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EP2128378B1 - Appareil et procédé d'injection - Google Patents

Appareil et procédé d'injection Download PDF

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Publication number
EP2128378B1
EP2128378B1 EP08157376A EP08157376A EP2128378B1 EP 2128378 B1 EP2128378 B1 EP 2128378B1 EP 08157376 A EP08157376 A EP 08157376A EP 08157376 A EP08157376 A EP 08157376A EP 2128378 B1 EP2128378 B1 EP 2128378B1
Authority
EP
European Patent Office
Prior art keywords
injection
fluid mixture
injection apparatus
rate
flow
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.)
Not-in-force
Application number
EP08157376A
Other languages
German (de)
English (en)
Other versions
EP2128378A1 (fr
Inventor
Christophe Rayssiguier
Nikhil Shindgikar
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.)
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
Original Assignee
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Prad Research and Development NV
Schlumberger Technology BV
Schlumberger Holdings Ltd
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 Services Petroliers Schlumberger SA, Gemalto Terminals Ltd, Prad Research and Development NV, Schlumberger Technology BV, Schlumberger Holdings Ltd filed Critical Services Petroliers Schlumberger SA
Priority to DE602008006176T priority Critical patent/DE602008006176D1/de
Priority to DK08157376.8T priority patent/DK2128378T3/da
Priority to AT08157376T priority patent/ATE505621T1/de
Priority to EP08157376A priority patent/EP2128378B1/fr
Priority to US12/468,656 priority patent/US20090294133A1/en
Publication of EP2128378A1 publication Critical patent/EP2128378A1/fr
Application granted granted Critical
Publication of EP2128378B1 publication Critical patent/EP2128378B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

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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
    • E21B27/00—Containers for collecting or depositing substances in boreholes or wells, e.g. bailers, baskets or buckets for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits
    • E21B27/02—Dump bailers, i.e. containers for depositing substances, e.g. cement or acids
    • 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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/004—Indexing systems for guiding relative movement between telescoping parts of downhole tools
    • E21B23/006—"J-slot" systems, i.e. lug and slot indexing mechanisms
    • 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
    • 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
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes

Definitions

  • the invention relates to an injection apparatus for injecting a chemical additive into a fluid mixture flowing in a well-bore.
  • the invention also relates to a corresponding injection method.
  • a particular application of the invention relates to the oilfield industry, for example in cementing operation.
  • the fluid injecting operations serves various purposes, for example delivering a chemical mixture into a fluid present in the borehole for consolidation purpose or fracturing purpose, or delivering a chemical mixture into a cement slurry for borehole cementing operation. These operations are well known in the oilfield industry.
  • Reference US 7,013,971 describes a method of cementing a casing in a wellbore with a tool connected at a lower end of a casing.
  • the tool comprises a plurality of holes.
  • the cement slurry is directly injected into the annulus with a plurality of stoppers.
  • the stoppers are pumped down and engage the holes so as to hold the cement slurry in the annulus until the cement slurry hardens.
  • the main disadvantage of such cementing operations is the lack or poor control about what is happening downhole.
  • EP 1,653,042 is considered the closest prior art document as it discloses an injection apparatus and method for injecting a chemical additive into a fluid mixture within an annulus of a wellbore.
  • the apparatus disclosed comprises a sliding sleeve valve that is activated by release of a series of darts from the surface whereby the sliding sleeve connects with a variety of side conduit and shunt tube configurations in order to allow the fluid mixture to flow into the annulus, to connect with the additive reservoir and to mix the two in the apparatus.
  • the body comprises at least one port for coupling to a reservoir containing the chemical additive, and at least one injection nozzle for injecting the chemical additive into the fluid mixture flowing into the annulus.
  • the valve arrangement has a closed position and an open position defined as a function of the fluid flow-rate of the fluid mixture flowing through the valve arrangement. In a closed position the valve arrangement closes the communication between the reservoir and the injection nozzle, the injection apparatus delivering a non-activated fluid mixture. In an open position, the valve arrangement puts in communication the reservoir with the injection nozzle, the injection apparatus injecting the chemical additive into the fluid mixture flowing into the annulus.
  • the valve arrangement may comprise a main sleeve comprising an internal conduit forming a Venturi and a peripheral groove forming a communication chamber, and an indexer sleeve coupled to the main sleeve and the body defining the position of the main sleeve as a function of the fluid flow-rate of the fluid mixture flowing through the main sleeve.
  • the main sleeve closes the communication between the reservoir and the injection nozzle.
  • the main sleeve puts in communication the reservoir with the injection nozzle through the communication chamber.
  • the body may further comprise at least one coupler at one extremity of the body for coupling the injection apparatus to a pipe, e.g. a casing.
  • the reservoir may be contained in a casing joint.
  • the injection nozzle may be located at a lower extremity of the body, above the port.
  • the internal chamber may be filled with a clean fluid.
  • the peripheral groove may be isolated from the injection nozzles by a seal in the closed position.
  • the valve arrangement may further comprise a compression spring positioned inside the internal chamber, pushing against a first and second shoulder of the body and the main sleeve, respectively.
  • the compression spring characteristic may determine a threshold flow-rate that triggers the main sleeve from the open position to the closed position and vice-versa.
  • the indexer sleeve may be positioned between the second shoulder and a third shoulder of the main sleeve, the indexer sleeve rotating around the main sleeve under limitation of an indexer pin secured to the body.
  • the indexer pin may be engaged in a groove in an external wall of the indexer sleeve, the groove having a plurality of 'J-slot' shape around the indexer sleeve.
  • the valve arrangement may further comprise a compensating piston positioned on top of the main sleeve for compensating the pressure between the internal chamber and the fluid mixture flowing through the injector apparatus.
  • the invention relates to an injection method for injecting a chemical additive into a fluid mixture flowing into an annulus of a well-bore.
  • the method comprises the following steps:
  • the triggering step may comprise sequentially raising the fluid flow-rate of the fluid mixture above a threshold flow-rate then lowering said flow-rate under the threshold flow-rate.
  • the method may further comprise the step of triggering the valve arrangement back to the close position by sequentially raising the fluid flow-rate of the fluid mixture above the threshold flow-rate then lowering said flow-rate under the threshold flow-rate, so as to stop putting in communication the injection nozzles with the reservoir.
  • the chemical additive in the reservoir may be at a pressure substantially identical as a pressure of the fluid mixture inside of the casing, which is higher than a pressure of the fluid mixture in the annulus.
  • the triggering step may be remotely controlled through a pumping arrangement of a surface equipment.
  • the invention enables reducing the wait on cement WOC during the cementing operations by directly injecting the chemical activator into the annulus around the casing whenever and wherever required. Further, the invention may also be used in other applications, such as the downhole preparation of a gelling system, based on polymers and cross-linkers.
  • the chemical additive can be efficiently mixed with the cement slurry during the displacement process in the desired zones of interest, for example near the casing shoe.
  • the invention enables operating the injection apparatus from the surface, by using variations of the pump flow rate, for a total control on opening and closing positions of the injection nozzles.
  • a selective treatment of the slurry in the zones of interest, minimizing the required volume of chemical additive in the reservoir and reducing costs is possible with the invention. It also enables using a downhole reservoir having a limited capacity and geometry adapted to the size of casing joints.
  • the invention enables, by reducing the WOC, keeping the rig idle as low as possible which is financially advantageous for the rig operators. Further, the invention enables reducing the risk linked with pumping the accelerator from the surface which may be problematic if the slurry sets during displacement.
  • FIG. 1 schematically shows an onshore hydrocarbon well location and equipments WE above a hydrocarbon geological formation GF after drilling operation has been carried out and after a casing string CA has been run.
  • the well-bore WB is a bore-hole generally filled with various fluid mixtures (e.g. the drilling mud or the like).
  • the equipment WE comprises a drilling rig DR for running the casing string CA in the bore-hole, cementing equipment comprising cement silo CR and pumping arrangement CP, and a well head and stuffing box arrangement WH providing a sealing for deploying the casing string CS or pumping down the cement into the generally pressurized well-bore WB.
  • cementing operations are generally undertaken to seal the annulus AN (i.e. the space between the well-bore WB and the casing CA where fluid can flow).
  • a first application is primary cementing which purpose is to achieve hydraulic isolation around the casing.
  • Other applications are remedial cementing which purposes are to stabilize the well-bore, to seal a lost circulation zone, to set a plug in an existing well or to plug a well so that it may be abandoned.
  • the cement may be pumped into the well casing through a casing shoe CS near the bottom of the bore-hole or a cementing valve installed in the casing so that the cement is positioned in the desired zone.
  • Cementing engineers prepare the cementing operations by determining the volume and physical properties of cement slurry and other fluids pumped before and after the cement slurry.
  • chemical additives are mixed with the cement slurry in order to modify the characteristics of the slurry or set cement.
  • Cement additives may be broadly categorized as accelerators (i.e. for reducing the time required for the set cement to develop sufficient compressive strength to enable further operations to be carried out), retarders (i.e. for increasing the thickening time of cement slurries to enable proper placement), dispersants (i.e. for reducing the cement slurry viscosity to improve fluid-flow characteristics), extenders (i.e.
  • weighting agents i.e. for increasing or lightening the slurry weight
  • fluid-loss or lost-circulation additives i.e. for controlling the loss of fluid to the formation through filtration
  • special additives designed for specific operating conditions.
  • the injector system IS of the invention enables injecting cement additives in the cement slurry at the proper time and at the desired location in the well-bore.
