Office Action 1: Non-Final Rejection (2024-08-28)
Rejection types: 102 - Lack of Novelty, 103 - Obviousness, 112 - Written Description/Enablement

CLAIMS:
CLAIMS

What is claimed is:

1\. A magnetic coupling mechanism in a downhole flow control tool, comprising:a first chamber configured to receive i) production fluids or ii) injection fluids;
a first component with a plurality of magnets located within the first chamber, and wherein the plurality of magnets are configured in a Halbach Array;
a second chamber configured to exclude a wellbore environment;
a second component with a plurality of magnets located within the second chamber, and
wherein the plurality of magnets are configured in a Halbach Array;
wherein the first chamber and the second chamber share a non-magnetic separation; and
wherein the first component is magnetically coupled to the second component by a plurality of strong magnetic flux.

2\. The magnetic coupling mechanism of claim 1, wherein:the plurality of magnets in the first component are configured to produce a weak magnetic flux directed away from the non-magnetic separation and a strong magnetic flux directed towards the non-magnetic separation.

3\. The magnetic coupling mechanism of claim 1, wherein:the plurality of magnets in the second component are configured to produce a weak magnetic flux directed away from the non-magnetic separation and a strong magnetic flux directed towards the non-magnetic separation.

4\. The magnetic coupling mechanism of claim 1, wherein:
the first component is configured to axially translate; and
wherein the second component is biased to axially translate by the plurality of strong magnetic flux.

5\. The magnetic coupling mechanism of claim 1, wherein:the first component is configured to rotationally translate; and
wherein the second component is biased to rotationally translate by the plurality of strong magnetic flux.

6\. The magnetic coupling mechanism of claim 1, wherein:the first component and the second component are separated by the non-magnetic separation.

7\. The magnetic coupling mechanism of claim 1, wherein the downhole flow control tool comprises a valve body with a flow path, an energy harvesting device, an adjustable valve, and a unit controller.

8\. The magnetic coupling mechanism of claim 7, wherein:the flow path comprises a first fluid port within a fluid chamber fluidically coupled to a second fluid port via at least one fluid duct;
wherein the energy harvesting device comprises a generator and a turbine assembly;
wherein the turbine assembly is fluidically coupled to the flow path and located between the second fluid port and the fluid chamber; and
wherein the turbine assembly is configured to induce rotation within the generator.

9\. The magnetic coupling mechanism of claim 8, wherein the first component and the second component are located within the energy harvesting device.

10\. The magnetic coupling mechanism of claim 7, wherein:the adjustable valve comprises a drive mechanism and a stem head;
wherein the drive mechanism is communicatively coupled to the unit controller;
wherein the stem head is located within a fluid chamber; and
wherein the drive mechanism is configured to position the stem head in i) a first position, ii) a second position, or iii) a third position.

11\. The magnetic coupling mechanism of claim 10, wherein the first component and the second component are located within the adjustable valve.

12\. A method of actuating a downhole mechanism by a magnetic coupling within a downhole tool assembly, comprising:positioning a first component in a first chamber, wherein the first component comprises a plurality of magnets, wherein the plurality of magnets are configured to produce a strong magnetic flux on a first side;
positioning a second component into a second chamber, wherein the second component comprises a plurality of magnets, wherein the plurality of magnets are configured to produce a strong magnetic flux on a second side;
wherein the first chamber and the second chamber are coupled by a non-magnetic separation;
wherein the first side of the first component is oriented towards the non-magnetic separation;

wherein the second side of the second component is oriented towards the non-magnetic separation;
magnetically coupling the strong magnetic flux on the first side of the first component to the strong magnetic flux on the second side of the second component; and
actuating the second component with the first component.

13\. The method of claim 12, wherein:the first chamber comprises a flow path for wellbore fluids; and wherein the second chamber excludes a wellbore environment.

14\. The method of claim 13, further comprising:rotating the first component with a flowrate of wellbore fluids; and
generating electrical power within the second chamber in response to a rotational motion of the second component.

15\. Th method of claim 12, wherein:the first chamber excludes the wellbore environment; and
wherein the second chamber comprises a flow path for wellbore fluids.

16\. Th method of claim 13, further comprising:positioning a first component with an actuator into i) a first position, ii) a second position, or iii) a third position; and
changing a flowrate of wellbore fluids within the flow path with a second component in response to the position of the first component.

17\. The method of claim 13, wherein the wellbore fluids are i) production fluids or ii) injection fluids.

18\. A downhole flow control tool system, comprising:a first component in a first chamber, wherein the first component comprises a plurality of magnets, wherein the plurality of magnets are configured to produce a strong magnetic flux on a first side;
a second component in a second chamber, wherein the second component comprises a plurality of magnets, wherein the plurality of magnets are configured to produce a strong magnetic flux on a second side, and wherein the first chamber and the second chamber are coupled by a non-magnetic separation;
a magnetic coupling by the strong magnetic flux on the first side of the first component and the strong magnetic flux on the second side of the second component; and
wherein the magnetic coupling is configured to:
actuating the second component with the first component.

19\. The downhole flow control tool system of claim 18, wherein actuating the second component with the first component further comprises:rotating the first component within a flow path with a flowrate of wellbore fluids; and
generating electrical power within the second chamber that excludes a wellbore environment in response to a rotational motion of the second component.

