In various well applications, the subterranean formation is stimulated to enhance recovery of hydrocarbon fluids such as oil and gas. One form of well stimulation is hydraulic fracturing which may be conducted in a wellbore following a drilling operation and an optional casing operation. Hydraulic fracturing operations initially were performed in single stage vertical or near vertical wells. To further improve productivity, however, hydraulic fracturing operations have trended toward use in generally horizontal wells. Although horizontal fracturing operations have improved productivity, current methods have limitations with respect to productivity and efficiency in certain types of subterranean environments and operations.
In general, the present disclosure provides a methodology and system for enhancing hydrocarbon fluid production. A well is formed in a subterranean region by drilling a borehole, e.g. a generally vertical wellbore. At least one tunnel, e.g. two tunnels, may be formed and oriented to extend outwardly from the borehole at least 10 feet into a formation surrounding the borehole. The orientation of the tunnels is selected such that the tunnels extend at a desired azimuthal orientation and/or deviation. For example, the orientation of the tunnels may be selected with respect to a direction of maximum horizontal stress in the formation. A fracture stimulation of the tunnels is performed to create a network of fractures. The orientation of the tunnels ensures that the network of fractures extends through a target zone in a hydrocarbon bearing region of the formation.
Certain embodiments will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate various implementations described herein and are not meant to limit the scope of various technologies described herein, and:
In the following description, numerous details are set forth to provide an understanding of some illustrative embodiments of the present disclosure. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.
The disclosure herein generally relates to a methodology and system for enhancing hydrocarbon fluid production. A well is formed in a subterranean region by drilling a borehole, e.g. a generally vertical wellbore. At least one tunnel, e.g. at least two tunnels, may be formed and oriented to extend outwardly from the borehole at least 10 feet into a formation surrounding the borehole. In some operations, the tunnels may be formed to extend outwardly from the borehole at least 15 feet and in other operations at least 20 feet. For example, some applications may utilize tunnels substantially longer than 20 feet. In various formations, the borehole is oriented generally vertically and the tunnels extend outwardly generally horizontally. However, some applications may utilize a deviated, e.g. horizontal, borehole with tunnels extending outwardly from the deviated borehole. Depending on the application and characteristics of the subterranean region, the tunnels may be oriented generally horizontally, generally vertically, or at desired orientations therebetween.
The orientation of the tunnels may be selected such that each tunnel extends at a desired angle with respect to a direction of principal stresses in the formation. For example, the tunnel azimuths may be oriented in a direction of maximum horizontal stress, minimum horizontal stress, or at a desired other angle with respect to the maximum horizontal stress. Additionally, the tunnel azimuths (as well as the borehole azimuth) may be constant but they may also vary in some applications, e.g. to achieve a desired positioning with respect to a hydrocarbon bearing target zone in a formation.
Once the tunnels are formed, a fracture stimulation of the tunnels may be performed to create a network of fractures. For example, a hydraulic fracturing fluid may be pumped downhole and out through the tunnel or tunnels to create fracture networks extending from each tunnel. The fracture networks may be formed to extend laterally from each tunnel but they also may be formed parallel with the tunnels and/or at other desired orientations. The orientation of the tunnels ensures that the network of fractures extends through a target zone in a hydrocarbon bearing region of the formation.
The diameter of the tunnels may vary according to the formation and/or other parameters of a given operation. By way of example, the tunnels are generally smaller in diameter than casing used along the borehole from which they extend. In some operations, the tunnel diameters may be 2 inches or less and in other operations the tunnel diameters may be 1.5 inches or less. However, some embodiments may utilize tunnels equal to or larger in diameter than the borehole. The diameter of the tunnels may be selected according to parameters of the formation and/or types of equipment used for forming the tunnels. Also, the resultant diameter of the tunnels may vary depending on the technique used to form the tunnels, e.g. drilling, jetting, or other suitable technique.
In some embodiments, the borehole may be drilled at least in part in a non-productive zone of the subterranean formation. The non-productive zone may be a zone which contains limited amounts of hydrocarbon fluid or is less desirable with respect to production of hydrocarbon fluid. Depending on the characteristics of the subterranean region, the borehole may be drilled in nonproductive rock and/or in a region with petrophysical and geo-mechanical properties different from the properties of the target zone. For example, the borehole may be drilled in a region of the formation having a substantially higher minimum in situ stress relative to that of the target zone. It should be noted the tunnels may be used in many types of formations, e.g. laminated formations, to facilitate flow of fluid to the tunnels through fracture networks even in the presence of pinch points between formation layers.
