Untitled record

full description

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This disclosure generally relates to equipment used and operations performed in connection with a subterranean well, and in the example shown below, the disclosure provides more specifically the injection of a fluid into one or more selected areas of a well, and provides the operation of the well tools with sensing

5 magnetic field sensing. In some cases it may be useful to have one or more borehole tools operated within the borehole individually or at least selectively. There is a constant need for improvements in the field that may be useful in processes such as selective injection of fluid into formation zones, selective production from several zones, operation of many types of well tools, and so on.

The present disclosure generally relates to equipment in use and operations to be performed in connection with an underground well

10 Surface and, in the example described below, provides more specifically for the injection of a fluid into one or more selected areas in a well, and provides for the operation of magnetic field sensing of the borehole tools. It can be useful in some circumstances to rotate, either singly or at least selectively, one or more borehole tools into a well.

US Patent 8839871 relates to equipment used and operations to be performed in relation to a subsurface well 15 and provides, in an example described below, more specifically on well tools operable by thermal expansion generated by reactants.

US Patent 2012241143 relates to equipment used and operations to be performed in connection with a subsurface well providing, in an embodiment described below, more specifically to a well tool utilizing a valve actuated by low electrical power input.

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US Patent 2007204995 relates to a system for remotely operating slide valves of a fracing system for the production of fluids, such as oil or natural gas.

Sliding valves can be opened and closed selectively according to the preference of a well operator, and the said invention provides a tool for remote operation of sliding valves for a fracturing system.

5 International Patent 2006051250 relates to the remote operation of a tool in the bottom of a well. In particular, the invention uses RFID technology to transmit data and operating instructions to/from stationary readers that are coupled to a well-bottom device such as a valve or sliding sleeve.

US Patent 2007235199 relates to wellbed performance. More specifically, the present invention relates to a device and methods for remote operation of a downhole tool. More specifically, the present invention 10 relates to a device and methods for operating a downhole tool based on the observation of a wellbed condition.

US Patent 2011174484 generally relates to equipment used and processes to be performed in relation to a subsurface well and provides, in the example described below, more specifically wells operable by thermal expansion of reactants.

EP 2484862 relates to downhole flow or slide bushings that straighten a series of 15 tubes down a wellbore for a fracturing or similar operation. The tools have an insert and bushing that can move in the tool bore. Multiple plugs, such as CRT, breaker blades, or the like, straighten the tubing string down to selectively isolate different areas of a formation for treatment.

There is a constant need for improvements in the art that can be useful in processes such as injection of fluid into formation zones selectively, selective production of multiple zones, operation of different types of well tools, 20 etc.

General description of the invention

Here a well bore service tool comprising a housing comprising one or more ports is disclosed and generally defining a flow lane, an actuator placed inside the housing, a magnetic system

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MSS (signature system) comprising a magnetic sensor in signal contact with an electronic circuit placed inside the housing and coupled to the actuator, and a bushing that is slippery inside the housing and transmitted from one position to a second position, wherein, the bushing is allowed to travel from the first position to the second position As soon as the trigger is turned on, the trigger is triggered as soon as a predetermined amount of predefined magnetic signature 5 is realized via

.MSS

Also disclosed herein is a wellbore servicing system comprising a string of tubing placed within a wellbore, and a first well tool included in the tubing string and comprising a first housing comprising one or more of the first ports and generally specifying a first flow lane, first actuator placed within the first housing , System

10 First Magnetic Indication (MSS) comprising a first magnetic sensor and a first electronic circuit placed inside the housing and coupled to the actuator, and a first bushing that is slippery inside the first housing and moves from one position to a second position, whereby, the first bushing moves from the first position to the second position upon turning on The first trigger, where the first trigger is triggered when a predetermined amount of preset magnetic pulses are realized via the first MSS.

15th Also disclosed is a wellbore servicing method that includes the placement of a well tool chain of tubes incorporating a Magnetic Slotting System (MSS), in which the well tool is configured to either allow a fluid contact path between the outside of the well tool and the well tool axial flow hole or to block the path of Fluid connection between the outer part of the borehole and an axial flow bore of the borehole, the insertion of a magnetic device into the axial flowbore of the borehole, where the medium sends

20 Magnetism Magnetic Signal, Well Tool Operation When a predetermined magnetic significance is perceived via MSS, the well tool is reconfigured to alter the path of fluid contact between the outside of the well tool and the axial flow bore of the well tool.