20\. The downhole flow control tool system of claim 18, wherein actuating the second component with the first component further comprises:
positioning a first component with an actuator into i) a first position, ii) a second position, or iii) a third position, wherein the first chamber excludes a wellbore environment; and
changing a flowrate of wellbore fluids within a flow path with a second component in response to the position of the first component.

OFFICE ACTION:
DETAILED ACTION
Notice of AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Drawings
The drawings are objected to under 37 CFR 1.83(a).  The drawings must show every feature of the invention specified in the claims.  Therefore, the features “the first component and the second component are located within the adjustable valve.” (claim 11) and “the first chamber excludes a wellbore environment” (claims 15 (line 2) and 20 (line 4)), must be shown or the feature(s) canceled from the claim(s).  No new matter should be entered.
Corrected drawing sheets in compliance with 37 CFR 1.121(d) are required in reply to the Office action to avoid abandonment of the application. Any amended replacement drawing sheet should include all of the figures appearing on the immediate prior version of the sheet, even if only one figure is being amended. The figure or figure number of an amended drawing should not be labeled as “amended.” If a drawing figure is to be canceled, the appropriate figure must be removed from the replacement sheet, and where necessary, the remaining figures must be renumbered and appropriate changes made to the brief description of the several views of the drawings for consistency. Additional replacement sheets may be necessary to show the renumbering of the remaining figures. Each drawing sheet submitted after the filing date of an application must be labeled in the top margin as either “Replacement Sheet” or “New Sheet” pursuant to 37 CFR 1.121(d). If the changes are not accepted by the examiner, the applicant will be notified and informed of any required corrective action in the next Office action. The objection to the drawings will not be held in abeyance.
Claim Rejections - 35 USC § 112
The following is a quotation of the first paragraph of 35 U.S.C. 112(a):
(a) IN GENERAL.—The specification shall contain a written description of the invention, and of the manner and process of making and using it, in such full, clear, concise, and exact terms as to enable any person skilled in the art to which it pertains, or with which it is most nearly connected, to make and use the same, and shall set forth the best mode contemplated by the inventor or joint inventor of carrying out the invention.
The following is a quotation of the first paragraph of pre-AIA  35 U.S.C. 112:
The specification shall contain a written description of the invention, and of the manner and process of making and using it, in such full, clear, concise, and exact terms as to enable any person skilled in the art to which it pertains, or with which it is most nearly connected, to make and use the same, and shall set forth the best mode contemplated by the inventor of carrying out his invention.
Claims 11, 15 and 20 are rejected under 35 U.S.C. 112(a) or 35 U.S.C. 112 (pre-AIA ), first paragraph, as failing to comply with the written description requirement. The claim(s) contains subject matter which was not described in the specification in such a way as to reasonably convey to one skilled in the relevant art that the inventor or a joint inventor, or for applications subject to pre-AIA  35 U.S.C. 112, the inventor(s), at the time the application was filed, had possession of the claimed invention.
Regarding claim 11, there is insufficient support for the limitation  “the first component and the second component are located within the adjustable valve.” The disclosure does not provide any explanation as to how the first component ( the turbine assembly 300 (pp[0035])), and the second component (rotor coupling plate 360 (pp[0036])), are able to be placed within the adjustable valve 212. The disclosure provides support for the first component and second component to be positioned within a power harvesting device 210 (pp[0035]) but not the adjustable valve 212.
Regarding claims 15 (line 2) and 20 (line 4), there is insufficient support for the limitation “the first chamber excludes a wellbore environment” because the disclosure mentions that the turbine 316 is within a flow path that allows fluid 312 to flow and contact the turbine 316 such that the turbine 316 transforms fluid motion into rotational motion (pp[0035]) and this rotational motion then rotates the rotor 336 which is blocked by 368 from receiving fluid flow (pp[0036]).The disclosure does not sufficiently disclose how the flow control tool system can operate as intended, i.e. “actuating the second component with the first component” as claimed in claims 12 and 18, if the turbine 316 is blocked off, i.e. excludes a wellbore environment.
The following is a quotation of 35 U.S.C. 112(b):
(b)  CONCLUSION.—The specification shall conclude with one or more claims particularly pointing out and distinctly claiming the subject matter which the inventor or a joint inventor regards as the invention.
The following is a quotation of 35 U.S.C. 112 (pre-AIA ), second paragraph:
The specification shall conclude with one or more claims particularly pointing out and distinctly claiming the subject matter which the applicant regards as his invention.
Claims 1-11, 15 and 20 are rejected under 35 U.S.C. 112(b) or 35 U.S.C. 112 (pre-AIA ), second paragraph, as being indefinite for failing to particularly point out and distinctly claim the subject matter which the inventor or a joint inventor (or for applications subject to pre-AIA  35 U.S.C. 112, the applicant), regards as the invention.
Regarding claims 15 and 20, it is unclear what the metes and bounds are of the limitation “the first chamber excludes a wellbore environment” because this limitation contradicts the recitation of  “actuating the second component with the first component” as recited in claims 12 and 18. The disclosure mentions that the turbine 316 is within a flow path that allows fluid 312 to flow and contact the turbine 316 such that the turbine 316 transforms fluid motion into rotational motion (pp[0035]) and this rotational motion then rotates the rotor 336 which is blocked by 368 from receiving fluid flow (pp[0036]).Therefore, it is unclear how the flow control tool system can operate as intended, i.e. “actuating the second component with the first component” as recited in claims 12 and 18, if the turbine 316 is be blocked off.
