EP2510190B1 - Drahtlos betätigtes hydrostatisches einstellungsmodul - Google Patents

Drahtlos betätigtes hydrostatisches einstellungsmodul Download PDF

Info

Publication number
EP2510190B1
EP2510190B1 EP11732214.9A EP11732214A EP2510190B1 EP 2510190 B1 EP2510190 B1 EP 2510190B1 EP 11732214 A EP11732214 A EP 11732214A EP 2510190 B1 EP2510190 B1 EP 2510190B1
Authority
EP
European Patent Office
Prior art keywords
well
packer
sensor
module
downhole
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.)
Active
Application number
EP11732214.9A
Other languages
English (en)
French (fr)
Other versions
EP2510190A4 (de
EP2510190A2 (de
Inventor
Dinesh R. Patel
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
Schlumberger Holdings Ltd
Prad Research and Development Ltd
Schlumberger Technology BV
Schlumberger Technology Corp
Original Assignee
Services Petroliers Schlumberger SA
Schlumberger Holdings Ltd
Prad Research and Development Ltd
Schlumberger Technology BV
Schlumberger Technology Corp
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, Schlumberger Holdings Ltd, Prad Research and Development Ltd, Schlumberger Technology BV, Schlumberger Technology Corp filed Critical Services Petroliers Schlumberger SA
Publication of EP2510190A2 publication Critical patent/EP2510190A2/de
Publication of EP2510190A4 publication Critical patent/EP2510190A4/de
Application granted granted Critical
Publication of EP2510190B1 publication Critical patent/EP2510190B1/de
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

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
    • 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
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • 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
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • E21B23/065—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers setting tool actuated by explosion or gas generating means
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
    • 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
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling

Definitions

  • Embodiments described relate to hydrostatic setting modules for use in downhole environments.
  • equipment and techniques for triggering a hydrostatic setting module are described. More specifically, wireless equipment and techniques may be utilized for such triggering without reliance on potentially more costly or stressful hydraulic triggering modes.
  • the well may be of a fairly sophisticated architecture.
  • the well may be thousands or tens of thousands of meters deep (tens of thousands of feet deep), traversing various formation layers, and zonally isolated throughout. That is to say, packers may be intermittently disposed about production tubing which runs through the well so as to isolate various well regions or zones from one another. Thus, production may be extracted from certain zones through the production tubing, but not others.
  • production tubing that terminates adjacent a production region is generally anchored or immobilized in place thereat by a mechanical packer, irrespective of any zonal isolation.
  • a packer such as the noted mechanical packer, may be secured near the terminal end of the production tubing and equipped with a setting mechanism.
  • the setting mechanism may be configured to drive the packer from a lower profile to a radially enlarged profile.
  • the tubing may be advanced within the well and into position with the packer in a reduced or lower profile. Subsequently, the packer may be enlarged to secure the tubing in place adjacent the production region.
  • the mechanism may be equipped with a trigger that is responsive to a given degree of pressure induced within the production tubing. So, for example, surface equipment and pumps adjacent the well head may be employed to induce a pressure differential of between about 20.68 MPa and 27.58 MPa (3,000 and 4,000 PSI) into the well. Depending on the location of the trigger for the setting mechanism, this driving up of pressure may take place through the bore of the production tubing or through the annulus between the tubing and the wall of the well.
  • the noted hydraulic manner of driving up pressure for triggering of the setting mechanism may place significant stress on the production tubing.
  • the strain on the tubing may lead to ballooning.
  • the strain on the tubing may have long term effects. That is to say, even long after setting the packer, strain placed on the tubing during the hydraulic setting of the packer may result in failure, for example, during production operations.
  • the entire production tubing string and packer assembly may be removed, examined, and another deployment of production equipment undertaken. Ultimately, this may eat up a couple of days' time and upwards of $100,000 in expenses.
  • pressurization of the annulus as a means to trigger the setting mechanism requires that the lower, generally open-hole, completions assembly be isolated. Generally this would involve the closing of a formation isolation valve or other barrier valve above the lower completions. Unfortunately, such a valve may not always be present. Once more, such valves come with their own inherent expense, installation cost, and failure modes, not to mention the activation time and techniques which must be dedicated to operation of the valve.
  • a setting mechanism may be employed that is hydraulically wired to the surface.
  • a hydrostatic set module may be utilized that includes a dedicated hydraulic control line run all the way to surface.
  • a dedicated hydraulic line for the setting mechanism only shifts the concerns over hydraulic deployment from potential production tubing stressors, plug placements, or barrier valve issues to issues with other downhole production equipment.
  • a dedicated hydraulic line is itself an added piece of production equipment.
  • a new piece of equipment is introduced, the possibility of defective production string equipment is inherently increased even before a setting application is run. Once more, where such defectiveness results in a failure, the same amount of time and expenses may be lost in removal and re-deployment of the production string.
  • the advantages obtained from protecting the production tubing by utilization of a dedicated hydraulic line for the setting mechanism may be negligible at best.
  • US 4856595 A discloses a downhole system according to the pre-amble of claim 1.
  • a wirelessly activated hydrostatic set module assembly according to claim 1 is provided.
  • a method of wirelessly actuating a downhole device from an oilfield surface according to claim 2 is furthermore provided.
  • Embodiments herein are described with reference to certain downhole setting applications.
  • embodiments depicted herein are of a packer being set downhole as part of a production assembly.
  • a variety of alternate applications utilizing a hydrostatic set module may employ wireless triggering and techniques as detailed herein.
  • wireless is meant to refer to any communication that takes place without the requirement of an optical or electrical wire, hydraulic line, or any other form of hard line substantially dedicated to supporting communications.
  • a downhole system 100 which includes an embodiment of a wirelessly triggered hydrostatic set module 150.
  • the module 150 is provided in conjunction with a packer 175 which may be utilized in sealing and anchoring production tubing 110 at a downhole location (see Fig. 2 ).
  • the packer 175 is outfitted with sealing elements 177 which may be hydraulically set via a hydraulic line 160 running from the module 150. In alternate embodiments, however, this line 160 may lead to hydraulically set devices other than packers.
  • the module 150 is wireless in nature. As shown in Fig. 1 , the module 150 is equipped with a wireless trigger mechanism 130. With added reference to Fig. 2 , the trigger 130 is configured to detect a wireless communication from surface 200. The communication may be in the form of a pressure pulse 201 or other signal emanating from surface 201 and transmitted downhole through the well 280. Regardless, the trigger mechanism 130 is configured to actuate the hydrostatic set module 150 in response to the detection of the wireless signal.