To facilitate production, at least one tunnel is formed which intersects the borehole and extends into a target zone, e.g. a productive zone containing hydrocarbon fluid. Often, a plurality of tunnels, e.g. at least two tunnels, may be formed to extend from the borehole outwardly into the target zone to serve as extended treatment passages. The target zone may be a single region or separate distinct regions of the formation. In some applications, the borehole may be entirely outside of the target zone and a plurality of tunnels may be formed in desired directions to reach the target zone. For example, the tunnels may be formed generally horizontally, generally vertically, generally along desired angles between horizontal and vertical, in generally opposed directions with respect to each other, or at other orientations with respect to each other. In other applications, however, the borehole may extend into or through the target zone.
As described above, the well stimulation may comprise a hydraulic fracturing of the stimulation zone or zones. During hydraulic fracturing, a fracturing fluid may be pumped down through the borehole and out through the plurality of tunnels. The fracturing fluid is forced under pressure from the tunnels out into the surrounding subterranean formation, e.g. into the surrounding hydrocarbon bearing target zone, to fracture the surrounding subterranean formation. For example, the surrounding subterranean formation may be fractured at a plurality of stimulation zones within the overall target zone.
It should be noted the fracturing fluid also may comprise propping agent for providing fracture conductivity after fracture closure. In certain embodiments, the fracturing fluid may comprise acid such as hydrochloric acid, acetic acid, citric acid, hydrofluoric acid, other acids, or mixtures thereof. The fracturing of the stimulation zones within the target zone enhances production of hydrocarbon fluid from the target zone to the wellbore and ultimately to the surface. The target zone may be a productive zone of the subterranean region containing desired hydrocarbon fluid, e.g. oil and/or gas.
Referring generally to
In the example illustrated, the borehole 24 is a generally vertical wellbore extending downwardly from a surface 30. However, some operations may form deviations in the borehole 24, e.g. a lateral section of the borehole 24, to facilitate hydrocarbon recovery. In some embodiments, the borehole 24 may be formed in nonproductive rock of formation 22 and/or in a zone with petrophysical and geo-mechanical properties different from the properties found in the target zone or zones 26.
At least one tunnel 32, e.g. a plurality of tunnels 32, may be formed to intersect the borehole 24. In the example illustrated, at least two tunnels 32 are formed to intersect the borehole 24 and to extend outwardly from the borehole 24. For example, the tunnels 32 may be formed and oriented laterally, e.g. generally horizontally, with respect to the borehole 24. Additionally, the tunnels 32 may be oriented to extend from borehole 24 in different directions, e.g. opposite directions, so as to extend into the desired target zone or zones 26.
The tunnels 32 provide fluid communication with an interior of the borehole/wellbore 24 to facilitate flow of the desired hydrocarbon fluid 28 from tunnels 32, into borehole 24, and up through borehole 24 to, for example, a collection location at surface 30. Furthermore, the tunnels 32 may be oriented in selected directions based on the material forming subterranean formation 22 and on the location of desired target zones 26.
Depending on the characteristics of the subterranean formation 22 and target zones 26, the tunnels 32 may be formed along various azimuths. For example, the tunnels 32 may be formed in alignment with a direction of maximum horizontal stress, represented by arrow 34, in formation 22. However, the tunnels may be formed along other azimuths such as in alignment with a direction of minimum horizontal stress in the formation, as represented by arrow 36.
In some embodiments, the tunnels 32 may be formed at a desired angle or angles with respect to principal stresses when selecting azimuthal directions. According to an example, the tunnel or tunnels 32 may be oriented at a desired angle with respect to the maximum horizontal stress in formation 22. It should be noted the azimuth and/or deviation of an individual tunnel 32 may be constant but the azimuth and/or deviation also may vary along the individual tunnel 32 to, for example, enable formation of the tunnel through a desired zone to facilitate recovery of hydrocarbon fluids 28.
Additionally, at least one of the tunnels 32 may be formed and oriented to take advantage of a natural fracture 38 or multiple natural fractures 38 which occur in formation 22. The natural fracture 38 may be used as a flow conduit which facilitates flow of the hydrocarbon fluid 28 into the tunnel or tunnels 32. Once the hydrocarbon fluid 28 enters the tunnels 32, the fluid is able to readily flow into wellbore 24 for production to the surface or other collection location.