Regarding claims 1 (line 5), 13 (line 2), 15 (line 2), 19 (line 4) and 20 (line 4), it is unclear what the metes and bounds are of the limitation “excludes a wellbore environment” because the scope of this limitation is not adequately defined.  The specification discloses that the electronic flow control node 200, which includes the power harvesting device 210 comprising the first and second components, will be placed in the wellbore 102. As such, both the first and second components will be exposed to conditions in the wellbore such as the high temperatures and pressures. As such, both the first and second components will be exposed to “a wellbore environment”. Therefore, it is unclear how the first and second components can be excluded from “a wellbore environment” when they are being disposed within the wellbore environment . For examination purposes, the examiner will interpret “a wellbore environment” as fluids within the wellbore, e.g. drilling fluid or production fluids.
Claims 2-11 are also rejected under this statute as the claims depend from claim 1.
Claim Rejections - 35 USC § 102
In the event the determination of the status of the application as subject to AIA  35 U.S.C. 102 and 103 (or as subject to pre-AIA  35 U.S.C. 102 and 103) is incorrect, any correction of the statutory basis (i.e., changing from AIA  to pre-AIA ) for the rejection will not be considered a new ground of rejection if the prior art relied upon, and the rationale supporting the rejection, would be the same under either status.
The following is a quotation of the appropriate paragraphs of 35 U.S.C. 102 that form the basis for the rejections under this section made in this Office action:
A person shall be entitled to a patent unless –
(a)(1) the claimed invention was patented, described in a printed publication, or in public use, on sale, or otherwise available to the public before the effective filing date of the claimed invention.
Claim(s) 1-6, 12-14 and 16-19 are rejected under 35 U.S.C. 102(a)(1) as being anticipated by Agnihotri et al. (U.S. Publication No. 20180320482).
Regarding claim 1, Agnihotri teaches a magnetic coupling mechanism (Fig. 2) in a downhole flow control tool (103; Fig. 1, 2, pp[0023]), comprising:
a first chamber configured to receive (the first chamber is within the inside of the drill pipe 116 in the highlighted region of the drill pipe 116 as shown in the annotated version of fig. 2 below.) i) production fluids or ii) injection fluids (drilling fluid flows through first chamber; pp[0023]);
a first component (first component comprising 204, 208, 210 and 222; Fig. 2) with a plurality of magnets located within the first chamber  and wherein the plurality of magnets are configured in a Halbach Array (the  drive array 222 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils arranged in a Halbach array; pp[0024]);
a second chamber (252; fig.2, pp[0027]) configured to exclude a wellbore environment (230 prevents drilling fluid from entering 252; pp[0027]);
a second component (224) with a plurality of magnets located within the second chamber, and wherein the plurality of magnets are configured in a Halbach Array (follower array 224 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils, arranged in a Halbach array; pp[0024]);
wherein the first chamber (first chamber as shown below) and the second chamber (252) share a non-magnetic separation (230 may be ceramic, polymers or fiberglass; pp[0024],[0027], Fig. 2); and
wherein the first component (222) is magnetically coupled to the second component (224) by a plurality of strong magnetic flux (drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228; pp[0029]).
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Figure 2(annotated)- First chamber
Regarding claim 2,  Agnihotri teaches the magnetic coupling mechanism of claim 1, wherein: the plurality of magnets (Fig. 3) in the first component (222) are configured to produce a weak magnetic flux  (flux direction 330 in section 310a which is  normal to surface of magnetic coupling 220. The magnetic field between drive array 222 and follower array 224 is stronger than using only array sections that produce fluxes normal to the surface; pp[0024], [0034], Fig. 3. ) directed away from the non-magnetic separation (230; Fig. 3) and a strong magnetic flux (310d; Fig. 3, pp[0034], [0035]) directed towards the non-magnetic separation (230; Fig. 3).
Regarding claim 3, Agnihotri teaches the magnetic coupling mechanism of claim 1, wherein: the plurality of magnets in the second component (224; Fig. 3) are configured to produce a weak magnetic flux (320c) directed away from the non-magnetic separation (230) and a strong magnetic flux (320b; pp[0035]) directed towards the non-magnetic separation (230; Fig. 3).
Regarding claim 4, Agnihotri  teaches the magnetic coupling mechanism of claim 1, wherein: the first component (222) is configured to axially translate (Because blades 204 are angled with respect to the flow of drilling fluid, the drilling fluid pushes against blades 204 and causes turbine 202 to spin, producing rotational motion. This rotational motion is transferred to drive array 222 by drive shaft 210; pp[0029]); and wherein the second component (224) is biased to axially translate by the plurality of strong magnetic flux (Because drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228, the rotational motion of drive array 222 is transferred to follower array 224 across barrier 230).
Regarding claim 5, Agnihotri  teaches the magnetic coupling mechanism of claim 1, wherein: the first component (222) is configured to rotationally translate (Because blades 204 are angled with respect to the flow of drilling fluid, the drilling fluid pushes against blades 204 and causes turbine 202 to spin, producing rotational motion. This rotational motion is transferred to drive array 222 by drive shaft 210; pp[0029]); and wherein the second component (224) is biased to rotationally translate by the plurality of strong magnetic flux (Because drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228, the rotational motion of drive array 222 is transferred to follower array 224 across barrier 230.).
Regarding claim 6, Agnihotri  teaches the magnetic coupling mechanism of claim 1, wherein: the first component (222) and the second component (224) are separated by the non-magnetic separation (230 may be ceramic, polymers or fiberglass; pp[0024],[0027], Fig. 2).
Regarding claim 12,  Agnihotri teaches a method of actuating a downhole mechanism by a magnetic coupling within a downhole tool assembly (Abstract, Fig. 2), comprising:
positioning a first component (first component comprising 204, 208, 210 and 222; Fig. 2) in a first chamber (the first chamber is within the inside of the drill pipe 116 in the highlighted region of the drill pipe 116 as shown in the annotated version of Figure 2 above.), wherein the first component comprises a plurality of magnets (the  drive array 222 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils arranged in a Halbach array; pp[0024]), wherein the plurality of magnets are configured to produce a strong magnetic flux on a first side (the magnets within 222 produce magnetic a strong flux from one side facing 224; pp[0024], Fig. 2);
positioning a second component (224) into a second chamber (252; fig.2, pp[0027]), wherein the second component comprises a plurality of magnets (follower array 224 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils, arranged in a Halbach array; pp[0024]), wherein the plurality of magnets are configured to produce a strong magnetic flux on a second side  (the magnets within 224 produce magnetic a second strong flux from a second side facing 222; pp[0024], Fig. 2);
wherein the first chamber and the second chamber are coupled by a non-magnetic separation (230 may be ceramic, polymers or fiberglass; pp[0024],[0027], Fig. 2);
wherein the first side of the first component is oriented towards the non-magnetic separation (first side, as discussed above, are oriented towards 230; pp[0024], Fig. 2);
wherein the second side of the second component is oriented towards the non-magnetic separation (second side, as discussed above, are oriented towards 230; pp[0024], Fig. 2);
magnetically coupling the strong magnetic flux on the first side of the first component to the strong magnetic flux on the second side of the second component (pp [0029], [0035], Fig. 2, 3); and
actuating the second component with the first component (Because drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228, the rotational motion of drive array 222 is transferred to follower array 224 across barrier 230. Follower array 224 is coupled to load 250 through follower shaft 240. As a result, the rotational motion produced by turbine 202 is transmitted to load 250; pp[0029], Fig. 2).
Regarding claim 13, Agnihotri teaches the method of claim 12, wherein: the first chamber comprises a flow path for wellbore fluids (drilling fluid flows through first chamber; pp[0023]); and wherein the second chamber excludes a wellbore environment (230 prevents drilling fluid from entering 252; pp[0027]).
Regarding claim 14, Agnihotri teaches  the method of claim 13, further comprising: rotating the first component with a flowrate of wellbore fluids (an axial flow turbine including an impeller located in throat 208 of drill pipe 116 and configured to capture the kinetic energy of drilling fluid flow to produce rotational motion; pp[0023]; and generating electrical power within the second chamber in response to a rotational motion of the second component (load 250 may be a generator that transforms the rotational motion of follower shaft 240 into electrical current; pp[0026], [0030]).
Regarding claim 16, Agnihotri teaches the method of claim 13, further comprising: positioning a first component with an actuator (204, 202 and 210 are in combination “the actuator”; pp[0029]) into i) a first position (202 beings to rotate due to drilling fluid; pp[0029]), ii) a second position, or iii) a third position; and changing a flowrate of wellbore fluids within the flow path with a second component in response to the position of the first component (After drilling fluid passes turbine 202, it continues through throat 208 and around barrier 230 into fluid passage 234. For example, fluid passage 234 may be an annulus between barrier 230 and drill pipe 116. From fluid passage 234, drilling fluid continues downhole toward drill bit 101. As such, the flow rate of the fluid will change as it traverses towards the drill bit; pp[0031]).
Regarding claim 17, Agnihotri teaches the method of claim 13, wherein the wellbore fluids are i) production fluids or ii) injection fluids (drilling fluid flows through first chamber; pp[0023]).
Regarding claim 18,  Agnihotri  teaches a downhole flow control tool system, comprising:
a first component  (first component comprising 204, 208, 210 and 222; Fig. 2)  in a first chamber  (the first chamber is within the inside of the drill pipe 116 in the highlighted region of the drill pipe 116 as shown above in the annotated version of Fig.2), wherein the first component comprises a plurality of magnets  (the  drive array 222 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils arranged in a Halbach array; pp[0024]), wherein the plurality of magnets are configured to produce a strong magnetic flux on a first side (the magnets within 222 produce magnetic a strong flux from one side facing 224; pp[0024], Fig. 2);
a second component (224) in a second chamber (252; fig.2, pp[0027]), wherein the second component comprises a plurality of magnets (follower array 224 includes an annular array of magnetic sections, which may include permanent magnets or electromagnetic coils, arranged in a Halbach array; pp[0024]), wherein the plurality of magnets are configured to produce a strong magnetic flux on a second side (the magnets within 224 produce magnetic a second strong flux from a second side facing 222; pp[0024], Fig. 2), and wherein the first chamber and the second chamber are coupled by a non-magnetic separation (230 may be ceramic, polymers or fiberglass; pp[0024],[0027], Fig. 2);
a magnetic coupling by the strong magnetic flux on the first side of the first component and the strong magnetic flux on the second side of the second component  (pp[0029], [0035], Fig. 2, 3); and
wherein the magnetic coupling is configured to: actuating the second component with the first component  (Because drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228, the rotational motion of drive array 222 is transferred to follower array 224 across barrier 230. Follower array 224 is coupled to load 250 through follower shaft 240. As a result, the rotational motion produced by turbine 202 is transmitted to load 250; pp[0029], Fig. 2).
Regarding claim 19, Agnihotri  teaches the downhole flow control tool system of claim 18, wherein actuating the second component with the first component further comprises:
rotating the first component within a flow path with a flowrate of wellbore fluids (Because blades 204 are angled with respect to the flow of drilling fluid, the drilling fluid pushes against blades 204 and causes turbine 202 to spin, producing rotational motion. This rotational motion is transferred to drive array 222 by drive shaft 210; pp[0029]); and generating electrical power within the second chamber that excludes a wellbore environment in response to a rotational motion of the second component  (Because drive array 222 is magnetically coupled to follower array 224 of magnetic coupling 220 by magnetic field 228, the rotational motion of drive array 222 is transferred to follower array 224 across barrier 230. Follower array 224 is coupled to load 250 through follower shaft 240. As a result, the rotational motion produced by turbine 202 is transmitted to load 250 and load 250 may be a generator that transforms the rotational motion of follower shaft 240 into electrical current; pp[0026],[0029], [0030], Fig. 2).