  • the trigger mechanism 130 may include a pressure sensor 480 as depicted in Figs. 4A and 4B .
  • a host of different signature types may be utilized in communicating with a processor 470 of the trigger mechanism 130 as described below.
  • a low pressure signature may be most suitable for communications.
  • the trigger mechanism 130 may be equipped with different types of sensors. For example, an acoustic sensor, flow meter or strain gauge may be utilized for respective detection of sonic transmission, fluid flow, or physical tension directed at the system 100 from the oilfield surface 200.
  • a radio frequency identification (RFID) or pip tag detector may be utilized for detection of an RFID or radioactively marked projectile, respectively.
  • RFID radio frequency identification
  • pip tag detector may be utilized for detection of an RFID or radioactively marked projectile, respectively.
  • a projectile may be dropped downhole from the oilfield surface 201 for activation of the trigger mechanism 130, once detected by the sensor thereof.
  • FIG. 2 an overview of an oilfield 201 accommodating a well 280 is shown.
  • the above noted system 100 with module 150 and packer 175, is disposed within the well 280 providing isolation above a production region 287.
  • the well 280 is defined by a casing 285 traversing various formation layers 290, 295 eventually reaching an uncased production region 287 with perforations 289 to encourage production therefrom.
  • the production region 287 may be cased, for example with casing perforations also present.
  • a hydrocarbon production flow may ultimately be directed through production tubing 110 of the system 100 and diverted through a line 255 at the well head 250.
  • a host of surface equipment 225 is disposed at the oilfield surface 200. Indeed, a rig 230 is even provided to support additional equipment for well interventions or other applications beyond the packer setting described herein.
  • a control unit 260 is provided along with a pulse generator 265 to direct communications with the triggering mechanism 130 as described below.
  • the pulse generator may be a pump. In other embodiments, however, alternate forms of wireless signal regulators may be employed as alluded to above.
  • the sealing elements 177 of the packer 175 are shown in an expanded state as directed by the hydrostatic set module 150 in response to actuation by the trigger mechanism 130.
  • the trigger mechanism 130 may be responsive to a wireless signal such as the noted pressure pulses 201, thereby actuating the module 150 until the packer 175 is set. Indeed, as the packer 175 is set, wireless communication with the trigger mechanism 130 are eventually cut off. Of course, this only takes place once the trigger mechanism 130 and module 150 are no longer needed due to the completion of the setting application.
  • the wireless communication signal may be sent through casing annulus as depicted between tubing 110 outside diameter and casing 285 inside diameter or alternately through the bore of the tubing 110 itself.
  • FIG. 3A an enlarged view of the system 100 is shown taken from 3-3 of Fig. 2 with focus on the hydrostatic set module 150 and packer 175.
  • the packer 175 is not yet set by the module 150. This is apparent as the sealing elements 177 of the packer 175 are shown in an undeployed state and displaying no sealing engagement with the casing 285 of the well 280.
  • the noted lack of sealing engagement means that wireless communications from the oilfield surface 200 may reach the trigger mechanism 130 of the module 150 for actuation. More specifically, the pulse generator 265 may be directed by the control unit 260 to transmit a particular signature of pressure pulses 201 downhole. These pulses 201 may be detected and evaluated by the pressure sensor 480 and processor 470 of the trigger mechanism 130, respectively (see Fig. 4A ). Thus, once the proper signature is detected, the module 150 may be triggered as described above.
  • Fig. 3B the system 100 is now shown with the packer 175 set following the above-noted activation of the module 150 by the trigger mechanism 130. As shown, the sealing elements 177 are now in full sealing engagement with the well casing 285 and the pulses 201 apparent in Fig. 3A have ceased. In an alternate embodiment the triggering mechanism 130 may be located uphole of the isolated location, perhaps along with the module 150 as well.
  • a wirelessly triggered hydrostatic set module 150 may be utilized for shifting sliding sleeves. For example, this may be done to expose or close perforations 289 such as those shown in Fig. 2 . or for opening and/or closing of a circulating valve for displacement of fluids.
  • multiple modules 150 may be employed such that shifting open or closed may be undertaken, for example, depending upon the particular wireless signature employed by the regulator as directed by the control unit 260.
  • a valve such as a formation isolation valve, may be linked to wirelessly triggered hydrostatic set modules 150 for opening or closing thereof according to the techniques described hereinabove.
  • Fig. 4A a schematic view of the system 100 detailed hereinabove is shown.
  • the hydraulic connection 420 to the hydrostatic set module 150 is also shown along with the hydraulic line 160 disposed between the module 150 and the packer 175 as referenced above.
  • production tubing 110 is centrally disposed relative to the overall system 100.
  • the entire system 100 is disposed within a well 280 such as that of Fig. 2 which is defined by casing 285.
  • illustration of the casing 285 is limited to portions located adjacent the packer 175.
  • the casing 285 defines a substantial majority of the well 280 as shown in Fig. 2 .
  • the trigger mechanism 130 includes a sensor 480.
  • the sensor 480 may be a pressure sensor configured to detect pressure pulses directed from an oilfield surface 201 and/or pressure pulse generator 265.
  • a variety of alternate sensor types may be utilized for detection of surface directed communications. These may include acoustic sensors, flow meters, strain gauges, and RFID or pip tag detectors, to name a few.