  • FIG. 2 schematically illustrates the injector system IS for injecting a chemical fluid mixture into a well-bore comprising an injector apparatus INJ according to the invention.
  • the injector system IS comprises an injector apparatus INJ and a reservoir RS.
  • the reservoir RS is installed inside the casing CA above the shoe CS, for example inside one or two casing joints.
  • the reservoir RS contains the above mentioned chemical additive which exact composition is determined by the goal of the injection operation.
  • the reservoir RS may consist of a bladder.
  • the injector apparatus INJ is directly connected onto the reservoir RS.
  • the landing collar LC for cement plug is located immediately above the injector apparatus INJ.
  • FIG. 3 schematically illustrates the injector apparatus INJ according to the invention.
  • the injector apparatus INJ comprises a body 1 defining an internal chamber 20 receiving a valve arrangement 30.
  • Injection nozzles 11 are drilled through the body so as to put the internal chamber 20 in communication with the annulus AN of the well-bore.
  • the upper extremity of the body 1 is coupled to an upper sub 2 through a threaded connection.
  • a seal 3 is positioned between the upper sub 2 and the upper extremity of the body 1.
  • the threaded connection and sealing enables an easy maintenance of the injector apparatus INJ.
  • the lower extremity of the body 1 is coupled to the casing joint (not shown on Figure 3 ) through a casing adapter 17.
  • the casing joint contains the reservoir (not shown on Figure 3 ).
  • the lower extremity of body 1 comprises a first port 14 directed towards the internal chamber 20 of the injector apparatus.
  • the casing adapter 17 comprises a second port 18 directed towards an outlet of the reservoir (not shown on Figure 3 ). Both ports 14 and 18 communicate through a channel 25 drilled through the tool body 1 and the casing adapter 17.
  • the injection nozzles 11 are located at the lower extremity of the body, above the first port 14.
  • the reservoir outlet is connected to the injection nozzles via the second port 18, the first port 14 and the valve arrangement.
  • the valve arrangement 30 comprises a main sleeve 4, an indexer sleeve 9 and a compression spring 10.
  • the main sleeve 4 comprises an internal conduit forming a Venturi.
  • the external and lower extremity of the main sleeve 4 comprises a peripheral groove 24 forming a communication chamber.
  • the compression spring 10 is installed inside the internal chamber of the body 1, pushing against a first 21 and second 22 shoulder of the body 1 and the main sleeve 4, respectively.
  • the indexer sleeve 9 may be positioned between the second shoulder 22 and a third shoulder 23 of the main sleeve 4.
  • the indexer sleeve 9 may rotate around the main sleeve 4. The rotation movement of the indexer sleeve 9 is controlled by an indexer pin 8 secured to the body 1.
  • a first set of seals 16 isolates the ports 14 and 18 from outside and inside fluids.
  • the reservoir is at the same pressure as the pressure inside of the casing, which is slightly higher than the annulus pressure, due to the pressure drop across the casing shoe check valves, or an optional choke (not shown) installed above the casing shoe.
  • the chemical additive contained in the reservoir starts flowing from the reservoir towards the annulus through the ports, the communication chamber and injection nozzles when the injector valve is in an open position.
  • a second set of seals 12A and 12B are positioned at both extremities of the main sleeve 4. They are equal-size seals. They enable providing a internal chamber of constant volume inside the apparatus irrespective of the sleeve position.
  • the internal chamber may be filled with a clean fluid 7, e.g. oil, in order to protect the valve arrangement, for example by avoiding problems with any debris by keeping the internal chamber clean.
  • the oil 7 also acts as a lubricant to ease the reciprocating movement of the main sleeve 4 and the rotation of the indexer sleeve 9.
  • the injector apparatus INJ may further comprise a compensating piston 5.
  • the compensating piston 5 is positioned on top of the main sleeve. It comprises seal 12A contacting the main sleeve and seal 6 contacting the body 1.
  • the compensating piston 5 ensures an identical pressure between the oil 7 and the fluid inside the injector apparatus, thus avoiding any pressure drop across the sleeve seals that may create a too high friction.
  • Figures 4, 5 and 6 are half cross-section views schematically illustrating the various positions during operation of the injector apparatus.
  • Figure 4 shows the injector apparatus in a closed position.
  • Figure 5 shows the injector apparatus in a trigger position.