Claim Rejections - 35 USC § 103
The following is a quotation of 35 U.S.C. 103 which forms the basis for all obviousness rejections set forth in this Office action:
A patent for a claimed invention may not be obtained, notwithstanding that the claimed invention is not identically disclosed as set forth in section 102, if the differences between the claimed invention and the prior art are such that the claimed invention as a whole would have been obvious before the effective filing date of the claimed invention to a person having ordinary skill in the art to which the claimed invention pertains. Patentability shall not be negated by the manner in which the invention was made.
The factual inquiries for establishing a background for determining obviousness under 35 U.S.C. 103 are summarized as follows:
1. Determining the scope and contents of the prior art.
2. Ascertaining the differences between the prior art and the claims at issue.
3. Resolving the level of ordinary skill in the pertinent art.
4. Considering objective evidence present in the application indicating obviousness or nonobviousness.
Claim(s) 7 and 10 are rejected under 35 U.S.C. 103 as being unpatentable over in view of Frosell et al. (U.S. Publication No. 20190010783).
Regarding claim 7, Agnihotri teaches the magnetic coupling mechanism of claim 1, wherein the downhole flow control tool comprises, an energy harvesting device (turbine 202 as illustrated in FIG. 2 is an axial flow turbine including an impeller located in throat 208 of drill pipe 116 and configured to capture the kinetic energy of drilling fluid flow to produce rotational motion; pp[0023]. The rotational motion produced by turbine 202 is transmitted to load 250 which can be a generator; pp[0029], [0030], [0062])
Agnihotri is silent regarding a valve body with a flow path, an adjustable valve and unit controller.
Frosell, drawn to a variable flow resistance system that be used on a drill string, discloses that  said system comprises a valve body with a flow path, an adjustable valve (the system 25 comprises a power generator 48 which can be used to run actuator 44 which controls a valve. The actuator 44 may be used as or include an adjustable valve to be in a fully open position, a fully closed position, or an intermediate position to control the flow rate of fluid through the system 25 (the system 25 therefore has a fluid flow path); pp[0037], [0040])  and unit controller (a controller and corresponding electronics 46 to control and manage the operation of the components of the system 25. In one embodiment, the controller may be in communication with or coupled to the flow rate sensor and the actuator 44 to control the actuator 44 based upon the measured flow rate and/or measured fluctuations of flow rate; pp[0047]).
Therefore, it would have been obvious to one of ordinary skill in the art before the effective filing date of the claimed invention to modify the system of Agnihotri such that the generator of Agnihotri is coupled with flow resistance system comprising the actuator, valve and controller, as taught by Frosell, because the valve will control of flow rate of fluid through the downhole system and the controller will allow control of the valve and thus facilitate in the adjustment of the flow of fluid (pp[0037], [0047], Frosell). Note that Agnihotri discloses a generator to power downhole tools but does not disclose the type of downhole devices that can be coupled to the generator, e.g. a valve, which forces the reader to look elsewhere for a more detailed description for actual implementation. Frosell teaches such details in an analogous assembly (pp[0035], Frosell).
Regarding claim 10, the combination of Agnihotri and Frosell teaches the magnetic coupling mechanism of claim 7.
Frosell further disclosure wherein: the adjustable valve comprises a drive mechanism (the actuator 44; pp[0037], Fig.2) and a stem head (the closure element of the valve is the “stem head”; pp[0037]); wherein the drive mechanism is communicatively coupled to the unit controller (he controller may be in communication with or coupled to the flow rate sensor and the actuator 44 to control the actuator 44 based upon the measured flow rate and/or measured fluctuations of flow rate; pp[0047]); wherein the stem head is located within a fluid chamber (the valve is located within the chamber of 25 to control the flow rate of fluid through the system 25; pp[0037], Fig. 2) ; and wherein the drive mechanism (44) is configured to position the stem head in i) a first position, ii) a second position, or iii) a third position (the actuator 44 may be used as or include an adjustable valve to be in a fully open position, a fully closed position, or an intermediate position; pp[0037]).
Allowable Subject Matter
Claims 8 and 9 would be allowable if rewritten to overcome the rejection(s) under 35 U.S.C. 112(b) or 35 U.S.C. 112 (pre-AIA ), 2nd paragraph, set forth in this Office action and to include all of the limitations of the base claim and any intervening claims.
Regarding claim 8, the combination of Agnihotri and Frosell does not teach the flow path comprises a first fluid port within a fluid chamber fluidically coupled to a second fluid port via at least one fluid duct and wherein the turbine assembly is fluidically coupled to the flow path and located between the second fluid port and the fluid chamber.
It would not be obvious to modify the combination with the above features because the turbine of Agnihotri is located on the opposite side of the magnetic coupler, away from the generator and the generator of Agnihotri will be coupled to the flow resistance system as taught by Frosell. As such, the turbine of Agnihotri is not positioned between a second fluid port and the fluid chamber. Furthermore, rearranging the turbine to be configured in the manner claimed above will prevent the system of Agnihotri from operating as intended because the location of the turbine of Agnihotri allows it to receive drilling fluid so that it can rotate.  Furthermore, more reference, alone or in combination with Agnihotri and Frosell teaches a first fluid port within a fluid chamber fluidically coupled to a second fluid port via at least one fluid duct and modifying the combination of Agnihotri and Frosell with this feature will be improper hindsight.
Conclusion


