AU2017404493A1 - Sensor configuration - Google Patents
Sensor configuration Download PDFInfo
- Publication number
- AU2017404493A1 AU2017404493A1 AU2017404493A AU2017404493A AU2017404493A1 AU 2017404493 A1 AU2017404493 A1 AU 2017404493A1 AU 2017404493 A AU2017404493 A AU 2017404493A AU 2017404493 A AU2017404493 A AU 2017404493A AU 2017404493 A1 AU2017404493 A1 AU 2017404493A1
- Authority
- AU
- Australia
- Prior art keywords
- sensor
- borehole
- hollow
- rib
- sensor configuration
- 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.)
- Abandoned
Links
- 238000000034 method Methods 0.000 claims abstract description 17
- 239000004568 cement Substances 0.000 claims description 10
- 239000000463 material Substances 0.000 claims description 9
- 239000007787 solid Substances 0.000 claims description 9
- 238000005553 drilling Methods 0.000 claims description 5
- 239000007769 metal material Substances 0.000 claims description 3
- 239000003795 chemical substances by application Substances 0.000 description 4
- 230000001953 sensory effect Effects 0.000 description 4
- 230000006870 function Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000003381 stabilizer Substances 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000003607 modifier Substances 0.000 description 2
- -1 steam Substances 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 150000007513 acids Chemical class 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 239000003995 emulsifying agent Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000001939 inductive effect Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000000700 radioactive tracer Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1078—Stabilisers or centralisers for casing, tubing or drill pipes
-
- 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
- E21B47/005—Monitoring or checking of cementation quality or level
-
- 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
- E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- 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
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
Landscapes
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Mechanical Engineering (AREA)
- Quality & Reliability (AREA)
- Testing Or Calibration Of Command Recording Devices (AREA)
- Earth Drilling (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow. A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow. A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.
Description
SENSOR CONFIGURATION
BACKGROUND [0001] In the resource exploration and recovery industry, information about conditions in the downhole environment is often helpful. One particular example of information is to know what the condition of the cement integrity is. are means to determine such information available in the art, that include running a wireline into a borehole after a cementing job is completed and sensing parameters related to the integrity of that cement. The results of the method are generally good but this method does require an additional wireline run. Rig time is ever-increasingly expensive and at the time of writing of this disclosure is running upwards of a million dollars a day. While it is possible to forego the information, it is preferable to have more rather than less information about the downhole conditions in order to avoid downtime, inefficiencies, etc. Accordingly the art would welcome alternative configurations that provide information about the downhole environment but also reduce rig time.
SUMMARY [0002] A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow.
[0003] A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow.
[0004] A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.
BRIEF DESCRIPTION OF THE DRAWINGS [0005] The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:
[0006] Figure 1 is a schematic illustration of a borehole with a tubular member therein and a solid body centralizer as described herein;
[0007] Figure 2 is a cross sectional view of the centralizer illustrated in Figure 1; and
WO 2018/169542
PCT/US2017/022896 [0008] Figure 3 is an illustration similar to Figure 1 but including another string in the borehole.
DETAILED DESCRIPTION [0009] A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
[0010] Referring to Figure 1, a sensor configuration 10 is illustrated in situ. The Figure includes borehole 12 within which is also disposed a tubular string 14, the sensor configuration being disposed about the string. The sensor configuration 10 comprises a centralizer 16 with a sensor 18 (while the term sensor may mean just a sensor itself, it is broadly intended herein to also include associated electronics and/or a power source) disposed therein (one or more sensors in one or more centralizer ribs) as discussed in more detail below. Centralizers 16 are commonly employed to maintain a tubular string at or near a center axis of a borehole 12 in which the tubular string 14 is disposed. Centralizer types known in the art include solid body centralizers (having an inside diameter surface that will fit over a tubular and a body of material that includes ribs, the material being essentially a solid mass or foamed mass or machined on a tubular like a stabilizer on a bottom hole assembly). Centralizers may be constructed of most materials having sufficient crush resistance to function as a centralizer in a downhole environment. Determination of suitability of a particular material for the task at hand is well within the level of skill of one of ordinary skill in the art. Metal material and polymeric material are two examples of materials employable.
