EP2128378A1 - Appareil et procédé d'injection - Google Patents

Appareil et procédé d'injection Download PDF

Info

Publication number
EP2128378A1
EP2128378A1 EP08157376A EP08157376A EP2128378A1 EP 2128378 A1 EP2128378 A1 EP 2128378A1 EP 08157376 A EP08157376 A EP 08157376A EP 08157376 A EP08157376 A EP 08157376A EP 2128378 A1 EP2128378 A1 EP 2128378A1
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.)
Granted
Application number
EP08157376A
Other languages
German (de)
English (en)
Other versions
EP2128378B1 (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
Schlumberger Holdings Ltd
Prad Research and Development NV
Schlumberger Technology BV
Original Assignee
Services Petroliers Schlumberger SA
Gemalto Terminals Ltd
Schlumberger Holdings Ltd
Prad Research and Development NV
Schlumberger Technology BV
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, Schlumberger Holdings Ltd, Prad Research and Development NV, Schlumberger Technology BV filed Critical Services Petroliers Schlumberger SA
Priority to DK08157376.8T priority Critical patent/DK2128378T3/da
Priority to EP08157376A priority patent/EP2128378B1/fr
Priority to AT08157376T priority patent/ATE505621T1/de
Priority to DE602008006176T priority patent/DE602008006176D1/de
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

Links

Images

Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • 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 DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP 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 the 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 DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—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 DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—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.
  • 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 communicates with 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 borehole 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.

Landscapes

  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
  • Crystals, And After-Treatments Of Crystals (AREA)
  • Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
  • Catching Or Destruction (AREA)
  • Processing Of Solid Wastes (AREA)
  • Diaphragms For Electromechanical Transducers (AREA)
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
DK08157376.8T DK2128378T3 (da) 2008-05-30 2008-05-30 Indretning og fremgangsmåde til injektion
EP08157376A EP2128378B1 (fr) 2008-05-30 2008-05-30 Appareil et procédé d'injection
AT08157376T ATE505621T1 (de) 2008-05-30 2008-05-30 Injektionsvorrichtung und -verfahren
DE602008006176T DE602008006176D1 (de) 2008-05-30 2008-05-30 Injektionsvorrichtung und -verfahren
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 true EP2128378A1 (fr) 2009-12-02
EP2128378B1 EP2128378B1 (fr) 2011-04-13

Family

ID=39760967

Family Applications (1)

Application Number Title Priority Date Filing Date
EP08157376A Not-in-force EP2128378B1 (fr) 2008-05-30 2008-05-30 Appareil et procédé d'injection

Country Status (5)

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

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013004609A1 (fr) * 2011-07-06 2013-01-10 Shell Internationale Research Maatschappij B.V. Système et procédé pour injecter un fluide de traitement dans un puits de forage et vanne d'injection de fluide de traitement
WO2013164599A1 (fr) * 2012-05-02 2013-11-07 Michael Pritchard Revêtement de puits de forage
US9638001B2 (en) 2012-02-14 2017-05-02 Shell Oil Company Method for producing hydrocarbon gas from a wellbore and valve assembly
US9771775B2 (en) 2011-11-08 2017-09-26 Shell Oil Company Valve for a hydrocarbon well, hydrocarbon well provided with such valve and use of such valve
IT202000005386A1 (it) * 2020-03-12 2021-09-12 Eni Spa Apparato e metodo per iniettare un fluido in pozzo durante la perforazione.

Families Citing this family (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8136594B2 (en) * 2009-08-24 2012-03-20 Halliburton Energy Services Inc. Methods and apparatuses for releasing a chemical into a well bore upon command
US8162054B2 (en) * 2009-08-24 2012-04-24 Halliburton Energy Services Inc. Methods and apparatuses for releasing a chemical into a well bore upon command
NO334525B1 (no) * 2011-02-28 2014-03-31 Archer Norge As Framgangsmåte og apparat for lokal tilførsel av behandlingsfluid til et brønnparti
US20130043027A1 (en) * 2011-08-18 2013-02-21 Schlumberger Technology Corporation Zonal Isolation Systems For Subterranean Wells
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
NO345437B1 (en) * 2018-06-01 2021-02-01 Prores E&P As Mud loss treatment drilling tool and method

