EP3494282A1 - Coiled tubing arrangement for wellbore unloading - Google Patents

Coiled tubing arrangement for wellbore unloading

Info

Publication number
EP3494282A1
EP3494282A1 EP16911774.4A EP16911774A EP3494282A1 EP 3494282 A1 EP3494282 A1 EP 3494282A1 EP 16911774 A EP16911774 A EP 16911774A EP 3494282 A1 EP3494282 A1 EP 3494282A1
Authority
EP
European Patent Office
Prior art keywords
wellbore
unloading
coiled tubing
debris
bottom hole
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
EP16911774.4A
Other languages
German (de)
French (fr)
Other versions
EP3494282B1 (en
EP3494282A4 (en
Inventor
Thomas J. WATKINS
Silviu LIVESCU
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.)
Baker Hughes Holdings LLC
Original Assignee
Baker Hughes Inc
Baker Hughes a GE Co LLC
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 Baker Hughes Inc, Baker Hughes a GE Co LLC filed Critical Baker Hughes Inc
Publication of EP3494282A1 publication Critical patent/EP3494282A1/en
Publication of EP3494282A4 publication Critical patent/EP3494282A4/en
Application granted granted Critical
Publication of EP3494282B1 publication Critical patent/EP3494282B1/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes
    • 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
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/20—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables
    • E21B17/203—Flexible or articulated drilling pipes, e.g. flexible or articulated rods, pipes or cables with plural fluid passages
    • 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
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells
    • E21B37/08—Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, e.g. casing perforations, or gravel packs