  • Figure 6 shows the injector apparatus in an open position.
  • the various positions are controlled by means of the indexer sleeve 9 which is shown in Figure 7 .
  • the indexer sleeve 9 is a reciprocating or rotating indexer sleeve.
  • the compression spring 10 maintains the main sleeve 4 in a closed position when a fluid of low or normal flow-rates F1 flows through the main sleeve 4 ( Figure 4 ).
  • the indexer sleeve 9 is in a closed position PC ( Figure 7 ).
  • a fluid flowing at a flow rate above a threshold flow-rate F2 will trigger the injector apparatus ( Figure 5 ).
  • the fluid flow rate above the threshold creates a downward force on the main sleeve 4 due to the effect of the Venturi.
  • the compression spring 10 is compressed.
  • the fixed indexer pin 8 is engaged in a groove 9A in the external wall of the indexer sleeve 9 being for example several 'J-slot' cut 9A all around the indexer sleeve.
  • the indexer sleeve 9 rotates to an intermediate or trigger position PT ( Figure 7 ).
  • the threshold flow-rate is determined by the characteristic of the compression spring 10.
  • the peripheral groove 24 forming the communication chamber in the main sleeve 4 is isolated from the injection nozzles 11 by the seal 13.
  • the peripheral groove 24 forming the communication chamber in the main sleeve 4 by-passes the seal 13 and put in communication the injection nozzles 11 with the ports 14 and 18 coupled to the reservoir (not shown).
  • the chemical additive contained in the pressurized reservoir can flow into the annulus of well-bore through the ports, the channel and the injection nozzles.
  • the valve arrangement may be triggered back to the close position by sequentially raising the fluid flow-rate of the fluid mixture above the threshold flow-rate F2 then lowering said flow-rate under the threshold flow-rate.
  • Figure 8 schematically illustrates the fluid displacement during the injection operation.
  • Figure 8 relates to a particular example during which a chemical additive is delivered into a cement slurry for borehole cementing operation.
  • a slurry SF is pushed downwards by a top plug TP which is pushed by a mud MD pumped downwards from the surface.
  • the slurry SF flows through the bottom plug BP, the injector apparatus INJ, the casing joint CJ receiving the reservoir RS and the check valve of the shoe CS. Then the slurry SF flows into the annulus AN between the casing CA and the wall of the bore-hole WB.
  • the injector apparatus INJ is in the closed position, meaning that the chemical additive is maintained in the pressurized reservoir.
  • the reservoir RS pressure is substantially the same than the casing pressure, which is slightly higher than the annulus pressure.
  • the top and bottom plugs are rubber or plastics plugs separating the various fluids and preventing the slurry from depositing on the internal wall of the casing which are typically used in cementing operation.
  • the injector apparatus is triggered from the surface.
  • the triggering phase is performed by, firstly, increasing the flow-rate of the slurry SF above the determined threshold flow-rate, for example by increasing the pumping rate of the pumping arrangement CP ( Figure 1 ), and, secondly, stopping, at least reducing under a determined threshold the pumping rate of the pumping arrangement CP.
  • the injector apparatus INJ switches to the open position.
  • the chemical additive contained in the reservoir RS flows out of the reservoir and is injected via the injection nozzles 11 into the annulus.
  • the slurry SF flowing in the annulus AN in front of the injection nozzles 11 is treated and becomes an activated slurry ASF.
  • the chemical fluid mixture is an accelerator, the cement slurry will set very quickly in the corresponding treated zone.
  • the top plug TP lands onto the bottom plug.
  • This provides a sudden pressure bump indicating the end of the displacement. Said bump may be detected by an appropriate detector (not shown) at the surface.
  • the chemical additive injection may be stopped by triggering the valve arrangement back to the close position. This may be performed by sequentially raising the fluid flow-rate of the fluid mixture above the threshold flow-rate F2 then lowering said flow-rate under the threshold flow-rate.
  • the invention is not limited to onshore hydrocarbon well and can also be used in relation with offshore hydrocarbon well.
  • the invention has been presented with a particular cementing application, it is not limited to the injection of activator in the cement slurry.
  • the invention may also apply for the downhole preparation of a gelling system, based on polymers and cross-linkers.