NEXT OFFICE ACTION: EXAMINER'S COMMENT
Notice of AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Reasons for Allowance
Claims 1-6 and 9-20 are allowed.
The following is an examiner’s statement of reasons for allowance:
The closest prior art to claims 1, 12 and 18 is Agnihotri et al. (U.S. Publication No. 20180320482).
Claims 1, 12 and 18 now include all of the limitations of claim 8, as well as intervening claim 7,  which was indicated as having allowable subject matter detailed in the Non-final Rejection mailed on 08/28/2024. As such, claims 1, 12 and 18 are now allowable. See Allowable Subject Matter section in the Non-final Rejection mailed on 08/28/2024 for further explanation regarding allowability.
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”
Conclusion

CITED REFERENCE SUMMARIES: Ref US20180320482A1: Claims:
A magnetic coupling of a downhole tool comprising: a first annular array of magnetic sections; a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array; and a barrier disposed between the first annular array and the second annular array, the barrier including an erosion-resistant layer.
a first annular array of magnetic sections;
a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array; and
a barrier disposed between the first annular array and the second annular array, the barrier including an erosion-resistant layer.
The magnetic coupling of claim 1 , wherein: the first annular array has a first outer diameter; the second annular array has a second outer diameter approximately equal to the first outer diameter; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately parallel to the common axis of rotation.
the first annular array has a first outer diameter;
the second annular array has a second outer diameter approximately equal to the first outer diameter;
the first annular array and the second annular array are configured to rotate about a common axis of rotation; and
the magnetic field is oriented approximately parallel to the common axis of rotation.
The magnetic coupling of claim 1 , wherein: the first annular array has an inner diameter; the second annular array has an outer diameter smaller than the inner diameter; the second annular array is disposed within the inner diameter of the first annular array; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately perpendicular to the common axis of rotation.
the first annular array has an inner diameter;
the second annular array has an outer diameter smaller than the inner diameter;
the second annular array is disposed within the inner diameter of the first annular array;
the magnetic field is oriented approximately perpendicular to the common axis of rotation.
The magnetic coupling of claim 1 , wherein the erosion-resistant layer includes a layer of titanium.
The magnetic coupling of claim 1 , wherein the second annular array comprises a plurality of permanent magnets.
The magnetic coupling of claim 5 , wherein a magnet among the plurality of permanent magnets is a samarium cobalt magnet.
The magnetic coupling of claim 1 , wherein the second annular array comprises a plurality of electromagnetic coils.
The magnetic coupling of claim 7 , further comprising a bootstrap circuit for energizing the plurality of electromagnetic coils, the bootstrap circuit comprising: a battery; and a first diode coupled to the battery, the first diode permitting the battery to supply electrical current to the plurality of electromagnetic coils.
a first diode coupled to the battery, the first diode permitting the battery to supply electrical current to the plurality of electromagnetic coils.
The magnetic coupling of claim 8 , the bootstrap circuit further comprising: a current source coupled to the second annular array, the current source configured to transform rotation of the second annular array into electrical current; and a second diode coupled to the current source, the second diode permitting the current source to supply electrical current to the plurality of electromagnetic coils.
a current source coupled to the second annular array, the current source configured to transform rotation of the second annular array into electrical current; and
a second diode coupled to the current source, the second diode permitting the current source to supply electrical current to the plurality of electromagnetic coils.
A drilling system comprising: a drill string; a magnetic coupling located within the drill string, the magnetic coupling including: a first annular array of magnetic sections; a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array; a barrier disposed between the first annular array and the second annular array, the barrier having an erosion-resistant layer; a motor coupled to the first annular array; and a load coupled to the second annular array.
a magnetic coupling located within the drill string, the magnetic coupling including: a first annular array of magnetic sections; a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array; a barrier disposed between the first annular array and the second annular array, the barrier having an erosion-resistant layer;
a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array;
a barrier disposed between the first annular array and the second annular array, the barrier having an erosion-resistant layer;
a motor coupled to the first annular array; and
a load coupled to the second annular array.
The drilling system of claim 10 , wherein: the first annular array has a first outer diameter; the second annular array has a second outer diameter approximately equal to the first outer diameter; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately parallel to the common axis of rotation.
The drilling system of claim 10 wherein: the first annular array has an inner diameter; the second annular array has an outer diameter smaller than the inner diameter; the second annular array is disposed within the inner diameter of the first annular array; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately perpendicular to the common axis of rotation.
The drilling system of claim 10 , wherein the erosion-resistant layer includes a layer of titanium.
The drilling system of claim 10 , wherein the second annular array comprises a plurality of permanent magnets.
The drilling system of claim 10 , wherein a magnet among the plurality of permanent magnets is a samarium cobalt magnet.