  • a pH or more chemical specific detector may even be employed for detection of an introduced fluid of a given characteristic. Such detectable fluid may even consist of the present wellbore fluid that is altered by the introduction of a pH altering or chemical presentation slug.
  • a processor 470 coupled thereto. Indeed, the processor 470 may immediately initiate triggering as described below upon detection of any surface directed communication. However, the processor 470 may also be programmed to initiate triggering upon the detection of a particular pattern or signature of surface communications. Thus, the odds of accidental triggering, for example, due to a false positive detection, may be reduced. Furthermore, the processor 470 may be employed to record and store data from the sensor 480 for later usage, perhaps unrelated to the triggering detailed below.
  • the processor 470 and any other electronics of the trigger mechanism 130 are powered by a conventional power source 460 such as an encapsulated lithium battery suitable for downhole use. More notably, however, the processor 470 is ultimately wired to a charge 400 that may be fired by the processor 470 as a means of triggering. In Fig. 4A , the charge 400 remains unfired and isolated at one side of charge barrier 450. However, upon direction by the processor 470, the charge 400 is configured to break this barrier 450 along with a chamber barrier 440, ultimately exposing a chamber 430 to wellbore pressure thereby actuating the hydrostatic set module 150 as described below.
  • a conventional power source 460 such as an encapsulated lithium battery suitable for downhole use. More notably, however, the processor 470 is ultimately wired to a charge 400 that may be fired by the processor 470 as a means of triggering. In Fig. 4A , the charge 400 remains unfired and isolated at one side of charge barrier 450. However, upon direction by the processor 470,
  • FIG. 4B a schematic view of the system 100 is shown in which the charge 400 of Fig. 4A has been set off.
  • the trigger of the trigger mechanism 130 has been pulled, so to speak. That is, based on analysis by the processor 470 of data obtained from the sensor 480, the charge 400 of Fig. 4A has been directed to go off, either upon being obtained or perhaps following a predetermined period of time.
  • this data obtained by the processor 470 relates to wireless surface communications detected by the sensor 480.
  • the setting mechanism 150 is that of an intensifier as would likely be the case for a conventional packer setting assembly. That is, aside from modifications for accommodating and coupling to the wireless trigger mechanism 130, as described above, the setting mechanism 150 may otherwise be a conventional off-the-shelf hydrostatic set module, for example. Such a module is detailed in U.S. Pat. No. 7,562,712 , Setting Tool for Hydraulically Actuated Devices , to Cho, et al..
  • FIG. 5 an alternate embodiment of a wirelessly triggered HSM system 100 is shown in schematic form.
  • redundancy has been built into the system 100 with the addition of a second trigger mechanism 535, a second hydraulic connection 520 to the HSM 150 and perhaps even a second line 560 therefrom to the packer 175.
  • This added redundancy may be employed to help ensure that complete triggering and packer setting takes place.
  • wireless communications through the wellbore may face interference challenges such as the presence of air in the case of pressure pulses 201 (see Fig. 2 ). Nevertheless, the presence of multiple trigger mechanisms 130, 530 increases the likelihood of wireless communication detection.
  • wireless communications may take the form of different signature patterns, independently tailored to each of the mechanisms 130, 530 to further increase the likelihood of processed detection. That is to say, the initial sensor 480 and processor 470 may be tuned to pick up a particular signature of wireless communications for analysis that differs from another signature geared toward the second sensor 580 and processor 575. Thus, where the initial signature fails to fully propagate downhole to its respective sensor 480 and processor 470, the other signature may nevertheless reach the second sensor 580 and processor 575 (or vice versa). Thus, another port 590 may be formed, chamber 530 exposed and the HSM 150 actuated.
  • a flow-chart summarizing an embodiment of employing a wirelessly triggered hydrostatic set module is shown.
  • a downhole system may be deployed into a well.
  • a production tubing system is described.
  • other types of systems may utilize wirelessly triggered hydrostatic set modules, such as completion systems utilizing sliding sleeves.
  • wireless communication signatures such as pressure pulses, may be directed downhole as indicated at 635 and 655.
  • a sensor of a trigger mechanism incorporated into the system may detect downhole communications as indicated at 675.
  • a hydrostatic set module of the system may be triggered by the mechanism based on processing of the wireless detection (see 695). This in turn may result in setting of a packer, shifting of a sliding sleeve or any number of downhole actuations as detailed herein.
  • Embodiments described hereinabove reduce the likelihood of having to remove and re-deploy an entire production string as a result of hydraulic strain induced on tubing due to packer setting. This is achieved in a manner that does not require the presence of a dedicated hydraulic line run from surface to the hydrostatic set module. As a result, concern over the introduction of new failure modes is eliminated. Furthermore, techniques detailed herein utilize wireless communications in conjunction with a hydrostatic set module that may be employed for a variety of applications beyond packer setting. Therefore, the value of the systems and techniques detailed herein may be appreciated across a variety of different downhole application settings.
  • redundancy may be provided by providing an additional triggering mechanism and HSM as noted hereinabove.
  • redundancy for sake of ensuring triggering may also be provided to the system by programming each individual processor to recognize multiple different types of wireless communication signatures.