Brief explanation of the docking Matt

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To fully accommodate and characterize the present disclosure, the following brief description will now be indicated, presented with reference to the accompanying drawings and detailed description:

Figure 1 is an illustrative partial cross-sectional projection of a well system that can exemplify the principles of this disclosure;

5 Figure 2 is an illustrative partial cross-sectional view of an injection valve that can be used in a well system and/or method, which embodies the principles of this disclosure;

Figures 3-6 are illustrative cross-sectional projections of another example of a syringe valve, in their extension, actuation and reverse flow configurations, respectively;

Figures 7 and 8 are illustrative top and side projections, respectively, of a magnetic medium that can be

10 use with injection valve;

Figure 9 is an illustrative cross-sectional projection of another example of an injection valve;

Figures 10a and b are illustrative cross-sectional projections of successive axial sections for another example

on the injection valve, in a closed body;

Figure 11 is an illustrative enlarged cross-sectional projection of a valve device that can be used in

15th injection valve;

Figure 12 for an illustrative enlarged cross sectional of a magnetic semantic system that can be used in an injection valve;

Figure 13 is an illustrative cross-sectional projection of another example of an injection valve;

Figure 14 is an illustrative enlarged cross-sectional projection of another example of the sensor

20 magnetic in the injection valve shown in Figure 13;

Figures 15a and b are illustrative cross-sectional projections of another example of an injection valve, in

first body; And

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Figures 16a and b are illustrative cross-sectional projections of another example of an injection valve, in second form.

Detailed description:

In the following drawings and description, similar parts will be typically indicated over a period of time

<p>5 The specification and drawings have the same reference numbers, respectively. In addition, similar reference numbers may refer to similar components in different embodiments disclosed herein. The scale is not necessarily applied to reality. Certain features of the invention may be shown exaggeratedly or somewhat schematically, and some details of traditional elements may not be presented for clarity and accuracy. The present invention is subject to various embodiments. Specific embodiments are described</p>

<p>10 in detail and are shown in the drawings, recognizing that the present disclosure is not intended to limit the invention to the embodiments described and described herein. It should be fully recognized that the various information contained in the embodiments discussed here may be embodied separately or in any suitable combination to achieve the desired results.</p>

Unless otherwise specified, the use of the terms 'connect', 'interconnect', 'associate', 'link', or

<p>15th Any other similar term describing interaction between elements limits interaction to direct interaction between elements and can also include indirect interaction between the described elements.</p>

Unless otherwise specified, the use of the terms “above,” “upper,” “up,” “top of the well,” “topside,” or other similar terms shall be construed as generally of the formation toward the surface or toward the surface of a body of water; Likewise, the use of the terms 'under', 'below', 'downwards' must be construed.

<p>20 "downhole", "bottom side", or other similar terms being generally in a formation far from the surface or away from the surface of a body of water, regardless of the direction of the wellbore. The use of any one or more of the foregoing terms should not be construed as referring to positions exactly along a ground axis.</p>

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Unless otherwise specified, the use of 'giver formation' should be interpreted to include both exposed subsurface areas and subterranean areas covered by water such as the ocean or fresh water.

In an embodiment as shown in Figure 1, a 5 10 wellbore servicing system is disclosed for use with a well and an associated method. For example, in

One embodiment, a 12 tubular string comprising several 16 injection valvesA-E and a set of 18A-E connected gaskets within it is placed in a wellbore

.14 ​​wellbore

In one embodiment, the 12 series of tubing may be of a type known to those skilled in the 10 artifacts as casing, liner, tube, production tubing string, run tubing string, drilling tubing string, completion tubing string, side tubing string, or any type may be used of piping chains as is known to those of ordinary skill in the art immediately upon review of this disclosure. In one embodiment, the 18 packersa-e can be configured to seal a 20 annulus formed in the diameter direction between the 12 tube chain and the borehole 14. In this embodiment, . can be initialized

15th Gaskets 18a-e for sealing coupling with an open borehole or unjacketed 14. In

An alternative embodiment is, for example, if the wellbore is casing or lining, then jacketed bore-type gaskets may be used instead. For example, in one embodiment, inflatable, inflatable, stretchable and/or other types of packing may be used, as required by the well conditions. In an alternative embodiment, no gaskets can be used, for example, the tube chain can be extended

20 12 In contact with the borehole 14, the 12 series of pipes can be cemented into the borehole,

And so on.