[0011] Referring to Figure 2, a cross section view of a sensor configuration 10 as disclosed herein is illustrated. The sensor configuration 10, as noted above, comprises a centralizer 16 and a sensor 18 disposed therein. The centralizer 16 is of a solid body type if viewed from an exterior thereof, with ribs 20 (helical or axially straight or of any other configuration) extending radially outwardly of a body 22. One or more of the ribs 20 defines a hollow 24 therein sufficient in size to accommodate the sensor 18 (and/or electronics, and/or power source). It should be appreciated that particular dimensions of the hollow 24 may be different in various iterations of the sensor configuration depending upon the particular size and type of sensor selected for use. One particular sensor contemplated for use in this configuration is a piezoelectric transducer utilized in a commercial tool known as a segmented bond tool (SBT) available from Baker Hughes Incorporated Houston Texas from
WO 2018/169542
PCT/US2017/022896 the SBT is positioned within the hollow 24. The sensor 18 may be configured to operate on battery power (disposed in the hollow with the sensor), inductive power from another tool run in the well later, power generated downhole, etc. electronics required to control the sensor and the power supply (both collectively under the penumbra of numeral 18) may be located in the hollow 24 as well.
[0012] The sensor configuration 10 is to be disposed on the tubular 14 in the same manner as prior art solid body centralizers are used specifically, the centralizer 16 is disposed on the tubular 14 and secured in place. In an alternate embodiment, the centralizer 16 may be located in between two segments of tubular 14 similar to a stabilizer in a drill string. Securement may be by welding, threading, or any other securement method know to the art for securement of centralizers or stabilizers. Important to note is that the centralizer presents no impediment to the inside diameter flow area of the tubular 14. Rib 20 containing sensor 18 is located in the annular space outside of the tubular 14. Sensors for cement integrity checks of the past were run in the ID of the tubing string 14, thereby necessarily being an impediment to flow but also requiring the separate run of wireline that the disclosure herein avoids. The sensors 18, being contained with the hollow 24 and in some embodiments being sealed within the hollow 24, also have no impact on flow area within the tubular 14. Of the possible types of sensors that may be employed in the hollow(s) 24, some include cement integrity sensors, pressure sensors, temperature sensors, etc. or combinations including at least one of the foregoing. Also, since generally more than one rib will be a part of a centralizer, it is contemplated to dispose one or more different sensors in different ribs. Stated alternately, in an embodiment where there are four ribs and wherein each of those four ribs is possessed of a hollow, there could be four sensors of the same type, three of the same and one different, a different sensor in each rib, some ribs without sensors, etc. It is also contemplated to but more than one type of sensor in a single hollow in iterations hereof.
[0013] In connection with embodiments that include a cement integrity sensor, in addition to the SBT sensor noted above, other sensors such as Electromagnetic Acoustic Transducers (EMATs), wedge transducers, pulse-echo transducers, pitch-catch configuration or combinations including at least one of the foregoing are contemplated. It is to be appreciated that the location of the cement integrity sensor in the ribs 20 is advantageous in itself for SBT type sensors. Specifically, the sensors being positioned outside of the tubular 14 brings them closer to the cement that the sensor is to examine and avoids the need for a sensory signal to pass through the tubular string 14 itself as would be the case in prior art systems.
WO 2018/169542
PCT/US2017/022896 [0014] Regardless of type of sensor used, the sensor configuration is a permanent part of the tubular string 14 and hence allows for sensory readings over time with related storage of that sensory information to the extent of an on board memory in the sensor 18. The information stored can be sent to surface via a communications conduit put in place with the tubular string 14, or can be downloaded to an after run tool 26 such as a drilling assembly, a completion string, etc., that includes an interrogator 28 (see Fig. 3). And while one of the benefits of the sensor configuration hereof is to avoid the need for a dedicated run to obtain sensory information such as with a wireline run of a sensor, it is possible to run a dedicated interrogation tool to receive the data stored in the sensor 18.
[0015] The embodiments contemplated herein may be manufactured by traditional manufacturing methods or by additive manufacturing methods.
[0016] A method for acquiring data from a borehole is also contemplated including disposing a centralizer defining a hollow in a rib and a sensor in the hollow in a tubing string; collecting data with the sensor. The data may be collected over time since the sensor is permanently mounted on the tubular string in the borehole. The sensor may communicate the data or store the data for future delivery to an interrogator. The interrogator may be run on a tool having a primary function other than as an interrogator such as a drilling assembly, a completion string, wireline, slick-line, etc. The data may be of any kind, including data for the parameters set forth hereinabove.
[0017] Set forth below are some embodiments of the foregoing disclosure:
[0018] Embodiment 1: A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow.
[0019] Embodiment 2: The sensor configuration as in any prior embodiment wherein the centralizer is a solid body centralizer.
[0020] Embodiment 3: The sensor configuration as in any prior embodiment wherein the sensor is entirely contained within the hollow.
[0021] Embodiment 4: The sensor configuration as in any prior embodiment wherein the sensor is sealed within the hollow.
