dans lequel le système est conçu pour l'injection de fluide à un débit choisi parmi : entre 5.000 et 15.000 litres par minute ; jusqu'à 15 000 litres par minute ; entre 8 000 et 12 000 litres par minute ; jusqu'à 12 000 litres par minute ; et jusqu'à 10 000 litres par minute.
  7. Système selon la revendication 6, dans lequel le tuyau de distribution de fluide (28) a un diamètre interne non obstrué d'au moins 102 mm (4"), de 102 mm à 152 mm (4" à 6").
  8. Système selon la revendication 6 ou 7, dans lequel le tuyau de distribution de fluide comprend un tuyau flexible (28) et un tuyau de raccordement (22) rigide ayant un ou plusieurs coudes de 60 degrés ou plus, tels que de 60 à 150 degrés, par ex. de 80 à 110 degrés, le connecteur (23, 24, 25) sous-marin étant situé sur une extrémité du tuyau de raccordement (22) rigide, éventuellement dans lequel le tuyau de raccordement (22) rigide est raccordé de manière amovible au tuyau flexible (28).
  9. Système selon l'une quelconque des revendications 6 à 8, dans lequel l'arbre de Noël (3) comporte un module de commande sous-marin (8) destiné à commander au moins une vanne maîtresse de production (7) de l'arbre de Noël (3), le module de commande sous-marin (8) étant conçu pour être commandé depuis une plate-forme de production proche, éventuellement dans lequel aucun moyen n'est prévu pour la commande du module de commande sous-marin (8) directement depuis le vaisseau marin (33).
  10. Procédé de distribution d'un fluide sous pression (par ex. de l'acide) vers une tête de puits d'hydrocarbures sous-marine (1), le procédé comprenant :
    a. l'enlèvement d'un chapeau d'arbre depuis un arbre de Noël (3) d'un ensemble de puits sous-marin ;
    b. le montage d'un ensemble (20) d'injection d'un fluide sous pression (par ex. de l'acide) sur l'arbre de Noël (3), l'ensemble (20) d'injection de fluide comprenant une soupape fermée à sécurité intégrée (21) et un connecteur (23, 24, 25) pour un tuyau de distribution de fluide (28) ;
    c. le raccordement d'une première extrémité du tuyau de distribution de fluide (28) au connecteur (23, 24, 25), une seconde extrémité du tuyau de distribution de fluide (28) étant raccordée à un appareil d'alimentation en fluide (30) installé sur un vaisseau marin (33) ;
    d. la distribution d'un fluide (par ex. de l'acide) sous pression, par l'intermédiaire du tuyau de distribution de fluide (28) et de la soupape fermée à sécurité intégrée (21), vers le tubing de production (5) d'un puits par l'intermédiaire de l'arbre de Noël (3),
    caractérisé en ce que le procédé comprend :
    la mise en place d'une conduite de commande hydraulique (31) entre la soupape fermée à sécurité intégrée (21) et une unité de commande (32) sur le vaisseau marin (33) de sorte que la soupape fermée à sécurité intégrée (21) puisse être commandée exclusivement depuis le système de commande (32) sur le vaisseau marin (33) ;
    éventuellement, dans lequel le fluide est distribué à un débit choisi parmi : entre 5 000 et 15 000 litres par minute ; jusqu'à 15 000 litres par minute ; entre 8 000 et 12 000 litres par minute ; jusqu'à 12 000 litres par minute ; et jusqu'à 10 000 litres par minute,
    éventuellement, dans lequel l'étape b comporte l'abaissement de l'ensemble (20) d'injection de fluide sous pression dans un emplacement sur l'arbre de Noël (3) par une grue, à l'aide d'un élément de point de levage installé dans le connecteur de tuyau flexible de pression de l'ensemble (20), et dans lequel l'élément de point de levage est enlevé avant l'étape c,
    éventuellement, dans lequel la seconde extrémité du tuyau flexible (28) est raccordée par l'intermédiaire d'un connecteur à libération rapide (29) à l'appareil d'alimentation en fluide (30) par l'intermédiaire d'un dévidoir ou d'une autre structure.
  11. Procédé selon la revendication 10, comportant l'étape consistant à laisser tomber ou à pomper une bille depuis le vaisseau marin (33) à travers le tuyau de distribution de fluide (28) et dans le tubing de production (5) du puits.
  12. Procédé selon l'une quelconque des revendications 10 à 11, dans lequel l'étape c est effectuée par abaissement de la première extrémité du tuyau de distribution de fluide (28) dans une position à l'aide d'une grue.
  13. Procédé selon l'une quelconque des revendications 10 à 12, dans lequel le tuyau de distribution de fluide comprend un tuyau flexible (28) et un tuyau de raccordement (22) rigide ayant un ou plusieurs coudes de 60 degrés ou plus, tels que de 60 à 150 degrés, par ex. de 80 à 110 degrés, et le connecteur (23, 24, 25) sous-marin étant situé sur une extrémité du tuyau de raccordement (22) rigide, et dans lequel l'étape c est effectuée par :
    (i) abaissement du tuyau flexible (28) dans un support adjacent à l'arbre de Noël (3) ;
    (ii) abaissement du tuyau de raccordement (22) ;
    (iii) raccordement d'une première extrémité du tuyau de raccordement (22) au tuyau flexible (28) ;
    (iv) raccordement du connecteur sous-marin du tuyau de raccordement (22) au connecteur de l'ensemble (20) d'injection de fluide.
  14. Procédé selon l'une quelconque des revendications 10 à 13, comportant la commande de la soupape fermée à sécurité intégrée (21) depuis le vaisseau marin (33) par maintien de la soupape fermée à sécurité intégrée (21) ouverte avec une pression hydraulique positive sur une conduite hydraulique (31) depuis le vaisseau marin (33).
  15. Procédé selon l'une quelconque des revendications 10 à 14, comportant la commande, depuis une plate-forme de production, d'une vanne maîtresse de production (7) et/ou d'une vanne de sécurité de fond (6) associée à l'arbre de Noël (3).
EP20889513.6A 2019-11-22 2020-11-20 Distribution de fluide à une tête de puits sous-marine Active EP4062029B1 (fr)

Applications Claiming Priority (2)

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US201962939271P 2019-11-22 2019-11-22
PCT/US2020/061534 WO2021102277A1 (fr) 2019-11-22 2020-11-20 Distribution de fluide à une tête de puits sous-marine

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GB201202581D0 (en) * 2012-02-15 2012-03-28 Dashstream Ltd Method and apparatus for oil and gas operations
GB2535393B (en) * 2013-10-21 2018-05-02 Onesubsea Llc Well intervention tool and method
US9695665B2 (en) * 2015-06-15 2017-07-04 Trendsetter Engineering, Inc. Subsea chemical injection system
US20180038190A1 (en) * 2016-08-08 2018-02-08 Trendsetter Engineering, Inc. Method and apparatus to effect injection of fluids into a subsea horizontal tree

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