Landscapes

  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Remote Sensing (AREA)
  • Geophysics (AREA)
  • Measuring Fluid Pressure (AREA)
  • Earth Drilling (AREA)

Claims (5)

  1. Drahtlos aktivierte hydrostatische Setzmodulanordnung zum Anordnen in einem Bohrloch (280) auf einem Ölfeld (200), wobei die Anordnung umfasst:
    ein hydrostatisches Setzmodul (150) zum hydraulischen Betätigen einer Untertagevorrichtung im Bohrloch; und
    einen mit dem Modul über eine hydraulische Verbindung (420) gekoppelten drahtlosen Auslösemechanismus (130) zum Initiieren des Betätigens, wobei der Mechanismus einen Sensor (480) zum Detektieren von Drahtloskommunikationen und einen Prozessor (470) für deren Analyse aufweist, wobei es sich bei dem Sensor um einen Drucksensor (480) handelt, der zum Detektieren von Drahtloskommunikationen in Form von sich durch das Bohrloch aus dem Ölfeld fortpflanzenden Druckpulsen (201) ausgelegt ist, wobei der Drucksensor und der Prozessor dazu ausgelegt sind, unterschiedliche Signaturmuster von Druckpulsen (201) voneinander zu unterscheiden, wobei die Anordnung gekennzeichnet ist durch einen zweiten Auslösemechanismus (535), der über eine zweite hydraulische Verbindung (520) mit dem hydrostatischen Setzmodul (150) gekoppelt ist, wobei der zweite Auslösemechanismus einen zweiten Drucksensor und Prozessor (580, 575) umfasst, die dazu ausgelegt sind, unterschiedliche Signaturmuster von Druckpulsen (201) voneinander zu unterscheiden.
  2. Verfahren zum drahtlosen Betätigen einer Untertagevorrichtung von Übertage im Ölfeld (200), wobei das Verfahren umfasst:
    In-Bereitstellung-Bringen eines Untertage-Systems (100) in eine Bohrung im Ölfeld (201);
    Senden (635, 655) mehrerer unterschiedlicher Drahtloskommunikationssignaturen nach Untertage in das Bohrloch von Übertage im Ölfeld, wobei es sich bei den Drahtloskommunikationssignaturen um Druckpulse handelt, die von einem Druckpulserzeuger (265) erzeugt werden, der sich während des Sendens über Tage befindet;
    Detektieren (675) der Kommunikationssignaturen mit einem Sensor (480) eines ersten Auslösemechanismus (130) des Systems sowie mit einem Sensor (580) eines zweiten Auslösemechanismus (530); und
    Betätigen (695) der Vorrichtung mit einem hydrostatischen Setzmodul (150) des Systems basierend auf der Analyse der detektierten Kommunikationssignaturen durch Prozessoren (470, 575) der Auslösemechanismen (130, 530), wobei die Prozessoren dazu programmiert sind, die mehreren unterschiedlichen Drahtloskommunikationssignaturen zu erkennen.
  3. Verfahren nach Anspruch 2, wobei es sich bei der Vorrichtung um einen Packer (175) handelt, wobei das Betätigen ferner ein Setzen des Packers umfasst.
  4. Verfahren nach Anspruch 2, wobei es sich bei der Vorrichtung um eine Schiebehülse handelt, wobei das Betätigen ferner ein Verschieben der Schiebehülse umfasst.
  5. Verfahren nach Anspruch 2, wobei es sich bei der Vorrichtung um ein Ventil handelt, wobei das Betätigen ferner ein Verändern einer Stellung des Ventils umfasst.
EP11732214.9A 2010-01-08 2011-01-07 Drahtlos betätigtes hydrostatisches einstellungsmodul Active EP2510190B1 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US29335510P 2010-01-08 2010-01-08
PCT/US2011/020538 WO2011085215A2 (en) 2010-01-08 2011-01-07 Wirelessly actuated hydrostatic set module