Depending on the parameters of a given formation 22 and hydrocarbon recovery operation, the diameter and length of tunnels 32 also may vary. The tunnels 32 are generally longer than the lengths of perforations formed in a conventional perforation operation. According to an embodiment, the tunnels 32 extend from the borehole 24 at least 10 feet into the formation 22 surrounding the borehole 24. However, some embodiments of the methodology utilize tunnels 32 which extend from the borehole 24 at least 15 feet into the formation 22. Other embodiments of the methodology utilize tunnels 32 which extend from the borehole 24 at least 20 feet into the formation 22. For example, some embodiments may utilize tunnels substantially longer than 20 feet.
Each tunnel 32 also has a diameter generally smaller than the diameter of borehole 24, e.g. smaller than the diameter of casing which may be used to line borehole 24. With respect to diameter, various embodiments utilize tunnels 32 having a diameter of 2 inches or less. However, some embodiments of the methodology utilize tunnels 32 having a diameter of 1.5 inches or less. The actual lengths, diameters, and orientations of tunnels 32 may be adjusted according to the parameters of the formation 22, target zones 26, and objectives of the hydrocarbon recovery operation.
With additional reference to
If the stimulation operation is a hydraulic fracturing operation, fracturing fluid may be pumped from the surface under pressure, down through wellbore 24, into tunnels 32, and then into the stimulation zones 40 surrounding the corresponding tunnels 32 as indicated by arrows 44. The pressurized fracturing fluid 44 causes formation 22 to fracture in a manner which creates the fracture networks 42 in stimulation zones 40. According to an embodiment, the tunnels 32/zones 40 may be fractured sequentially. For example, the fracturing operation may be performed through sequential tunnels 32 and/or sequentially through individual tunnels 32 to cause sequential fracturing of the stimulation zones 40 and creation of the resultant fracture networks 42.
The tunnels 32 may be formed via a variety of techniques, such as various drilling techniques or jetting techniques. For example, drilling equipment may be deployed down into wellbore 24 and used to form the desired number of tunnels 32 in appropriate orientations for a given subterranean environment and production operation. However, the tunnels 32 also may be formed by other suitable techniques, such as jetting techniques, laser techniques, injection of reactive fluid techniques, electrical decomposition techniques, or other tunnel formation techniques. In a specific example, the tunnels 32 may be jetted using hydraulic jetting technology similar to hydraulic jetting technologies available from Radial Drilling Services Ltd, Viper Drill of Houston Tex., Jett-Drill Well Services Ltd, or Fishbones AS of Stavanger Norway.
The use of tunnels 32 during the stimulation operation enables creation of fracture networks 42. The fracture networks 42 provide fractures with an increased density, thus increasing the size of the contact area with respect to each target zone 26 containing hydrocarbon fluid 28. This, in turn, leads to an increase in well productivity compared to wells completed without utilizing tunnels 32.
As illustrated graphically in
The projected oil production from such wells is illustrated graphically in
In an operational example, the orientation of tunnels 32 may be determined based on various well productivity considerations prior to creating the tunnels 32. For example, the tunnels 32 may be created in the direction of maximum horizontal stress to enable formation of fractures which are aligned with the direction of such tunnels 32. In other embodiments, the extended tunnels 32 may be created in a direction perpendicular to a direction of maximum horizontal stress information 22 to enable creation of fractures oriented perpendicular to the direction of tunnels 32.
The tunnels 32 also may be placed at an angle to the principal horizontal stresses such that the created fractures are oblique with respect to the tunnels 32. As described above, individual tunnels 32 also may be oriented to intersect natural fractures 38 within the formation 22 which may be further activated during subsequent stimulation. In some embodiments, the tunnels 32 may be formed at a desired angle with respect to a horizontal plane.
It should be noted production levels corresponding to various orientations of the tunnels 32 can be forecast by employing various well production modeling techniques using software products such as Kinetix™ available from Schlumberger Corporation, Gohfer® available from Barree & Associates, or other suitable software products. Depending on the parameters of a given operation, the wellbore 24 may be an open hole, a cased hole with packers and port collars, or a wellbore with a cased and cemented completion. The tunnels 32 may be formed as extended treatment passages and may be created prior to or subsequent to casing the wellbore 24.