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0722037A2 (fr) * 1995-01-13 1996-07-17 Halliburton Company Dispositif pour l'injection d'un fluide dans un trou de forage
EP1223303A1 (fr) * 2000-01-20 2002-07-17 James Victor Carisella Appareil et procede d'injection de fluide de traitement
US7013971B2 (en) 2003-05-21 2006-03-21 Halliburton Energy Services, Inc. Reverse circulation cementing process
EP1653042B1 (fr) * 2004-10-12 2007-08-15 Services Petroliers Schlumberger Appareil pour l'injection d'un fluide dans un puits de forage et procédé d'injection correspondant
EP1653043B1 (fr) * 2004-11-02 2008-03-12 Services Petroliers Schlumberger Appareil et procédé de traitement de puits de pétrole

Family Cites Families (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3273647A (en) * 1963-08-19 1966-09-20 Halliburton Co Combination well testing and treating apparatus
US5355959A (en) * 1992-09-22 1994-10-18 Halliburton Company Differential pressure operated circulating and deflation valve
US5533570A (en) * 1995-01-13 1996-07-09 Halliburton Company Apparatus for downhole injection and mixing of fluids into a cement slurry
GB9513657D0 (en) * 1995-07-05 1995-09-06 Phoenix P A Ltd Downhole flow control tool
GB9525008D0 (en) * 1995-12-07 1996-02-07 Red Baron Oil Tools Rental Bypass valve
US6263969B1 (en) * 1998-08-13 2001-07-24 Baker Hughes Incorporated Bypass sub
US6394184B2 (en) * 2000-02-15 2002-05-28 Exxonmobil Upstream Research Company Method and apparatus for stimulation of multiple formation intervals
US7004248B2 (en) * 2003-01-09 2006-02-28 Weatherford/Lamb, Inc. High expansion non-elastomeric straddle tool
GB2397593B (en) * 2003-01-24 2006-04-12 Smith International Improved downhole apparatus
US7836962B2 (en) * 2008-03-28 2010-11-23 Weatherford/Lamb, Inc. Methods and apparatus for a downhole tool
US9291044B2 (en) * 2009-03-25 2016-03-22 Weatherford Technology Holdings, Llc Method and apparatus for isolating and treating discrete zones within a wellbore

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0722037A2 (fr) * 1995-01-13 1996-07-17 Halliburton Company Dispositif pour l'injection d'un fluide dans un trou de forage
EP1223303A1 (fr) * 2000-01-20 2002-07-17 James Victor Carisella Appareil et procede d'injection de fluide de traitement
US7013971B2 (en) 2003-05-21 2006-03-21 Halliburton Energy Services, Inc. Reverse circulation cementing process
EP1653042B1 (fr) * 2004-10-12 2007-08-15 Services Petroliers Schlumberger Appareil pour l'injection d'un fluide dans un puits de forage et procédé d'injection correspondant
EP1653043B1 (fr) * 2004-11-02 2008-03-12 Services Petroliers Schlumberger Appareil et procédé de traitement de puits de pétrole

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013004609A1 (fr) * 2011-07-06 2013-01-10 Shell Internationale Research Maatschappij B.V. Système et procédé pour injecter un fluide de traitement dans un puits de forage et vanne d'injection de fluide de traitement
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
US9771775B2 (en) 2011-11-08 2017-09-26 Shell Oil Company Valve for a hydrocarbon well, hydrocarbon well provided with such valve and use of such valve
US9638001B2 (en) 2012-02-14 2017-05-02 Shell Oil Company Method for producing hydrocarbon gas from a wellbore and valve assembly
WO2013164599A1 (fr) * 2012-05-02 2013-11-07 Michael Pritchard Revêtement de puits de forage
GB2517351A (en) * 2012-05-02 2015-02-18 Michael Pritchard Wellbore encasement
IT202000005386A1 (it) * 2020-03-12 2021-09-12 Eni Spa Apparato e metodo per iniettare un fluido in pozzo durante la perforazione.
WO2021181320A1 (fr) * 2020-03-12 2021-09-16 Eni S.P.A. Appareil et procédé d'injection d'un fluide dans un puits pendant le forage