Publications (3)

Publication Number Publication Date
EP2510190A2 EP2510190A2 (de) 2012-10-17
EP2510190A4 EP2510190A4 (de) 2017-10-11
EP2510190B1 true EP2510190B1 (de) 2020-12-02

Family

ID=44257624

Family Applications (1)

Application Number Title Priority Date Filing Date
EP11732214.9A Active EP2510190B1 (de) 2010-01-08 2011-01-07 Drahtlos betätigtes hydrostatisches einstellungsmodul

Country Status (3)

Country Link
US (1) US20110168403A1 (de)
EP (1) EP2510190B1 (de)
WO (1) WO2011085215A2 (de)

Families Citing this family (73)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8389862B2 (en) 2008-10-07 2013-03-05 Mc10, Inc. Extremely stretchable electronics
US8261817B2 (en) * 2009-11-13 2012-09-11 Baker Hughes Incorporated Modular hydraulic operator for a subterranean tool
US10441185B2 (en) 2009-12-16 2019-10-15 The Board Of Trustees Of The University Of Illinois Flexible and stretchable electronic systems for epidermal electronics
GB201012175D0 (en) 2010-07-20 2010-09-01 Metrol Tech Ltd Procedure and mechanisms
US8813857B2 (en) 2011-02-17 2014-08-26 Baker Hughes Incorporated Annulus mounted potential energy driven setting tool
US20150119740A1 (en) * 2011-06-30 2015-04-30 The Johns Hopkins University Whole-body pletysmography system for the continuous characterization of sleep and breathing in a mouse
US8881798B2 (en) 2011-07-20 2014-11-11 Baker Hughes Incorporated Remote manipulation and control of subterranean tools
US20130020097A1 (en) * 2011-07-21 2013-01-24 Schlumberger Technology Corporation Downhole fluid-flow communication technique
CN105283122B (zh) 2012-03-30 2020-02-18 伊利诺伊大学评议会 可共形于表面的可安装于附肢的电子器件
US9316077B2 (en) 2012-08-20 2016-04-19 Halliburton Energy Services, Inc. Hydrostatic pressure actuated stroke amplifier for downhole force generator
US10030513B2 (en) 2012-09-19 2018-07-24 Schlumberger Technology Corporation Single trip multi-zone drill stem test system
US10036231B2 (en) 2012-10-16 2018-07-31 Yulong Computer Telecommunication Technologies (Shenzhen) Co., Ltd. Flow control assembly
US10030473B2 (en) 2012-11-13 2018-07-24 Exxonmobil Upstream Research Company Method for remediating a screen-out during well completion
US9068445B2 (en) * 2012-12-17 2015-06-30 Baker Hughes Incorporated Sensing indicator having RFID tag, downhole tool, and method thereof
US9557434B2 (en) 2012-12-19 2017-01-31 Exxonmobil Upstream Research Company Apparatus and method for detecting fracture geometry using acoustic telemetry
US9759062B2 (en) 2012-12-19 2017-09-12 Exxonmobil Upstream Research Company Telemetry system for wireless electro-acoustical transmission of data along a wellbore
US10100635B2 (en) 2012-12-19 2018-10-16 Exxonmobil Upstream Research Company Wired and wireless downhole telemetry using a logging tool
US20150300159A1 (en) 2012-12-19 2015-10-22 David A. Stiles Apparatus and Method for Evaluating Cement Integrity in a Wellbore Using Acoustic Telemetry
WO2014100276A1 (en) 2012-12-19 2014-06-26 Exxonmobil Upstream Research Company Electro-acoustic transmission of data along a wellbore
US10480308B2 (en) 2012-12-19 2019-11-19 Exxonmobil Upstream Research Company Apparatus and method for monitoring fluid flow in a wellbore using acoustic signals
WO2014099207A1 (en) 2012-12-21 2014-06-26 Exxonmobil Upstream Research Company Fluid plugs as downhole sealing devices and systems and methods including the same
CA2894495C (en) 2012-12-21 2017-01-10 Exxonmobil Upstream Research Company Flow control assemblies for downhole operations and systems and methods including the same
CA2892997C (en) 2012-12-21 2017-05-16 Exxonmobil Upstream Research Company Systems and methods for stimulating a multi-zone subterranean formation
US9945208B2 (en) 2012-12-21 2018-04-17 Exxonmobil Upstream Research Company Flow control assemblies for downhole operations and systems and methods including the same
WO2014109748A1 (en) 2013-01-10 2014-07-17 Halliburton Energy Services, Inc. Boost assisted force balancing setting tool
WO2015039248A1 (en) 2013-09-18 2015-03-26 Packers Plus Energy Services Inc. Hydraulically actuated tool with pressure isolator
US10132149B2 (en) 2013-11-26 2018-11-20 Exxonmobil Upstream Research Company Remotely actuated screenout relief valves and systems and methods including the same
US9790762B2 (en) 2014-02-28 2017-10-17 Exxonmobil Upstream Research Company Corrodible wellbore plugs and systems and methods including the same
US9574439B2 (en) 2014-06-04 2017-02-21 Baker Hughes Incorporated Downhole vibratory communication system and method
WO2016028414A1 (en) 2014-08-21 2016-02-25 Exxonmobil Upstream Research Company Bidirectional flow control device for facilitating stimulation treatments in a subterranean formation
EP3191683A1 (de) 2014-09-12 2017-07-19 Exxonmobil Upstream Research Company Diskrete bohrlochvorrichtungen, kohlenwasserstoffbohrlöcher mit einem bohrlochkommunikationsnetzwerk und diskrete bohrlochvorrichtungen sowie systeme und verfahren damit
US9951596B2 (en) 2014-10-16 2018-04-24 Exxonmobil Uptream Research Company Sliding sleeve for stimulating a horizontal wellbore, and method for completing a wellbore
US9863222B2 (en) 2015-01-19 2018-01-09 Exxonmobil Upstream Research Company System and method for monitoring fluid flow in a wellbore using acoustic telemetry
US10408047B2 (en) 2015-01-26 2019-09-10 Exxonmobil Upstream Research Company Real-time well surveillance using a wireless network and an in-wellbore tool
US9850725B2 (en) 2015-04-15 2017-12-26 Baker Hughes, A Ge Company, Llc One trip interventionless liner hanger and packer setting apparatus and method