Use of tunnels 32 and the stimulation techniques described herein also may be employed to reduce the amount of sand and material delivered downhole in a variety of fracturing operations while still enhancing production of the desired hydrocarbon fluids. Although the tunnels 32 effectively increase production via vertical wellbore 24, the tunnels 32 and stimulation techniques described herein may be used in vertical wells and deviated wells, e.g. horizontal wells, in unconventional or conventional formations.
Depending on the parameters of a given application, the wellbore geometries described herein may be adjusted according to the type, size, orientation, and other features of the target zone or zones 26. Additionally, the location of the borehole 24 as well as the tunnels 32 may be affected by the type of non-productive zones adjacent the target zone(s) 26 containing desired hydrocarbon fluids 28. Similarly, many different types of equipment, e.g. packers, valves, sleeves, sand screens, and/or other types of equipment may be used in completing the wellbore 24. Various sections of the wellbore 24 may be cased or open-hole depending on the parameters of the specific application.
Although a few embodiments of the system and methodology have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.
The present document is based on and claims priority to U.S. Provisional Application Ser. No. 62/442,240, filed Jan. 4, 2017, which is incorporated herein by reference in its entirety.
Filing Document | Filing Date | Country | Kind |
---|---|---|---|
PCT/US2018/012312 | 1/4/2018 | WO |
Publishing Document | Publishing Date | Country | Kind |
---|---|---|---|
WO2018/129136 | 7/12/2018 | WO | A |
Number | Name | Date | Kind |
---|---|---|---|
2731414 | Binder, Jr. | Jan 1956 | A |
2808109 | Kirk | Oct 1957 | A |
3282337 | Pye | Nov 1966 | A |
3336221 | Ralston | Aug 1967 | A |
3553099 | Savage | Jan 1971 | A |
3704750 | Miles | Dec 1972 | A |
3878884 | Raleigh | Apr 1975 | A |
3892274 | Dill | Jul 1975 | A |
4007797 | Jeter | Feb 1977 | A |
4032460 | Zilch et al. | Jun 1977 | A |
4036732 | Irani et al. | Jul 1977 | A |
4046668 | Farcasiu et al. | Sep 1977 | A |
4046669 | Blaine et al. | Sep 1977 | A |
4108760 | Williams et al. | Aug 1978 | A |
4139450 | Hanson et al. | Feb 1979 | A |
4347118 | Funk et al. | Aug 1982 | A |
4479541 | Wang | Oct 1984 | A |
4519463 | Schuh | May 1985 | A |
4613631 | Espenscheid et al. | Sep 1986 | A |
4640362 | Schellstede | Feb 1987 | A |
4666683 | Brown et al. | May 1987 | A |
4848486 | Bodine | Jul 1989 | A |
4977961 | Avasthi | Dec 1990 | A |
RE33660 | Jelsma | Aug 1991 | E |
5261489 | Jennings, Jr. et al. | Nov 1993 | A |
5335726 | Rodrigues | Aug 1994 | A |
5358051 | Rodrigues | Oct 1994 | A |
5373906 | Braddick | Dec 1994 | A |
5868210 | Johnson et al. | Feb 1999 | A |
5893416 | Read | Apr 1999 | A |
6581690 | Van Drentham-Susman et al. | Jun 2003 | B2 |
7347260 | Ferguson et al. | Mar 2008 | B2 |
7422059 | Jelsma | Sep 2008 | B2 |
7431083 | Olsen | Oct 2008 | B2 |
7441595 | Jelsma | Oct 2008 | B2 |
7686101 | Belew et al. | Mar 2010 | B2 |
7788037 | Soliman | Aug 2010 | B2 |
7971658 | Buckman, Sr. | Jul 2011 | B2 |
7971659 | Gatlin et al. | Jul 2011 | B2 |