The drilling system of claim 10 , wherein the second annular array comprises a plurality of electromagnetic coils.
The drilling system of claim 16 , further comprising a bootstrap circuit for energizing the plurality of electromagnetic coils, the bootstrap circuit comprising: a battery; and a first diode coupled to the battery, the first diode permitting the battery to supply electrical current to the plurality of electromagnetic coils.
The drilling system of claim 17 , the bootstrap circuit further comprising: a current source coupled to the plurality of electromagnetic coils; and a second diode coupled to the current source, the second diode permitting the current source to supply current to the plurality of electromagnetic coils.
a current source coupled to the plurality of electromagnetic coils; and
a second diode coupled to the current source, the second diode permitting the current source to supply current to the plurality of electromagnetic coils.
The drilling system of claim 10 , wherein the load is a generator.
A method of bootstrapping a magnetic coupling of a downhole tool, comprising: rotating a first annular array of magnetic sections in a magnetic coupling; supplying current from a battery to an electromagnetic coil located within a second annular array of magnetic sections in the magnetic coupling; coupling the first annular array to the second annular array using a magnetic field produced by the electromagnetic coil; transferring rotational motion from the first annular array to the second annular array using the magnetic field; transferring rotational motion from the second annular array to an alternating current (AC) source configured to transform rotational motion into electrical current; and supplying electrical current from the AC source to the electromagnetic coil.
rotating a first annular array of magnetic sections in a magnetic coupling;
supplying current from a battery to an electromagnetic coil located within a second annular array of magnetic sections in the magnetic coupling;
coupling the first annular array to the second annular array using a magnetic field produced by the electromagnetic coil;
transferring rotational motion from the first annular array to the second annular array using the magnetic field;
transferring rotational motion from the second annular array to an alternating current (AC) source configured to transform rotational motion into electrical current; and
supplying electrical current from the AC source to the electromagnetic coil.
The method of claim 20 , wherein the magnetic coupling includes a barrier disposed between the first annular array and the second annular array, the barrier including an erosion-resistant layer.
The method of claim 20 , wherein: the first annular array has a first outer diameter; the second annular array has a second outer diameter approximately equal to the first outer diameter; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately parallel to the axis of rotation.
the magnetic field is oriented approximately parallel to the axis of rotation.
The method of claim 20 , wherein: the first annular array has an inner diameter; the second annular array has an outer diameter smaller than the inner diameter; the second annular array is disposed within the inner diameter of the first annular array; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately perpendicular to the axis of rotation.
the magnetic field is oriented approximately perpendicular to the axis of rotation.
Ref US20190010783A1: Claims:
A variable flow resistance system for use with a subterranean well, the system comprising: a first flow path to receive a fluid; a flow rate sensor to measure a flow rate of the fluid received into the first flow path; and an actuator to control an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.
a first flow path to receive a fluid;
a flow rate sensor to measure a flow rate of the fluid received into the first flow path; and
an actuator to control an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.
The variable flow resistance system of claim 1 , wherein the flow rate sensor measures flow rate fluctuations of the fluid received into the first flow path, the system further comprising: a receiver comprising the flow rate sensor to receive a control signal through the measured flow rate fluctuations of the fluid; wherein the actuator controls the inflow rate of the fluid received into the first flow path based upon the control signal received by the receiver.
a receiver comprising the flow rate sensor to receive a control signal through the measured flow rate fluctuations of the fluid;
wherein the actuator controls the inflow rate of the fluid received into the first flow path based upon the control signal received by the receiver.
The variable flow resistance system of claim 2 , further comprising: a transmitter to transmit the control signal by generating the flow rate fluctuations of the fluid.
a transmitter to transmit the control signal by generating the flow rate fluctuations of the fluid.
The variable flow resistance system of claim 3 , wherein the transmitter is coupled to a choke, a valve, or a pump to generate the flow rate fluctuations of the fluid.
The variable flow resistance system of claim 1 , further comprising a controller configured to control the actuator based upon the measured flow rate of the fluid, wherein the actuator adjusts the inflow rate of the fluid received into the first flow path.
The variable flow resistance system of claim 1 , further comprising a power source to provide power to the variable flow resistance system.
The variable flow resistance system of claim 6 , wherein the power source comprises a power storage device to provide stored power for the variable flow resistance system.
The variable flow resistance system of claim 6 , wherein the power source comprises a power generator to generate power for the variable flow resistance system.
The variable flow resistance system of claim 8 , wherein the power generator comprises a turbine to generate power solely from fluid received into the first flow path.
The variable flow resistance system of claim 8 , wherein the flow rate sensor comprises the power generator such that the power generator measures the flow rate of the fluid received into the first flow path.
The variable flow resistance system of claim 8 , wherein the actuator and the power generator are positioned in series or in parallel within the first flow path with respect to each other.