In the embodiment in Figure 1, the injection valves 16A-E can be configured to selectively allow fluid communication between an inner portion of the tubing chain 12 (eg, a flow hole) and each section of the insulated annular space 20 between two gaskets 18A-E. Embodiment, be each section

25 from the annular space 20 in fluid contact with one or more regions of the earth . formation

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formation zones 22a–d. In an alternative embodiment, if gaskets 18a-e are not used, the injection valves 16a-e can be placed in fluid contact with individual areas 22a-d (eg, with holes, for example). In one embodiment, areas 22a can be -d sections of the same configuration 22 or sections of different configurations.For example, in an embodiment, 5 each region 22a-d may be associated with one or more 16a-e injection valves.

In the embodiment in Figure 1, two injection valves 16b,c are attached to the insulated annular space section 20 between gaskets 18b,c, and this section of the annular space is in contact with the enclosed area 22b. It will be realized that any number of injection valves can be connected to a zone (for example, zones 22a-d).

10 In one embodiment, the initiation of faults 26 may be useful for many locations in a region (eg, in hermetically sealed laminate formations, etc.), in which cases multiple injection valves can provide selective conduction (eg, injecting) fluid 24 at several trigger points (eg, initiation of fracturing) along wellbore 14. For example, as shown in Figure 1, valve 16c was opened and fluid 24 was injected into zone 22b, resulting in

15th to the 26 fractures. Additionally, in one embodiment, the other valves 16a, b, d, and e are closed while fluid 24 flows out of valve 16c and into zone 22b helping to direct all fluid flow 24 toward the fault formation 26, enhancing control over the process at That specific site.

In an alternative embodiment, many valves 16a-e can be opened while fluid 24 flows in a region of 20 ground formations 22. In a well system 10, for example, both valves 16b and c can be opened

Fluid 24 flows in region 22b, helping to form faults at several fault starting sites corresponding to open valves. In an embodiment, one or more valves 16a-e may be configured to operate at different times. For example, in one embodiment, one group (eg valves 16b, c) may be opened at one time period and another group (eg valves 16a 25) may be opened in another time period. In an alternative embodiment, one or more groups may be opened

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Valves 16A-E are highly synchronized. In addition, in an embodiment, only one set of valves 16a-e may be preferred to open at a point in time, such that the fluid flow 24 can be focused on a specific area, and thus the flow within that area can be individually controlled.

Note that the borehole servicing system 10 and method are described here and depicted in the drawings

5 As an example only of the wide range of possible systems and methods that incorporate the principles of this disclosure. It should therefore be recognized that these principles are in no way limited to the details of the wellbore servicing system 10 or the attached method, or to the details of any components thereof (for example, piping 12, wellbore 14, valves 16a-e, shims 18a- e, and so on. For example, it is not necessary for a wellbore to be 14-floor as depicted in Figure 1, or a wellbore to be unsealed, or 10 to have five of each of the valves 16A-E and the gaskets 18A-E, or that there are four Areas 22a-d, or faults 26 to be formed in Zones, or fluid 24 to be injected, or zones to be treated in any specific order, and so on. In one embodiment, fluid 24 may be of any type of fluid injected into a ground formation, for example, for catalysis, compatibility, acidification, fracturing, water overflow, steam overflow, curing, gravel filling, cementing, or any other purpose

15th Another as those of ordinary skill in the field will realize once this disclosure is reviewed. Thus, it will be recognized that the principles of this disclosure apply to many different types of well systems and processes.

In an additional or alternative embodiment, the principles of this disclosure may be applied in cases where the fluid is not only injected, but is also (or only) produced from configuration 22. In this embodiment, fluid 24 (eg oil, gas, water, and so on) can be produced from Genesis 22. Thus, well tools can benefit other than

20 Injection valves from the principles described here.

Thus, it must be recognized that the field of detection is not limited to any specific position or arrangement of the many components of the injection valve 16. Indeed, the principles of this disclosure apply to a wide range of different bodies, and to a wide range of different types of well tools (for example, packers, circulation valves, tester valves,

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perforating equipment, completion equipment, sand screens, and so on.