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Claims (17)

  1. Appareil d'injection pour injecter un additif chimique dans un mélange de fluide s'écoulant dans un espace annuaire (AN) d'un puits de forage (WB) comprenant un corps (1) définissant une chambre interne (20) recevant un agencement de soupape (30) :
    dans lequel le corps (1) comporte :
    - au moins un orifice (14, 18) pour un couplage à un réservoir (RS) contenant l'additif chimique, et
    - au moins une buse d'injection (11) pour injecter l'additif chimique dans le mélange de fluide s'écoulant dans l'espace annulaire (AN),
    dans lequel l'agencement de soupape (30) présente une position fermée et une position ouverte définies en fonction du débit de fluide du mélange de fluide s'écoulant à travers l'agencement de soupape, de sorte que :
    • dans une position fermée, l'agencement de soupape (30) ferme la communication entre le réservoir (RS) et la buse d'injection (11), l'appareil d'injection délivrant un mélange de fluide non activé, et
    • dans une position ouverte, l'agencement de soupape (30) met en communication le réservoir (RS) avec la buse d'injection (11), l'appareil d'injection injectant l'additif chimique dans le mélange de fluide s'écoulant dans l'espace annulaire (AN).
  2. Appareil d'injection selon la revendication 1, dans lequel l'agencement de soupape (30) comporte :
    - un manchon principal (4) comprenant un conduit interne formant un venturi et une gorge périphérique (24) formant une chambre de communication, et
    - un manchon .de repère (9) couplé au manchon principal (4) et au corps (1) définissant la position du manchon principal en fonction du débit de fluide du mélange de fluide s'écoulant à travers le manchon principal, de sorte que :
    • dans la position fermée, le manchon principal (4) ferme la communication entre le réservoir (RS) et la buse d'injection (11), et
    • dans une position ouverte, le manchon principal (4) met en communication le réservoir (RS) avec la buse d'injection (11) à travers la chambre de communication.
  3. Appareil d'injection selon la revendication 1 ou 2, dans lequel le corps (1) comporte en outre au moins un coupleur (2, 17) à une extrémité du corps (1) pour coupler l'appareil d'injection à un tuyau (CA, CJ).
  4. Appareil d'injection selon l'une quelconque des revendications 1 à 3, dans lequel le réservoir (RS) est contenu dans un raccord de tubage (CJ).
  5. Appareil d'injection selon l'une quelconque des revendications 1 à 4, dans lequel la buse d'injection (11) est située à une extrémité inférieure du corps, au-dessus de l'orifice (14, 18).
  6. Appareil d'injection selon l'une quelconque des revendications 1 à 5, dans lequel la chambre interne (20) est remplie avec un fluide propre (7).
  7. Appareil d'injection selon l'une quelconque des revendications 1 à 6, dans lequel la gorge périphérique (24) est isolée des buses d'injection (11) par un joint d'étanchéité (13) dans la position fermée.
  8. Appareil d'injection selon l'une quelconque des revendications 1 à 7, dans lequel l'agencement de soupape (30) comporte en outre un ressort de compression (10) positionné à l'intérieur de la chambre interne (20), exerçant une poussée contre des premier (21) et deuxième épaulements du corps (1) et du manchon principal (4), respectivement.
  9. Appareil d'injection selon la revendication 8, dans lequel la caractéristique du ressort de compression (10) détermine un débit seuil qui déclenche le manchon principal de la position ouverte à la position fermée et vice versa.
  10. Appareil d'injection selon la revendication 8, dans lequel le manchon de repère (9) est positionné entre le deuxième épaulement (22) et un troisième épaulement (23) du manchon principal (4), le manchon de repère (9) tournant autour du manchon principal (4) sous la limitation d'une goupille de repère (8) fixée sur le corps (1).
  11. Appareil d'injection selon la revendication 10, dans lequel la goupille de repère (8) est engagées dans une gorge (9A) dans une paroi externe du manchon de repère (9), la gorge ayant une pluralité de « fentes en J » autour du manchon de repère.
  12. Appareil d'injection selon l'une quelconque des revendications 1 à 11, dans lequel l'agencement de soupape (30) comporte en outre un piston de compensation (5) positionné au sommet du manchon principal pour compenser la pression entre la chambre interne (20) et le mélange de fluide s'écoulant à travers l'appareil injecteur.
  13. Procédé d'injection pour injecter un additif chimique dans un mélange de fluide s'écoulant dans un espace annulaire (AN) d'un puits de forage (WB), le procédé comprenant les étapes suivantes :
    - faire fonctionner un appareil d'injection en un emplacement approprié dans le puits de forage, l'appareil d'injection comprenant un corps (1) définissant une surface interne (20) recevant un agencement de soupape (30), au moins une buse d'injection (11) pour injecter un additif chimique contenu dans un réservoir (RS) sous pression dans le mélange de fluide s'écoulant dans l'espace annulaire (AN), l'agencement de soupape étant dans une configuration fermée,
    - laisser s'écouler le mélange de fluide à un premier débit (F1) dans le puits de forage à travers l'appareil d'injection,
    - déclencher l'agencement de soupape à une position ouverte en laissant s'écouler le mélange de fluide à un second débit dans le puits de forage à travers l'appareil d'injection, de façon à mettre en communication les buses d'injection (11) avec le réservoir (RS) et laisser s'écouler l'additif chimique dans l'espace annulaire (AN) du puits de forage à travers les buses d'injection (11).
  14. Procédé d'injection selon la revendication 13, dans lequel l'étape de déclenchement comporte l'augmentation séquentielle du débit de fluide du mélange de fluide au-dessus d'un débit seuil (F2), puis la diminution dudit débit sous le débit seuil.
  15. Procédé d'injection selon la revendication 14, dans lequel le procédé comporte en outre l'étape de déclenchement de l'agencement de soupape pour revenir en position fermée par l'augmentation séquentielle du débit de fluide du mélange de fluide au-dessus du débit seuil (F2), puis la diminution dudit débit sous le débit seuil, de façon à interrompre la mise en communication des buses d'injection (11) avec le réservoir (RS).
  16. Procédé d'injection selon la revendication 13, dans lequel l'additif chimique dans le réservoir (RS) est à une pression sensiblement identique à la pression du mélange de fluide à l'intérieur du tubage, qui est plus élevée qu'une pression du mélange de fluide dans l'espace annulaire.
  17. Procédé d'injection selon la revendication 13, 14 ou 15, dans lequel l'étape de déclenchement est commandée à distance par un agencement de pompage (CP) d'un équipement de surface.
EP08157376A 2008-05-30 2008-05-30 Appareil et procédé d'injection Not-in-force EP2128378B1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
DE602008006176T DE602008006176D1 (de) 2008-05-30 2008-05-30 Injektionsvorrichtung und -verfahren
DK08157376.8T DK2128378T3 (da) 2008-05-30 2008-05-30 Indretning og fremgangsmåde til injektion
AT08157376T ATE505621T1 (de) 2008-05-30 2008-05-30 Injektionsvorrichtung und -verfahren
EP08157376A EP2128378B1 (fr) 2008-05-30 2008-05-30 Appareil et procédé d'injection
US12/468,656 US20090294133A1 (en) 2008-05-30 2009-05-19 Injection Apparatus and Method