The variable flow resistance system of claim 1 , wherein the flow rate sensor comprises a flow meter.
The variable flow resistance system of claim 1 , further comprising a tool body and a second flow path configured to send the fluid into an interior or exterior of the tool body.
The variable flow resistance system of claim 1 , further comprising a production tubing string, wherein the first flow path comprises a production orifice for the production tubing string.
The variable flow resistance system of claim 1 , wherein the actuator comprises at least one of a screw assembly, a piezoelectric actuator, a hydraulic cylinder, an electric motor, and a hydraulic pump.
A variable flow resistance system for use with a subterranean well, the system comprising: a first flow path to receive a fluid; a receiver to receive a control signal through flow rate fluctuations of the fluid received into the first flow path; and an actuator to control an inflow rate of the fluid received into the first flow path based upon the control signal received by the receiver.
a receiver to receive a control signal through flow rate fluctuations of the fluid received into the first flow path; and
an actuator to control an inflow rate of the fluid received into the first flow path based upon the control signal received by the receiver.
The variable flow resistance system of claim 16 , wherein the receiver comprises a flow rate sensor to measure the flow rate fluctuations of the fluid received into the first flow path, the system further comprising: a transmitter to transmit the control signal by generating the flow rate fluctuations of the fluid.
The variable flow resistance system of claim 16 , wherein the actuator adjusts the inflow rate of the fluid received into the first flow path to generate second flow rate fluctuations of the fluid, further comprising: a second receiver downstream of the actuator to receive a second control signal through the second flow rate fluctuations of the fluid.
a second receiver downstream of the actuator to receive a second control signal through the second flow rate fluctuations of the fluid.
A method of variably controlling flow resistance in a well, the method comprising: receiving a fluid into a first flow path; measuring a flow rate of the fluid received into the first flow path; and adjusting an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.
receiving a fluid into a first flow path;
measuring a flow rate of the fluid received into the first flow path; and
adjusting an inflow rate of the fluid received into the first flow path based upon the measured flow rate of the fluid.
The method of claim 19 , wherein the adjusting the inflow rate comprises: comparing the measured flow rate of the fluid with a predetermined value; and adjusting the inflow rate of the fluid received into the first flow path based upon the comparison of the measured flow rate of the fluid with the predetermined value.
comparing the measured flow rate of the fluid with a predetermined value; and
adjusting the inflow rate of the fluid received into the first flow path based upon the comparison of the measured flow rate of the fluid with the predetermined value.
The method of claim 19 , wherein the measuring the flow rate comprises measuring flow rate fluctuations of the fluid, and wherein the adjusting the inflow rate comprises: comparing the measured flow rate fluctuations of the fluid with a predetermined pattern for the flow rate fluctuations of the fluid; adjusting the inflow rate of the fluid received into the first flow path based upon the comparison of the measured flow rate fluctuations of the fluid with the predetermined pattern for the flow rate fluctuations of the fluid.
comparing the measured flow rate fluctuations of the fluid with a predetermined pattern for the flow rate fluctuations of the fluid;
adjusting the inflow rate of the fluid received into the first flow path based upon the comparison of the measured flow rate fluctuations of the fluid with the predetermined pattern for the flow rate fluctuations of the fluid.
The method of claim 19 , wherein: the measuring the flow rate comprises receiving a control signal through flow rate fluctuations of the fluid; and the adjusting the inflow rate comprises adjusting the inflow rate of the fluid received into the first flow path based upon the control signal.
the measuring the flow rate comprises receiving a control signal through flow rate fluctuations of the fluid; and
the adjusting the inflow rate comprises adjusting the inflow rate of the fluid received into the first flow path based upon the control signal.
The method of claim 23 , further comprising generating the flow rate fluctuations of the fluid to transmit the control signal.
The method of claim 19 , further comprising generating power from the fluid received into the first flow path.
Ref US20180320482: Claims:
What is claimed is: 1. A magnetic coupling of a downhole tool comprising: a first annular array of magnetic sections; a second annular array of magnetic sections coupled to the first annular array by a magnetic field that transfers rotational motion from the first annular array to the second annular array; and a barrier disposed between the first annular array and the second annular array, the barrier including an erosion-resistant layer. 2. The magnetic coupling of claim 1, wherein: the first annular array has a first outer diameter; the second annular array has a second outer diameter approximately equal to the first outer diameter; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately parallel to the common axis of rotation. 3. The magnetic coupling of claim 1, wherein: the first annular array has an inner diameter; the second annular array has an outer diameter smaller than the inner diameter; the second annular array is disposed within the inner diameter of the first annular array; the first annular array and the second annular array are configured to rotate about a common axis of rotation; and the magnetic field is oriented approximately perpendicular to the common axis of rotation. 4. The magnetic coupling of claim 1, wherein the erosion-resistant layer includes a layer of titanium. 5. The magnetic coupling of claim 1, wherein the second annular array comprises a plurality of permanent magnets. 6. The magnetic co
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