With reference to Figures 2-6, 9, 10a-10b, 15a-15b, and 16a-16b, in one embodiment, the injection valve 16 comprises a housing 30, a 50 actuator, a 32 sleeve, and a system

<p>5 Magnetic significance 100 MSS. While embodiments of the injection valve 16 have been disclosed for Figures 6-2, 9, 10a-10b, 15a-15b, and 16a-16b, those of ordinary skill in the art will, upon seeing this disclosure, recognize the appropriate alternate configurations. Thus, while embodiments of the injection valve 16 may be disclosed with reference to a particular configuration (for example, as will be disclosed for one or more of the shapes here), this disclosure should not be construed as being limited to such embodiments.</p>

<p>10 With reference to Figs 2, 3, 9, 10a-10b, and 15a-15b, one embodiment of the injection valve 16 is illustrated in a first form. In one embodiment, when the injection valve 16 is located in a first body, also referred to as an extension pattern/body or mounting style/body, the injection valve 16 may be configured to not allow a fluid contact path between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 ( (e.g., borehole). In one embodiment, as will be disclosed here,</p>

<p>15th The injection valve 16 can be configured to switch from the first shape to the second configuration once it has gone through a predetermined amount of predefined magnetic signature (for example, at least one of one or more predefined magnetic signatures that are useful for initialization/programming of a valve). 16 to select).</p>

Referring to Figures 4-6, and 16a-16b, the injection valve 16 is illustrated in a second figure. in one

<p>20 embodiments, when the injection valve 16 is located in the second body, the injection valve 16 may be configured to allow a fluid communication path between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 (for example, a wellbore). In one embodiment, the valve can remain 16 injections into the second body immediately after the transition to the second body.</p>

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In one embodiment, housing 30 may be distinguished by a generally tubular body. Housing 30 may also be distinguished by generally defining a longitudinal flush hole (eg, flush lane 36). In addition, in an embodiment, housing 30 may comprise one or more cavities or chambers formed by one or more of the The inner and/or outer parts of housing 30, as will be disclosed here 5. In one embodiment, housing 30 may be configured to connect to and/or to be included in a tubing chain, such as tubular 12. For example, housing 30 may include a suitable means of connection to tubing 12. For example, in an embodiment, housing 30 may have internally and/or externally threaded surfaces as may be suitably used to fabricate a threaded connection to tubular member 12. In an additional or alternative embodiment, the housing 30 10 may also include a connection interface suitable for making a connection with the downhole portion of the tubular organic 12.

Alternatively, an injection valve such as the injection valve 16 may be embedded within the tube-like tube 12 by any suitable connection, such as one or more quick connector type connections. Appropriate connections to the tubular member will be known to those of ordinary skill in the art upon review of this disclosure.

<p>15th In one embodiment, the housing 30 can be configured to allow one or more slewing to be placed in it, as will be disclosed here. In addition, in an embodiment, the housing 30 may also comprise a set of ports configured to provide a path for fluid communication between the exterior of the housing 30 and the flow lane 36 of the housing 30, when configured with this disclosure, as disclosed herein. For example, in the embodiment in Figure 2, the injection valve 16 includes one</p>

<p>20 one or more ports or openings (eg, 28 openings) placed around housing 30 and providing a path for fluid communication between flow lane 36 and the exterior of housing 30, as will be disclosed here.</p>

In one embodiment, the sleeve 32 may generally have a cylindrical or tubular structure. In one embodiment, the sleeve 32 can be slidly attached to the inner bore surface

<p>25 Housing 30 in a highly watertight or highly watertight manner. In addition,</p>

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In one embodiment, the sleeve 32 and/or housing 30 may also include one or more suitable seals (eg, O-ring, T-seal, gasket, etc.) The outer cylinder of the bushing 32 and the inner housing surface, eg, for the purpose of preventing and/or restricting the movement of the fluid through this interface.