Also Published As

Publication number Publication date
US20090294133A1 (en) 2009-12-03
DK2128378T3 (da) 2011-07-18
ATE505621T1 (de) 2011-04-15
EP2128378B1 (fr) 2011-04-13
DE602008006176D1 (de) 2011-05-26

Similar Documents

Publication Publication Date Title
EP2128378B1 (fr) Appareil et procédé d'injection
US7624803B2 (en) Injection apparatus for injecting an activated fluid into a well-bore and related injection method
US20170044864A1 (en) Method of sealing wells by squeezing sealant
CA2715250C (fr) Systeme pour forer des puits en sous-pression
US20080196889A1 (en) Reverse Circulation Cementing Valve
RU2671369C1 (ru) Бурение хвостовиком с использованием извлекаемой направляющей компоновки низа
CN105026679A (zh) 用于钻出地下钻孔的钻井方法
CN103470242B (zh) 一种油田水平井体积压裂方法
US10060210B2 (en) Flow control downhole tool
US20110162844A1 (en) Assembly and method for placing a cement plug
CN104153753A (zh) 基于常规油管带压拖动的水平井体积压裂管柱及压裂方法
US9416620B2 (en) Cement pulsation for subsea wellbore
CN104196492B (zh) 一种带压拖动井下封堵阀
US7478674B2 (en) System and method for fracturing and gravel packing a wellbore
US20110315381A1 (en) Compositions and method for use in plugging a well
RU2626108C2 (ru) Способ крепления скважины потайной колонной с фильтром
CN204140019U (zh) 一种带压拖动井下封堵阀
CN114396243B (zh) 一种气体钻井高压气井完井方法
US20240076951A1 (en) Downhole Mixing of Wellbore Treatment Fluids
CN206830063U (zh) 一种同井注采生产管柱
RU2379475C1 (ru) Способ селективной изоляции продуктивного пласта при цементировании первой ступени обсадной колонны скважины
RU2189431C1 (ru) Способ изоляции продуктивного пласта при цементировании обсадной колонны

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MT NL NO PL PT RO SE SI SK TR

AX Request for extension of the european patent

Extension state: AL BA MK RS

17P Request for examination filed

Effective date: 20100412

AKX Designation fees paid

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MT NL NO PL PT RO SE SI SK TR

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MT NL NO PL PT RO SE SI SK TR

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REF Corresponds to:

Ref document number: 602008006176

Country of ref document: DE

Date of ref document: 20110526

Kind code of ref document: P

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602008006176

Country of ref document: DE

Effective date: 20110526

REG Reference to a national code

Ref country code: NL

Ref legal event code: T3

REG Reference to a national code

Ref country code: DK

Ref legal event code: T3

LTIE Lt: invalidation of european patent or patent extension

Effective date: 20110413

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: NO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110713

Ref country code: HR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: SE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: PT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110816

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: ES

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110724

Ref country code: AT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: LV

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: GR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110714

Ref country code: IS

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110813

Ref country code: SI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: CY

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: FI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: BE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: MT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: MC

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20110531

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CZ

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: EE

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: SK

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: RO

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

Ref country code: PL

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

REG Reference to a national code

Ref country code: IE

Ref legal event code: MM4A

26N No opposition filed

Effective date: 20120116

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20110530

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602008006176

Country of ref document: DE

Effective date: 20120116

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20120523

Year of fee payment: 5

Ref country code: NL

Payment date: 20120515

Year of fee payment: 5

Ref country code: DK

Payment date: 20120510

Year of fee payment: 5

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: FR

Payment date: 20120608

Year of fee payment: 5

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: CH

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20120531

Ref country code: LI

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20120531

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LU

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20110530

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: BG

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110713

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20130529

Year of fee payment: 6

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: TR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: HU

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20110413

REG Reference to a national code

Ref country code: NL

Ref legal event code: V1

Effective date: 20131201

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20131203

REG Reference to a national code

Ref country code: DK

Ref legal event code: EBP

Effective date: 20130531

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602008006176

Country of ref document: DE

Effective date: 20131203

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20131201

REG Reference to a national code

Ref country code: FR

Ref legal event code: ST

Effective date: 20140131

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DK

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20130531

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20130531

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20140530

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20140530