Definitions

  • a wellbore unloading arrangement includes a running string and an unloading bottom hole assembly for removal of debris in the form of solids and liquids from the wellbore.
  • the running string is made up of two strings of inner coiled tubing which are disposed within an outer coiled tubing string.
  • the unloading bottom hole assembly is affixed to the running string and incorporates a fluid jet pump and debris vacuum as well as a nitrogen injection tool.
  • Nitrogen injection during operation of the fluid jet pump decreases the density of fluids within the wellbore proximate the bottom hole assembly, thereby improving the effectiveness of the debris vacuum.
  • the inventors have also determined that the combination of fluid jetting, vacuum and nitrogen injection allows a user to unload wellbores at greater depths than with conventional techniques. Nitrogen injection counteracts hydrostatic pressure that could otherwise preclude the removal of debris.
  • Figure 1 is a side, cross-sectional view of an exemplary wellbore which contains a wellbore unloading arrangement constructed in accordance with the present invention.
  • Figure 2 is an axial cross-section of the running string of the wellbore unloading arrangement.
  • Figure 3 is a side view of an exemplary unloading bottom hole assembly in accordance with the present invention.
  • Figure 1 illustrates an exemplary wellbore 10 which has been drilled through the earth 12 from the surface 14 down to a hydrocarbon-bearing formation 16.
  • Debris 18 is located within the wellbore 10.
  • the debris 18 is typically relatively fine and may include sand and cuttings.
  • a wellbore unloading arrangement 20 is disposed within the wellbore 10 from the surface 14 via a coiled tubing injector (not shown).
  • the wellbore unloading arrangement 20 includes a running string 22 and an unloading bottom hole assembly 24.
  • Figure 2 depicts an axial cross-section of the running string 22. It can be seen that the running string 22 includes an outer coiled tubing string 26 which defines a flowbore 28. First and second inner coiled tubing strings 30, 32 are located within the flowbore 28 of the outer coiled tubing string 26.
  • FIG. 3 illustrates an exemplary unloading bottom hole assembly 24 in greater detail.
  • the unloading bottom hole assembly 24 includes an outer housing 34 with a nose portion 36 having injection nozzles 38 for injection of fluids into the wellbore 10.
  • the fluids that can be injected via the injection nozzles 38 are provided via the first and second coiled tubing strings 30, ⁇ 32.
  • the lower end of the first coiled tubing string 30 is blocked by a plug 39 to cause fluid flowing through the first coiled tubing string 30 to exit through a lateral opening 41.
  • Vacuum ports 40 are located in the housing 34 to permit fluid and solids to enter the flowbore 28 of the outer coiled tubing string 26 from the wellbore 10. Debris 18 will enter the flowbore 28 of the outer coiled tubing string 26 and then to surface 14. Larger debris 18 may be filtered out from entering the flowbore 28 by screening by the vacuum ports 40.
  • a nitrogen supply 42 and associated fluid pump 44 are located at surface 14 and are operably associated with the wellbore unloading arrangement 20 to flow nitrogen into the first inner coiled tubing string 30.
  • a liquid supply 46 and associated fluid pump 48 are also located at surface 14 and are operably associated with the wellbore unloading arrangement 20 to flow liquid from the liquid supply 46 into the second inner coiled tubing string 32.
  • the liquid of the liquid supply 46 is typically water but may be other fluids as well.
  • a coiled tubing injection assembly (not shown), of a type well known in the art, is also located at surface 14 and is used to inject the wellbore unloading arrangement 20 into the wellbore 10 as well as remove it from the wellbore 10.
  • the wellbore unloading arrangement 20 is disposed into the wellbore 10 and lowered so that the unloading bottom hole assembly 24 is in a desired location proximate the debris 18 to be removed.
  • Nitrogen is pumped through the first inner coiled tubing string 30 to the unloading bottom hole assembly 24.
  • Non-nitrogen liquid is pumped down the second inner coiled tubing string 32 to the unloading bottom hole assembly 24.
  • a fluid jet pump 33 switches between injection of liquid from the second inner coiled tubing string 32 through nozzles 38 and vacuum power to draw debris into the flowbore 28 of the outer coiled tubing string 26 through vacuum ports 40.
  • the liquid that is injected through injection nozzles 38 will help dislodge debris 18 within the wellbore 10. This dislodged debris 18 can then be drawn into the flowbore 28 through vacuum ports 40.
  • nitrogen can be flowed from the nitrogen source 42 to injection nozzles 38. Nitrogen injection into the wellbore 10 will preferably occur proximate the debris 18 and may be done continuously as injection of liquid and vacuuming occurs. Also, the wellbore unloading arrangement 20 may be moved axially within the wellbore 10 during these operations to help further dislodge debris 18 and aid its removal.

Abstract

A wellbore unloading arrangement for removal of debris from a wellbore. The unloading arrangement includes an unloading bottom hole assembly which can inject both nitrogen and a liquid as well as draw debris into a flowbore for transmission to surface. Nitrogen injection allows unloading at greater depths.