5 With reference to the embodiments given in Figs. 2-6, 9, 10a, 15a and 16a, the sleeve 32 can be sliding sliding within the housing 30. For example, the sleeve 32 can be sliding sliding between several longitudinal positions with respect to housing 30. In addition, The relative position of the bushing 32 can determine whether one or more ports (eg, slots 28) of the housing 30 are capable of providing a path for fluid communication.

10 With reference to the embodiments in Figs. 2, 3, 9, 10a and 15a, when the injection valve 16 is configured in the first configuration, the sleeve 32 is located in the first position with respect to housing 30. In this embodiment, the sleeve 32 can be editably coupled to the housing 30, on the for example, via a shear stud, snap ring, and so on, for example, such that the sleeve 32 is fixed to housing 30. For example, in the embodiment in Figure 2, the sleeve 32 is editably coupled to housing 30 via

15th Shear stud 34. In an additional or alternative embodiment, the sleeve 32 may remain in the first position across the y

Applying fluid pressure (eg, a supporting fluid contained in the chamber within the housing 30) on one or more of the bushing portions 32, as will be disclosed here.

With reference to embodiments in Figures 4-6 and 16a, when the injection valve 16 is configured in the second configuration, the sleeve 32 is located in a second position with respect to housing 30. In one embodiment, when there is

20 The bushing 32 is in the second position, the injection valve 16 can be configured to provide a two-way fluid connection between the outside of the injection valve 16 and the flow passage 36 of the injection valve 16, for example, through orifices 28. In one embodiment, when the bushing 32 is in the second position, the sleeve 32 may The sleeve 32 is not associated with the housing 30. In an alternative embodiment, when the sleeve 32 is in the second position, the sleeve 32 may be held in the second position (eg, via a snap ring).

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In one embodiment, the bushing 32 can be configured to selectively move downwards (eg, down a well). For example, in embodiments in Figs 2-6, 9, 10a, 15a and 16a, the injection valve 16 can be configured to move from the body the first to the second setting once a predetermined amount of preset magnetic pulse indices are received.For example, a valve can be configured

<p>5 injection 16 so that connecting a predetermined number of magnetic devices, each of which transmits a predetermined magnetic pulse function (for example, a magnetic pulse function defined by a specific injection valve 16) within the flow lane 36 causes the actuator 50 to operate, as will be realized here .</p>

In one embodiment, the sleeve 32 may also comprise a mandrel 54 comprising a 56 retractable seat and a 52 piston. For example, in the given embodiment

<p>10 In Figure 2, the retractable seat 56 can have elastic collars 58 (eg, collet fingers) and can be configured so that the elastic collars 58 can fit inside an annular cavity 60 for the housing 30. Additionally, in one embodiment, the elastic collars 58 can be configured Retractable seat 56 for sealing engagement and retention of a sealing member (eg, magnetic device, ball, arrow, stopper, and so on). For example, in one embodiment,</p>

<p>15th After the injection valve 16 has passed the predetermined number of predetermined magnetic pulse indices (for example, once the 54 mandrel has been moved), the elastic collars 58 can be configured to deflect inward in the direction of the diameter (for example, across an inclined surface 62 of the 60 bore) and from The retractable seat 56 is then moved to the sealing position.In one embodiment, the retractable seat 56 may be configured to allow engagement of the sealing member (for example,</p>

<p>20 a magnetic device, ball, arrow, stopper, and so on) by applying pressure to the sealing member and then applying a force to the sealing member and/or the mandrel 54, for example, to apply a force to the bushing 32, for example, in the direction down the well, In this embodiment, a force sufficient in the direction down the well may be sufficient to shear one or more shear pins (for example, 34 shear pins) and/or the sleeve 32 to travel from the first position</p>

25 to the second position relative to the housing 30.