8167060 | Brunet et al. | May 2012 | B2 |
8201643 | Soby et al. | Jun 2012 | B2 |
8220547 | Craig et al. | Jul 2012 | B2 |
8372786 | Berkland et al. | Feb 2013 | B2 |
8408333 | Pai et al. | Apr 2013 | B2 |
8420576 | Eoff et al. | Apr 2013 | B2 |
8424620 | Perry, Jr. et al. | Apr 2013 | B2 |
8590618 | Jelsma | Nov 2013 | B2 |
8672034 | Al-Ajmi et al. | Mar 2014 | B2 |
8770316 | Jelsma | Jul 2014 | B2 |
9121272 | Potapenko et al. | Sep 2015 | B2 |
9567809 | Savage | Feb 2017 | B2 |
9803134 | De Wolf et al. | Oct 2017 | B2 |
9976351 | Randall | May 2018 | B2 |
10005955 | Beuterbaugh et al. | Jun 2018 | B2 |
20020005286 | Mazorow et al. | Jan 2002 | A1 |
20030062167 | Surjaatmadja et al. | Apr 2003 | A1 |
20050056418 | Nguyen | Mar 2005 | A1 |
20050230107 | McDaniel et al. | Oct 2005 | A1 |
20060048946 | Al-Muraikhi | Mar 2006 | A1 |
20060070740 | Surjaatmadja et al. | Apr 2006 | A1 |
20060102343 | Skinner et al. | May 2006 | A1 |
20070261852 | Surjaatmadja et al. | Nov 2007 | A1 |
20070261887 | Pai et al. | Nov 2007 | A1 |
20080078548 | Pauls et al. | Apr 2008 | A1 |
20080135292 | Sihler et al. | Jun 2008 | A1 |
20080139418 | Cioletti et al. | Jun 2008 | A1 |
20090017678 | Meier et al. | Jan 2009 | A1 |
20090065253 | Suarez-Rivera et al. | Mar 2009 | A1 |
20090101414 | Brunet et al. | Apr 2009 | A1 |
20090114385 | Lumbye | May 2009 | A1 |
20090250211 | Craig | Oct 2009 | A1 |
20090288884 | Jelsma | Nov 2009 | A1 |
20100126722 | Cornelissen et al. | May 2010 | A1 |
20100187012 | Belew et al. | Jul 2010 | A1 |
20100243266 | Soby et al. | Sep 2010 | A1 |
20100282470 | Alberty et al. | Nov 2010 | A1 |
20110005762 | Poole | Jan 2011 | A1 |
20110017468 | Birch et al. | Jan 2011 | A1 |
20110061869 | Abass | Mar 2011 | A1 |
20110067871 | Burdette et al. | Mar 2011 | A1 |
20110068787 | Freedman et al. | Mar 2011 | A1 |
20110147088 | Brunet et al. | Jun 2011 | A1 |
20120024530 | Todd | Feb 2012 | A1 |
20120067646 | Savage | Mar 2012 | A1 |
20120160567 | Belew et al. | Jun 2012 | A1 |
20120325555 | Jette et al. | Dec 2012 | A1 |
20130000908 | Walters et al. | Jan 2013 | A1 |
20130032349 | Alekseenko | Feb 2013 | A1 |
20130062125 | Savage | Mar 2013 | A1 |
20130213716 | Perry et al. | Aug 2013 | A1 |
20130220606 | Yhuel et al. | Aug 2013 | A1 |
20130233537 | McEwen-King et al. | Sep 2013 | A1 |
20130304444 | Strobel et al. | Nov 2013 | A1 |
20130341029 | Roberts et al. | Dec 2013 | A1 |
20140096950 | Pyecroft et al. | Apr 2014 | A1 |
20140096966 | Freitag | Apr 2014 | A1 |
20140102708 | Purkis et al. | Apr 2014 | A1 |
20140144623 | Pyecroft et al. | May 2014 | A1 |
20140340082 | Yang et al. | Nov 2014 | A1 |
20150007988 | Ayasse | Jan 2015 | A1 |
20150096748 | West | Apr 2015 | A1 |
20150107825 | Miller et al. | Apr 2015 | A1 |
20150218925 | Lecampion et al. | Aug 2015 | A1 |
20150337613 | Belew et al. | Nov 2015 | A1 |
20150356403 | Storm, Jr. | Dec 2015 | A1 |
20160053597 | Brown et al. | Feb 2016 | A1 |
20160115772 | Graham et al. | Apr 2016 | A1 |
20160131787 | Quirein et al. | May 2016 | A1 |
20160153239 | Randall | Jun 2016 | A1 |
20160160619 | Randall | Jun 2016 | A1 |
20160215581 | Ingraham et al. | Jul 2016 | A1 |
20160281480 | Pyecroft et al. | Sep 2016 | A1 |