[0022] Embodiment 5: The sensor configuration as in any prior embodiment wherein the sensor is a cement integrity sensor.
[0023] Embodiment 6: The sensor configuration as in any prior embodiment wherein the sensor is a temperature sensor.
[0024] Embodiment 7: The sensor configuration as in any prior embodiment wherein the sensor is a pressure sensor.
WO 2018/169542
PCT/US2017/022896 [0025] Embodiment 8: The sensor configuration as in any prior embodiment wherein the rib is more than one rib, at least more than one of the more than one ribs containing sensors.
[0026] Embodiment 9: The sensor configuration as in any prior embodiment wherein the sensors are selected from the same type of sensor or different sensors for the more than one of the more than one rib.
[0027] Embodiment 10: The sensor configuration as in any prior embodiment wherein the centralizer comprises a metallic material.
[0028] Embodiment 11: The sensor configuration as in any prior embodiment wherein the centralizer comprises a polymeric material.
[0029] Embodiment 12: A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow.
[0030] Embodiment 13: A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.
[0031] Embodiment 14: The method as in any prior embodiment wherein the sensing is over time.
[0032] Embodiment 15: The method as in any prior embodiment further including running another tool whose primary function is not sensor interrogation with an interrogator thereon.
[0033] Embodiment 16: The method as in any prior embodiment wherein the tool is a drilling assembly.
[0034] Embodiment 17: The method as in any prior embodiment wherein the tool is a completion string.
[0035] The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should further be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The modifier “about” used in connection with a quantity is inclusive of the stated value and has the meaning dictated by the context (e.g., it includes the degree of error associated with measurement of the particular quantity).
WO 2018/169542
PCT/US2017/022896 [0036] The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and / or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
[0037] While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.
WO 2018/169542
PCT/US2017/022896
Claims (17)
- What is claimed is:1. A sensor configuration comprising (10):a centralizer (16) having a rib (20);a hollow (24) defined within the rib (20); and a sensor (18) positioned within the hollow (24).
- 2. The sensor configuration (10) as claimed in claim 1 wherein the centralizer (16) is a solid body centralizer.
- 3. The sensor configuration (10) as claimed in claim 1 wherein the sensor (18) is entirely contained within the hollow (24).
- 4. The sensor configuration (10) as claimed in claim 1 wherein the sensor (18) is sealed within the hollow (24).
- 5. The sensor configuration (10) as claimed in claim 1 wherein the sensor (18) is a cement integrity sensor.
- 6. The sensor configuration (10) as claimed in claim 1 wherein the sensor (18) is a temperature sensor.
- 7. The sensor configuration (10) as claimed in claim 1 wherein the sensor (18) is a pressure sensor.
- 8. The sensor configuration (10) as claimed in claim 1 wherein the rib (20) is more than one rib (20), at least more than one of the more than one ribs (20) containing sensors (18).
- 9. The sensor configuration (10) as claimed in claim 8 wherein the sensors (18) are selected from the same type of sensor (18) or different sensors (18) for the more than one of the more than one rib (20).
- 10. The sensor configuration (10) as claimed in claim 2 wherein the centralizer (16) comprises a metallic material.
- 11. The sensor configuration (10) as claimed in claim 2 wherein the centralizer (16) comprises a polymeric material.
- 12. A borehole system comprising:a borehole (12);a tubular string (14) disposed within the borehole (12);a centralizer (16) having a rib (20), and the rib (20) defining a hollow (24), disposed upon the tubular string (14);a sensor (18) within the hollow (24).WO 2018/169542PCT/US2017/022896
- 13. A method for acquiring data in a borehole (12) comprising:running a sensor configuration (10) as claimed in claim 1 on a tubular string (14) into a borehole (12);cementing the tubular string (14) in the borehole (12); and sensing with the sensor configuration (10), a parameter in the borehole (12).
- 14. The method as claimed in claim 12 wherein the sensing is over time.
- 15. The method as claimed in claim 11 further including running another tool (26) whose primary function is not sensor interrogation with an interrogator (28) thereon.
- 16. The method as claimed in claim 12 wherein the tool (26) is a drilling assembly.
- 17. The method as claimed in claim 12 wherein the tool (26) is a completion string.