EP3304430A4 (de) 2015-06-01 2019-03-06 The Board of Trustees of the University of Illionis Miniaturisierte elektronische systeme mit drahtlosstrom- und nahfeldkommunikationfähigkeiten
EP3304130B1 (de) 2015-06-01 2021-10-06 The Board of Trustees of the University of Illinois Alternativer ansatz zur uv-erfassung
US10060256B2 (en) 2015-11-17 2018-08-28 Baker Hughes, A Ge Company, Llc Communication system for sequential liner hanger setting, release from a running tool and setting a liner top packer
US10221669B2 (en) 2015-12-02 2019-03-05 Exxonmobil Upstream Research Company Wellbore tubulars including a plurality of selective stimulation ports and methods of utilizing the same
US10196886B2 (en) 2015-12-02 2019-02-05 Exxonmobil Upstream Research Company Select-fire, downhole shockwave generation devices, hydrocarbon wells that include the shockwave generation devices, and methods of utilizing the same
US10309195B2 (en) 2015-12-04 2019-06-04 Exxonmobil Upstream Research Company Selective stimulation ports including sealing device retainers and methods of utilizing the same
US20170350203A1 (en) * 2016-06-06 2017-12-07 Baker Hughes Incorporated Electrically-Actuated Slip Devices
US10465505B2 (en) 2016-08-30 2019-11-05 Exxonmobil Upstream Research Company Reservoir formation characterization using a downhole wireless network
US10526888B2 (en) 2016-08-30 2020-01-07 Exxonmobil Upstream Research Company Downhole multiphase flow sensing methods
US10590759B2 (en) * 2016-08-30 2020-03-17 Exxonmobil Upstream Research Company Zonal isolation devices including sensing and wireless telemetry and methods of utilizing the same
US10415376B2 (en) 2016-08-30 2019-09-17 Exxonmobil Upstream Research Company Dual transducer communications node for downhole acoustic wireless networks and method employing same
US10697287B2 (en) 2016-08-30 2020-06-30 Exxonmobil Upstream Research Company Plunger lift monitoring via a downhole wireless network field
US10344583B2 (en) 2016-08-30 2019-07-09 Exxonmobil Upstream Research Company Acoustic housing for tubulars
US10364669B2 (en) 2016-08-30 2019-07-30 Exxonmobil Upstream Research Company Methods of acoustically communicating and wells that utilize the methods
US10487647B2 (en) 2016-08-30 2019-11-26 Exxonmobil Upstream Research Company Hybrid downhole acoustic wireless network
CN106321076B (zh) * 2016-10-19 2021-05-04 中国石油化工股份有限公司 一种注水井启动压力测试方法
US10697288B2 (en) 2017-10-13 2020-06-30 Exxonmobil Upstream Research Company Dual transducer communications node including piezo pre-tensioning for acoustic wireless networks and method employing same
CA3079020C (en) 2017-10-13 2022-10-25 Exxonmobil Upstream Research Company Method and system for performing communications using aliasing
US10837276B2 (en) 2017-10-13 2020-11-17 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along a drilling string
CN111201454B (zh) 2017-10-13 2022-09-09 埃克森美孚上游研究公司 用于利用通信执行操作的方法和系统
WO2019074657A1 (en) 2017-10-13 2019-04-18 Exxonmobil Upstream Research Company METHOD AND SYSTEM FOR REALIZING OPERATIONS USING COMMUNICATIONS
MX2020003296A (es) 2017-10-13 2020-07-28 Exxonmobil Upstream Res Co Metodo y sistema para realizar operaciones de hidrocarburo con redes de comunicacion mixta.
US10690794B2 (en) 2017-11-17 2020-06-23 Exxonmobil Upstream Research Company Method and system for performing operations using communications for a hydrocarbon system
WO2019099188A1 (en) 2017-11-17 2019-05-23 Exxonmobil Upstream Research Company Method and system for performing wireless ultrasonic communications along tubular members
US10844708B2 (en) 2017-12-20 2020-11-24 Exxonmobil Upstream Research Company Energy efficient method of retrieving wireless networked sensor data
US11156081B2 (en) 2017-12-29 2021-10-26 Exxonmobil Upstream Research Company Methods and systems for operating and maintaining a downhole wireless network
WO2019133290A1 (en) 2017-12-29 2019-07-04 Exxonmobil Upstream Research Company Methods and systems for monitoring and optimizing reservoir stimulation operations
US10711600B2 (en) 2018-02-08 2020-07-14 Exxonmobil Upstream Research Company Methods of network peer identification and self-organization using unique tonal signatures and wells that use the methods
US11268378B2 (en) 2018-02-09 2022-03-08 Exxonmobil Upstream Research Company Downhole wireless communication node and sensor/tools interface
US10364659B1 (en) 2018-09-27 2019-07-30 Exxonmobil Upstream Research Company Methods and devices for restimulating a well completion
US11952886B2 (en) 2018-12-19 2024-04-09 ExxonMobil Technology and Engineering Company Method and system for monitoring sand production through acoustic wireless sensor network
US11293280B2 (en) 2018-12-19 2022-04-05 Exxonmobil Upstream Research Company Method and system for monitoring post-stimulation operations through acoustic wireless sensor network
WO2020219435A1 (en) 2019-04-24 2020-10-29 Schlumberger Technology Corporation System and methodology for actuating a downhole device
CN115516238A (zh) 2020-04-17 2022-12-23 斯伦贝谢技术有限公司 具有锁定的弹簧力的液压触发器
WO2022204284A1 (en) * 2021-03-26 2022-09-29 Schlumberger Technology Corporation Redundant trigger system
US20230088359A1 (en) * 2021-09-21 2023-03-23 Baker Hughes Oilfield Operations Llc Remote set tool with contingency trigger and system
US11952861B2 (en) * 2022-03-31 2024-04-09 Schlumberger Technology Corporation Methodology and system having downhole universal actuator
US11993991B2 (en) 2022-03-31 2024-05-28 Schlumberger Technology Corporation System and method for electronically controlling downhole valve system