Description

COILED TUBING ARRANGEMENT FOR WELLBORE UNLOADING
BACKGROUND OF THE INVENTION
1. Field of the Invention
[0001] The invention relates generally to devices and methods for unloading, or cleaning wellbores.
2. Description of the Related Art
[0002] In the course of production of hydrocarbon production fluids from a wellbore, it is often necessary to unload, or clean, the wellbore by removing solids and liquids from the wellbore. Typically, removal of such solids and liquids is needed following stimulation. Baker Hughes has used a Sand Vac™ and Well Vac™ system which features a high pressure fluid jet pump for dislodging debris coupled with a debris vacuum for transporting debris solids and liquids to surface.
SUMMARY OF THE INVENTION
[0003] The present invention provides systems and methods for unloading wellbores using a high pressure fluid jet pump and debris vacuum in conjunction with nitrogen injection. A wellbore unloading arrangement includes a running string and an unloading bottom hole assembly for removal of debris in the form of solids and liquids from the wellbore. The running string is made up of two strings of inner coiled tubing which are disposed within an outer coiled tubing string.
[0004] The unloading bottom hole assembly is affixed to the running string and incorporates a fluid jet pump and debris vacuum as well as a nitrogen injection tool. Nitrogen injection during operation of the fluid jet pump decreases the density of fluids within the wellbore proximate the bottom hole assembly, thereby improving the effectiveness of the debris vacuum. The inventors have also determined that the combination of fluid jetting, vacuum and nitrogen injection allows a user to unload wellbores at greater depths than with conventional techniques. Nitrogen injection counteracts hydrostatic pressure that could otherwise preclude the removal of debris. BRIEF DESCRIPTION OF THE DRAWINGS
[0005] For a thorough understanding of the present invention, reference is made to the following detailed description of the preferred embodiments, taken in conjunction with the accompanying drawings, wherein like reference numerals designate like or similar elements throughout the several figures of the drawings and wherein:
[0006] Figure 1 is a side, cross-sectional view of an exemplary wellbore which contains a wellbore unloading arrangement constructed in accordance with the present invention.
[0007] Figure 2 is an axial cross-section of the running string of the wellbore unloading arrangement.
[0008] Figure 3 is a side view of an exemplary unloading bottom hole assembly in accordance with the present invention.
DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS
[0009] Figure 1 illustrates an exemplary wellbore 10 which has been drilled through the earth 12 from the surface 14 down to a hydrocarbon-bearing formation 16. Debris 18 is located within the wellbore 10. The debris 18 is typically relatively fine and may include sand and cuttings.
[0010] A wellbore unloading arrangement 20 is disposed within the wellbore 10 from the surface 14 via a coiled tubing injector (not shown). The wellbore unloading arrangement 20 includes a running string 22 and an unloading bottom hole assembly 24.
[0011] Figure 2 depicts an axial cross-section of the running string 22. It can be seen that the running string 22 includes an outer coiled tubing string 26 which defines a flowbore 28. First and second inner coiled tubing strings 30, 32 are located within the flowbore 28 of the outer coiled tubing string 26.
[0012] Figure 3 illustrates an exemplary unloading bottom hole assembly 24 in greater detail. The unloading bottom hole assembly 24 includes an outer housing 34 with a nose portion 36 having injection nozzles 38 for injection of fluids into the wellbore 10. The fluids that can be injected via the injection nozzles 38 are provided via the first and second coiled tubing strings 30,· 32. In a preferred embodiment, the lower end of the first coiled tubing string 30 is blocked by a plug 39 to cause fluid flowing through the first coiled tubing string 30 to exit through a lateral opening 41. Vacuum ports 40 are located in the housing 34 to permit fluid and solids to enter the flowbore 28 of the outer coiled tubing string 26 from the wellbore 10. Debris 18 will enter the flowbore 28 of the outer coiled tubing string 26 and then to surface 14. Larger debris 18 may be filtered out from entering the flowbore 28 by screening by the vacuum ports 40.
[0013] A nitrogen supply 42 and associated fluid pump 44 are located at surface 14 and are operably associated with the wellbore unloading arrangement 20 to flow nitrogen into the first inner coiled tubing string 30. A liquid supply 46 and associated fluid pump 48 are also located at surface 14 and are operably associated with the wellbore unloading arrangement 20 to flow liquid from the liquid supply 46 into the second inner coiled tubing string 32. The liquid of the liquid supply 46 is typically water but may be other fluids as well. A coiled tubing injection assembly (not shown), of a type well known in the art, is also located at surface 14 and is used to inject the wellbore unloading arrangement 20 into the wellbore 10 as well as remove it from the wellbore 10.
[0014] In operation, the wellbore unloading arrangement 20 is disposed into the wellbore 10 and lowered so that the unloading bottom hole assembly 24 is in a desired location proximate the debris 18 to be removed. Nitrogen is pumped through the first inner coiled tubing string 30 to the unloading bottom hole assembly 24. Non-nitrogen liquid is pumped down the second inner coiled tubing string 32 to the unloading bottom hole assembly 24. During operation, a fluid jet pump 33 switches between injection of liquid from the second inner coiled tubing string 32 through nozzles 38 and vacuum power to draw debris into the flowbore 28 of the outer coiled tubing string 26 through vacuum ports 40. The liquid that is injected through injection nozzles 38 will help dislodge debris 18 within the wellbore 10. This dislodged debris 18 can then be drawn into the flowbore 28 through vacuum ports 40.
[0015] During operation to remove the debris 18, nitrogen can be flowed from the nitrogen source 42 to injection nozzles 38. Nitrogen injection into the wellbore 10 will preferably occur proximate the debris 18 and may be done continuously as injection of liquid and vacuuming occurs. Also, the wellbore unloading arrangement 20 may be moved axially within the wellbore 10 during these operations to help further dislodge debris 18 and aid its removal.
[0016] The inventors believe that nitrogen injection during operation of the fluid jet pump 33 decreases the density of fluids within the wellbore 10 proximate the unloading bottom hole assembly 24, thereby improving the effectiveness of the debris vacuum. Further, the inventors have discovered that effective operation of the liquid injection and debris removal is possible at greater wellbore depths than with conventional systems.