20160312587 | Montaron et al. | Oct 2016 | A1 |
20170030180 | Maurer | Feb 2017 | A1 |
20170204713 | Bell et al. | Jul 2017 | A1 |
20180023375 | Potapenko et al. | Jan 2018 | A1 |
20180112468 | Savage et al. | Apr 2018 | A1 |
20180163122 | Panga et al. | Jun 2018 | A1 |
20180306017 | Savage | Oct 2018 | A1 |
20180328118 | Morse et al. | Nov 2018 | A1 |
20190017358 | Morse et al. | Jan 2019 | A1 |
20200157901 | Cardon et al. | May 2020 | A1 |
Number | Date | Country |
---|---|---|
102504292 | Jun 2012 | CN |
105349166 | Feb 2016 | CN |
2631422 | Aug 2013 | EP |
2672409 | Dec 2013 | EP |
2198119 | Oct 2017 | EP |
2406863 | Apr 2005 | GB |
9113177 | Sep 1991 | WO |
9420727 | Sep 1994 | WO |
0046484 | Aug 2000 | WO |
03050377 | Jun 2003 | WO |
2004046494 | Jun 2004 | WO |
2005090747 | Sep 2005 | WO |
2009096805 | Aug 2009 | WO |
2009157812 | Dec 2009 | WO |
2013019390 | Feb 2013 | WO |
2015089458 | Jun 2015 | WO |
2016138005 | Sep 2016 | WO |
2017074722 | May 2017 | WO |
2017078989 | May 2017 | WO |
2018049311 | Mar 2018 | WO |
2018049367 | Mar 2018 | WO |
2018049368 | Mar 2018 | WO |
2019014160 | Jan 2019 | WO |
2019014161 | Jan 2019 | WO |
2019168885 | Sep 2019 | WO |
2019241454 | Dec 2019 | WO |
2019241455 | Dec 2019 | WO |
2019241456 | Dec 2019 | WO |
2019241457 | Dec 2019 | WO |
2019241458 | Dec 2019 | WO |
Entry |
---|
Alekseenko, O. P., Potapenko, D.I., Chemy, S.G., Esipov, D.V., Kuranakov, D.S., Lapin, V.N. “3-D Modeling of fracture initiation from perforated non-cemented wellbore”, SPE J., vol. 18, No. 3, 589-600, 2013. |
Alekseenko O.P. , Potapenko D.I. , Kuranakov D.S., Lapin V.N., Cherny S.G., and Esipov D.V. “3D Modeling of Fracture Initiation from Cemented Perforated Wellbore”, presented at 19th European Conference on Fracture, Kazan, Russia, Aug. 26-31, 2012. |
Potyondy, “Simulating stress corrosion with a bonded-particlle model for rock”, International Journal of Rock Mechanics and Mining Sciences, vol. 44, Issue 5, Jul. 2007, pp. 677-691. |
Atkinson et al., “Acoustic Emission During Stress Corrosion Cracking in Rocks”, Earthquake Prediction: An International Review, vol. 4, pp. 605-616, 1981. |
Wikipedia.org, “Wood's metal”, edited May 4, 2019, Accessed Jul. 3, 2019; https://en.wikipedia.org/wiki/Wood%27s_metal. |
Pinto, I.S.S. et al., “Biodegradable chelating agents for industrial, domestic, and agricultural applications—a review”, Environmental Science and Pollution Research, 2014, 21, pp. 11893-11906. |
Office Action received in U.S. Appl. No. 16/629,992 dated Apr. 21, 2021, 53 pages. |
Office Action received in U.S. Appl. No. 16/629,992 dated Jan. 18, 2022, 11 pages. |
Office Action issued in Eurasian Patent Application No. 201991640 dated Nov. 17, 2021, 4 pages with English translation. |
Office Action issued in U.S. Appl. No. 16/332,418 dated Nov. 29, 2021, 12 pages. |
Office Action issued in Kuwait patent application No. KW/P/2019/221 dated Oct. 13, 2021, 6 pages. |
2nd Office Action issued in Chinese patent application 201880014781.6 dated Oct. 22, 2021, 23 pages with English Translation. |
Number | Date | Country | |
---|---|---|---|
20210131242 A1 | May 2021 | US |
Number | Date | Country | |
---|---|---|---|
62442240 | Jan 2017 | US |