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2017/022896 WO2018169542A1 (en) | 2017-03-17 | 2017-03-17 | Sensor configuration |
Publications (1)
Publication Number | Publication Date |
---|---|
AU2017404493A1 true AU2017404493A1 (en) | 2019-10-24 |
Family
ID=63523140
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
AU2017404493A Abandoned AU2017404493A1 (en) | 2017-03-17 | 2017-03-17 | Sensor configuration |
Country Status (9)
Country | Link |
---|---|
US (1) | US20200063547A1 (en) |
EP (1) | EP3596307A4 (en) |
CN (1) | CN110431284A (en) |
AR (1) | AR111289A1 (en) |
AU (1) | AU2017404493A1 (en) |
BR (1) | BR112019019176A2 (en) |
CA (1) | CA3056749A1 (en) |
MX (1) | MX2019011051A (en) |
WO (1) | WO2018169542A1 (en) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
DE102019004509B4 (en) * | 2019-06-28 | 2024-05-02 | TRACTO-TECHNlK GmbH & Co. KG | Device for dampening a force acting on an electronic component and drill string section of an earth drilling device comprising such a device |
Family Cites Families (13)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
MY115236A (en) * | 1996-03-28 | 2003-04-30 | Shell Int Research | Method for monitoring well cementing operations |
CA2264409A1 (en) * | 1998-03-16 | 1999-09-16 | Halliburton Energy Services, Inc. | Method for permanent emplacement of sensors inside casing |
US7071697B2 (en) * | 2001-01-04 | 2006-07-04 | Schlumberger Technology Corporation | Centralizer including measurement means |
US7185715B2 (en) * | 2003-03-10 | 2007-03-06 | Baker Hughes Incorporated | Apparatus and method of controlling motion and vibration of an NMR sensor in a drilling bha |
US7114562B2 (en) * | 2003-11-24 | 2006-10-03 | Schlumberger Technology Corporation | Apparatus and method for acquiring information while drilling |
US7673682B2 (en) * | 2005-09-27 | 2010-03-09 | Lawrence Livermore National Security, Llc | Well casing-based geophysical sensor apparatus, system and method |
US8302686B2 (en) * | 2007-04-02 | 2012-11-06 | Halliburton Energy Services Inc. | Use of micro-electro-mechanical systems (MEMS) in well treatments |
US9062531B2 (en) * | 2010-03-16 | 2015-06-23 | Tool Joint Products, Llc | System and method for measuring borehole conditions, in particular, verification of a final borehole diameter |
US9243488B2 (en) * | 2011-10-26 | 2016-01-26 | Precision Energy Services, Inc. | Sensor mounting assembly for drill collar stabilizer |
WO2016126244A1 (en) * | 2015-02-04 | 2016-08-11 | Halliburton Energy Services, Inc. | Fluid monitoring using radio frequency identification |
BR112017011643A2 (en) * | 2015-02-09 | 2018-03-06 | Halliburton Energy Services Inc | downhole octg centerer, downhole apparatus and capsule for dispensing a downhole article |
CA2969791C (en) * | 2015-03-03 | 2019-09-24 | Halliburton Energy Services, Inc. | Blade-mounted sensor apparatus, systems, and methods |
BR112017016275A2 (en) * | 2015-03-31 | 2018-03-27 | Halliburton Energy Services Inc | "well monitoring system and method". |
-
2017
- 2017-03-17 WO PCT/US2017/022896 patent/WO2018169542A1/en active Application Filing
- 2017-03-17 CN CN201780088514.9A patent/CN110431284A/en active Pending
- 2017-03-17 AU AU2017404493A patent/AU2017404493A1/en not_active Abandoned
- 2017-03-17 BR BR112019019176A patent/BR112019019176A2/en not_active IP Right Cessation
- 2017-03-17 CA CA3056749A patent/CA3056749A1/en not_active Abandoned
- 2017-03-17 US US16/488,833 patent/US20200063547A1/en not_active Abandoned
- 2017-03-17 EP EP17900852.9A patent/EP3596307A4/en not_active Withdrawn
- 2017-03-17 MX MX2019011051A patent/MX2019011051A/en unknown
-
2018
- 2018-03-16 AR ARP180100621A patent/AR111289A1/en unknown
Also Published As
Publication number | Publication date |
---|---|
US20200063547A1 (en) | 2020-02-27 |
BR112019019176A2 (en) | 2020-04-14 |
WO2018169542A1 (en) | 2018-09-20 |
EP3596307A4 (en) | 2020-04-22 |
CA3056749A1 (en) | 2018-09-20 |
EP3596307A1 (en) | 2020-01-22 |
CN110431284A (en) | 2019-11-08 |
MX2019011051A (en) | 2019-10-17 |
AR111289A1 (en) | 2019-06-26 |
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Date | Code | Title | Description |
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MK4 | Application lapsed section 142(2)(d) - no continuation fee paid for the application |