Claims

CLAIMS What is claimed is:
1. A wellbore unloading arrangement (20) for removal of debris (18) from a wellbore ( 0), the wellbore unloading arrangement being characterized by:
a running string (22) to dispose an unloading bottom hole assembly into the wellbore;
an unloading bottom hole assembly (24) carried by the running string, the unloading bottom hole assembly being configured to inject nitrogen and a liquid into the wellbore; and
the unloading bottom hole assembly further being configured to draw debris (18) into the running string using suction.
2. The wellbore unloading arrangement of claim 1 wherein the running string further comprises:
an outer coiled tubing string (26) defining a flowbore (28) along its length; a first inner coiled tubing string (30) within the flowbore of the outer coiled tubing string; and
a second inner coiled tubing string (32) within the flowbore of the outer coiled tubing string.
3. The wellbore unloading arrangement of claim 2 wherein:
the nitrogen is flowed through the first inner coiled tubing string; and the liquid is flowed through the second inner coiled tubing string.
4. The wellbore unloading arrangement of claim 1 further comprising a jet pump (33) which provides motive power to both inject liquid and the suction to draw debris into the flowbore.
5. The wellbore unloading arrangement of claim 1 wherein the liquid is water.
6. A wellbore unloading arrangement (20) for removal of debris (18) from a wellbore (10), the wellbore unloading arrangement being characterized by:
a running string (22) to dispose an unloading bottom hole assembly into the wellbore, the running string having an outer coiled tubing string (26) which defines a flowbore (28) along its length and at least one inner coiled tubing string within the flowbore to transmit nitrogen through the running string to an unloading bottom hole assembly;
an unloading bottom hole assembly (24) carried by the running string, the unloading bottom hole assembly being configured to inject nitrogen and a liquid; and the unloading bottom hole assembly further being configured to draw debris into the running string using suction.
7. The wellbore unloading arrangement of claim 6 wherein the at least one inner coiled tubing string is further characterized by:
a first inner coiled tubing string (30) through which the nitrogen is flowed; and a second inner coiled tubing string (32) through which the liquid is flowed.
1 8. The wellbore unloading arrangement of claim 6 further characterized by a jet
2 pump (33) which provides motive power to both inject liquid and the suction to draw
3 debris into the flowbore. l 9. The wellbore unloading arrangement of claim 6 wherein the liquid is water.
1
1 10. A method of unloading a wellbore (10) by removing debris (18) from the
wellbore, the method being characterized by the steps of:
disposing a wellbore unloading arrangement (20) into the wellbore, the wellbore unloading arrangement having an unloading bottom hole assembly (24);
5 injecting a liquid into the wellbore through the unloading bottom hole
6 assembly to dislodge the debris (18);
removing the debris from the wellbore by drawing the debris into the
8 unloading bottom hole assembly with suction;
injecting nitrogen into the wellbore through the unloading bottom hole0 assembly proximate the debris.
1
1 11. The method of claim 1 Q wherein the step of disposing the wellbore unloading arrangement into the wellbore is further characterized by:
3 disposing an unloading bottom hole assembly (24) into the wellbore with a
4 running string (22) which includes an outer coiled tubing string (26) which defines a
5 flowbore (28) and at least one inner coiled tubing string which resides within the
6 flowbore.
1
l 12. The method of claim 11 further characterized by: injecting the nitrogen through the at least one inner coiled tubing string; and removing the debris (18) through the flowbore (28).
EP16911774.4A 2016-08-04 2016-08-04 Coiled tubing arrangement for wellbore unloading Active EP3494282B1 (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2016/045558 WO2018026370A1 (en) 2016-08-04 2016-08-04 Coiled tubing arrangement for wellbore unloading