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
EP08157376A EP2128378B1 (fr) 2008-05-30 2008-05-30 Appareil et procédé d'injection

Publications (2)

Publication Number Publication Date
EP2128378A1 EP2128378A1 (fr) 2009-12-02
EP2128378B1 true EP2128378B1 (fr) 2011-04-13

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US (1) US20090294133A1 (fr)
EP (1) EP2128378B1 (fr)
AT (1) ATE505621T1 (fr)
DE (1) DE602008006176D1 (fr)
DK (1) DK2128378T3 (fr)

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US9435174B2 (en) 2011-07-06 2016-09-06 Shell Oil Company System and method for injecting a treatment fluid into a wellbore and a treatment fluid injection valve
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EP2744973B1 (fr) 2011-11-08 2015-08-19 Shell Internationale Research Maatschappij B.V. Vanne pour puits d'hydrocarbures, puits d'hydrocarbures doté d'une telle vanne et utilisation de celle-ci
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US20140096971A1 (en) * 2012-10-05 2014-04-10 Timothy S. Keizer New method and arrangement for feeding chemicals into a hydrofracturing process and oil and gas applications
US9388664B2 (en) 2013-06-27 2016-07-12 Baker Hughes Incorporated Hydraulic system and method of actuating a plurality of tools
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IT202000005386A1 (it) * 2020-03-12 2021-09-12 Eni Spa Apparato e metodo per iniettare un fluido in pozzo durante la perforazione.

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Also Published As

Publication number Publication date
EP2128378A1 (fr) 2009-12-02
DE602008006176D1 (de) 2011-05-26
US20090294133A1 (en) 2009-12-03
ATE505621T1 (de) 2011-04-15
DK2128378T3 (da) 2011-07-18

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