Family Cites Families (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3233674A (en) * 1963-07-22 1966-02-08 Baker Oil Tools Inc Subsurface well apparatus
US4856595A (en) * 1988-05-26 1989-08-15 Schlumberger Technology Corporation Well tool control system and method
US5893413A (en) * 1996-07-16 1999-04-13 Baker Hughes Incorporated Hydrostatic tool with electrically operated setting mechanism
US6450263B1 (en) * 1998-12-01 2002-09-17 Halliburton Energy Services, Inc. Remotely actuated rupture disk
US6915848B2 (en) * 2002-07-30 2005-07-12 Schlumberger Technology Corporation Universal downhole tool control apparatus and methods
US7562712B2 (en) * 2004-04-16 2009-07-21 Schlumberger Technology Corporation Setting tool for hydraulically actuated devices
US7337850B2 (en) * 2005-09-14 2008-03-04 Schlumberger Technology Corporation System and method for controlling actuation of tools in a wellbore
US8056628B2 (en) * 2006-12-04 2011-11-15 Schlumberger Technology Corporation System and method for facilitating downhole operations

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
None *

Also Published As

Publication number Publication date
EP2510190A4 (de) 2017-10-11
WO2011085215A3 (en) 2011-10-06
EP2510190A2 (de) 2012-10-17
WO2011085215A2 (en) 2011-07-14
US20110168403A1 (en) 2011-07-14

Similar Documents

Publication Publication Date Title
EP2510190B1 (de) Drahtlos betätigtes hydrostatisches einstellungsmodul
US10731430B2 (en) Perforating gun
DK179965B1 (en) MULTI-ZONE FRACTURING WITH FULL WELLBORE ACCESS
US9243474B2 (en) Using dynamic underbalance to increase well productivity
EP3726004B1 (de) Systeme und verfahren zum abschluss mehrerer zonen in einem einzelnen durchlauf
US20120061095A1 (en) Apparatus and Method For Remote Actuation of A Downhole Assembly
WO2016018429A1 (en) Multi-zone actuation system using wellbore darts
US8985215B2 (en) Single trip multi-zone completion systems and methods
US20170335644A1 (en) Smart frac ball
WO2012091984A2 (en) Dissolvable barrier for downhole use and method thereof
AU2013402083A1 (en) Intelligent cement wiper plugs and casing collars
US20130043048A1 (en) Systems and Methods for Selective Electrical Isolation of Downhole Tools
US20130020097A1 (en) Downhole fluid-flow communication technique
US20170183938A1 (en) Valves For Regulating Downhole Fluids Using Contactless Actuation
US8733458B2 (en) Method and apparatus for setting a packer
CA3054380C (en) Perforation tool and methods of use
US9581013B2 (en) Apparatus and method for determining orientation of a device and mill position in a wellbore utilizing identification tags
US11268356B2 (en) Casing conveyed, externally mounted perforation concept
WO2018182578A1 (en) Measuring strain in a work string during completion operations
US11371317B2 (en) Remote-open barrier valve
US20230212925A1 (en) Pressure-activated valve assemblies and methods to remotely activate a valve
US20200003024A1 (en) Casing conveyed, externally mounted perforation concept

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

17P Request for examination filed

Effective date: 20120711

AK Designated contracting states

Kind code of ref document: A2

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

DAX Request for extension of the european patent (deleted)
A4 Supplementary search report drawn up and despatched

Effective date: 20170912

RIC1 Information provided on ipc code assigned before grant

Ipc: E21B 43/00 20060101ALI20170906BHEP

Ipc: E21B 23/04 20060101ALI20170906BHEP

Ipc: E21B 47/12 20120101AFI20170906BHEP

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

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20190715

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

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

Free format text: STATUS: GRANT OF PATENT IS INTENDED

INTG Intention to grant announced

Effective date: 20200706

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

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

Free format text: STATUS: THE PATENT HAS BEEN GRANTED

AK Designated contracting states

Kind code of ref document: B1

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

Ref legal event code: REF

Ref document number: 1341144

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201215

Ref country code: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602011069504

Country of ref document: DE

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

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

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: 20201202

Ref country code: RS

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: 20201202

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: 20210303

REG Reference to a national code

Ref country code: NO

Ref legal event code: T2

Effective date: 20201202

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20201202

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1341144

Country of ref document: AT

Kind code of ref document: T

Effective date: 20201202

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

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: 20201202

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: 20201202

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: 20201202

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: 20210302

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 FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20201202

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: 20201202

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

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

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: 20210405

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: 20201202

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: 20201202

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: 20201202

Ref country code: SM

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: 20201202

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: 20201202

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: 20201202

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602011069504

Country of ref document: DE

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

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: 20201202

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: 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: 20210402

Ref country code: MC

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: 20201202

Ref country code: LU

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

Effective date: 20210107

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20210131

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: FR

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

Effective date: 20210202

Ref country code: AL

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: 20201202

26N No opposition filed

Effective date: 20210903

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

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: 20201202

Ref country code: LI

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

Effective date: 20210131

Ref country code: DE

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

Effective date: 20210803

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: 20201202

Ref country code: DK

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: 20201202

Ref country code: CH

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

Effective date: 20210131

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: 20210107

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

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: 20210402

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

Ref country code: BE

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

Effective date: 20210131

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

Ref country code: NO

Payment date: 20230110

Year of fee payment: 13

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; INVALID AB INITIO

Effective date: 20110107

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: 20201202

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

Ref country code: IT

Payment date: 20221213

Year of fee payment: 13

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

Ref country code: GB

Payment date: 20231116

Year of fee payment: 14

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

Ref country code: MK

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: 20201202