Publications (3)

Publication Number Publication Date
EP3494282A1 true EP3494282A1 (en) 2019-06-12
EP3494282A4 EP3494282A4 (en) 2020-03-25
EP3494282B1 EP3494282B1 (en) 2021-04-21

Family

ID=61074006

Family Applications (1)

Application Number Title Priority Date Filing Date
EP16911774.4A Active EP3494282B1 (en) 2016-08-04 2016-08-04 Coiled tubing arrangement for wellbore unloading

Country Status (5)

Country Link
EP (1) EP3494282B1 (en)
BR (1) BR112019001850B1 (en)
MY (1) MY197513A (en)
SA (1) SA519401010B1 (en)
WO (1) WO2018026370A1 (en)

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11365607B2 (en) 2020-03-30 2022-06-21 Saudi Arabian Oil Company Method and system for reviving wells

Family Cites Families (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5388650B1 (en) * 1993-06-14 1997-09-16 Mg Nitrogen Services Inc Non-cryogenic production of nitrogen for on-site injection in downhole drilling
US6029746A (en) * 1997-07-22 2000-02-29 Vortech, Inc. Self-excited jet stimulation tool for cleaning and stimulating wells
US6877571B2 (en) * 2001-09-04 2005-04-12 Sunstone Corporation Down hole drilling assembly with independent jet pump
US7048056B1 (en) * 2003-08-11 2006-05-23 Blake Mark A Down-hole well cleaning tool
US7213648B2 (en) * 2004-03-30 2007-05-08 Kirby Hayes Incorporated Pressure-actuated perforation with continuous removal of debris
EP1852571A1 (en) * 2006-05-03 2007-11-07 Services Pétroliers Schlumberger Borehole cleaning using downhole pumps
US9856706B2 (en) * 2012-06-05 2018-01-02 Halliburton Energy Services, Inc. Methods and systems for performance of subterranean operations using dual string pipes
US20140014350A1 (en) * 2012-07-13 2014-01-16 Morley Sebree Circulating coil cleanout tool and method

Also Published As

Publication number Publication date
MY197513A (en) 2023-06-19
EP3494282B1 (en) 2021-04-21
EP3494282A4 (en) 2020-03-25
BR112019001850A2 (en) 2019-05-07
WO2018026370A1 (en) 2018-02-08
SA519401010B1 (en) 2023-01-17
BR112019001850B1 (en) 2022-08-23

Similar Documents

Publication Publication Date Title
US7905291B2 (en) Borehole cleaning using downhole pumps
US4921577A (en) Method for operating a well to remove production limiting or flow restrictive material
US10697272B2 (en) Well cleanout system
US20160251951A1 (en) Centrifugal Separator for Downhole Pump
CA2769935C (en) Method and system for cleaning fracture ports
US8985209B2 (en) High pressure jet perforation system
US8668011B2 (en) Method of hydraulically fracturing a formation
EP3494282B1 (en) Coiled tubing arrangement for wellbore unloading
GB2482158A (en) Flow control apparatus
US11359461B2 (en) Wellbore system for interventionaless cleanout
US6685439B1 (en) Hydraulic jet pump
CA2937488A1 (en) Sequential re-completions of horizontal wells in unconsolidated sand reservoirs to increase non-thermal primary heavy oil recovery
US20110203792A1 (en) System, method and assembly for wellbore maintenance operations
US4838353A (en) System for completing and maintaining lateral wells
CA2315669C (en) Apparatus and method for cleaning debris from wells
US20160201417A1 (en) Fluid displacement stimulation of deviated wellbores using a temporary conduit
US20030111226A1 (en) Combination surge/pressure wash tool for oil wells and method therefor
CN110878683B (en) Device and method for removing near-well pollution of oil and gas well
CA2877036A1 (en) Fluid displacement stimulation of deviated wellbores using a temporary conduit

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

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

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

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20190301

AK Designated contracting states

Kind code of ref document: A1

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

AX Request for extension of the european patent

Extension state: BA ME

RIN1 Information on inventor provided before grant (corrected)

Inventor name: LIVESCU, SILVIU

Inventor name: WATKINS, THOMAS, J.

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

Effective date: 20200226

RIC1 Information provided on ipc code assigned before grant

Ipc: E21B 19/22 20060101ALI20200220BHEP

Ipc: E21B 41/00 20060101ALI20200220BHEP

Ipc: E21B 17/20 20060101ALI20200220BHEP

Ipc: E21B 37/06 20060101ALI20200220BHEP

Ipc: E21B 37/00 20060101AFI20200220BHEP

Ipc: E21B 37/08 20060101ALI20200220BHEP

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: 20201130

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: BAKER HUGHES HOLDINGS LLC

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: CH

Ref legal event code: EP

REG Reference to a national code

Ref country code: DE

Ref legal event code: R096

Ref document number: 602016056709

Country of ref document: DE

REG Reference to a national code

Ref country code: IE

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: AT

Ref legal event code: REF

Ref document number: 1384813

Country of ref document: AT

Kind code of ref document: T

Effective date: 20210515

REG Reference to a national code

Ref country code: LT

Ref legal event code: MG9D

REG Reference to a national code

Ref country code: AT

Ref legal event code: MK05

Ref document number: 1384813

Country of ref document: AT

Kind code of ref document: T

Effective date: 20210421

REG Reference to a national code

Ref country code: NL

Ref legal event code: MP

Effective date: 20210421

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: 20210421

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: 20210421

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: 20210421

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: 20210721

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: 20210421

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: 20210421

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: 20210823

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: 20210721

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: 20210421

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: 20210421

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: 20210421

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: 20210722

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: 20210821

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: 20210421

REG Reference to a national code

Ref country code: DE

Ref legal event code: R097

Ref document number: 602016056709

Country of ref document: DE

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

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: 20210421

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: 20210421

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: 20210421

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: 20210421

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: 20210421

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: 20210421

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: 20210421

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

REG Reference to a national code

Ref country code: DE

Ref legal event code: R119

Ref document number: 602016056709

Country of ref document: DE

26N No opposition filed

Effective date: 20220124

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: 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: 20210421

REG Reference to a national code

Ref country code: BE

Ref legal event code: MM

Effective date: 20210831

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

Effective date: 20210804

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

Ref country code: LI

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

Effective date: 20210831

Ref country code: CH

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

Effective date: 20210831

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: 20210821

Ref country code: LU

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

Effective date: 20210804

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: 20210421

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: 20210421

Ref country code: IE

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

Effective date: 20210804

Ref country code: GB

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

Effective date: 20210804

Ref country code: FR

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

Effective date: 20210831

Ref country code: DE

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

Effective date: 20220301

Ref country code: BE

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

Effective date: 20210831

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

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: 20210421

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: 20160804