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In the embodiment in Figures 3-6, the retractable seat 56 may be in the form of an extendable ring which can be configured to extend inward in the tow direction to its sealing position by shifting the sleeve 32 downwards, as shown in Figure 4. In addition Furthermore, in one embodiment, the retractable seat 56 can be configured to move to a retractable position by shedding

5 A force on the retractable seat 56, for example, is via an upward force applied by a sealing member (for example, a 38 magnetic device). For example, in the embodiment in Figure 5, the injection valve 16 can be configured so that when the The magnetic device 38 from the flow path 36 (eg, via backflow or up) of the fluid through the flow path 36), the magnetic device 38 can engage with the retractable seat

<p>10 56. In this embodiment as shown in Figure 6, the injection valve 16 can also be configured so that</p>

The engagement between the magnetic device 38 and the retractable seat 56 causes an upward force to be applied to the retaining sleeve 72. For example, in this embodiment, the upward force would be sufficient to overcome the downward tilt force (eg, via a spring 70 applied to the retaining sleeve 72), allowing the Retractable Seat 56 to expand outward in the direction of the tow, and then move the seat

<p>15th Retractable 56 to the retractable position. In this embodiment, when the retractable seat 56 is in the retracted position, the injection valve 16 can be configured to allow the sealing member 38 to be moved upward toward the ground surface.</p>

In one embodiment, the actuator 50 may comprise a 46 piercing member and/or a 44 valve device. In one embodiment, the perforating member 46 . can be operated

<p>20 By any means, such as hydraulic, mechanical, explosive, chemical actuator, or any other type of actuator as those of ordinary skill in the art will realize immediately upon review of this disclosure. Other types of valve media 44 (such as those described in US Patent Application No. 688,058/12 and/or US Patent Application No. 353,664/12, for which the full disclosure contents are incorporated herein by reference), may be used as corresponds to the scope of this disclosure.</p>

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In one embodiment as shown in Figure 2, the injection valve 16 can be configured so that when the valve means 44 is opened, the piston 52 on the mandrel 54 becomes unbalanced (for example, via a pressure differential created across the piston 52) and the piston 52 is displaced in the direction down the well. In this embodiment, the pressure difference produced across the piston 52 (for example, by applying fluid pressure 5 from the flow pass 36) may be sufficient to move the sleeve 32 from the first position (for example, a closed position) to the second position (for example , open position) and/or cut one or more shear pins (for example, shear bolts 34).

In the embodiment shown in Figure 9, the actuator 50 may comprise two or more valve media 44. In this embodiment, the injection valve 16 can be configured so that when the first 10 valve media is operating 44, sufficient support fluid 63 is drained (eg e.g. out-chamber, allowed-in-chamber, permitted from first chamber to second chamber, or a combination thereof), allowing the sleeve 32 to travel to the second position. Additionally, in one embodiment, the injection valve 16 can also be configured so that when a second valve 44 is actuated, an additional volume of the supporting fluid 63 is drained, allowing the bushing to be displaced 32 (for example, from the second 15 position). , in the embodiment in Fig. 9, the bushing offset can perform 32

Also, the bushing 32 is moved out of the second position, impeding fluid communication between the inflow passage 36 of the injection valve 16 and the outboard of the injection valve 16 through the orifices 28.

In an additional or alternative embodiment, the actuator 50 can be configured to operate multiple injection valves (eg, two or more 16A-E injection valves). For example, in one embodiment, the actuator 50 can be configured to operate multiple RAPIDFRAC (TM) ) Sleeve marketed by

Halliburton Energy Services, Inc., in this embodiment. of Houston, Texas USA

Actuator 50 can be configured to initiate a hydraulic fluid calibration in RAPIDFRAC TM (Sleeves) in response to a predetermined number of predefined magnetic pulse signatures, for example, so that a set of 25 injection valves opens after a specified period of time.

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In embodiments in Figures 3-6, the injection valve 16 may also comprise one or more chambers (eg, chamber 64 and chamber 66). In this embodiment, one or more chambers may selectively retain a fluid Supportive (eg, incompressible fluid), for example, for the purpose of holding the sleeve 32 in the first position. For example, in embodiment

5 shown in Figure 11, the injection valve 16 can be configured so that chamber 66 initially contains air or inert gas at about or near atmospheric pressure and chamber 64 contains a support fluid 63. Additionally, in one embodiment, the chambers (on for example, chamber 64 and chamber 66) to initially isolate them from each other, for example, via a pressure septum 48, as shown in Figure 11. In one embodiment, the pressure septum 48 can be configured

10 to open and/or actuate (for example, smashed, broken, punctured, or rendered lose its structural integrity) in response to the passage of the injection valve 16 by a predetermined number of predetermined magnetic impulses, as will be disclosed here. For example, in an embodiment , the actuator 50 can include a perforating member (for example, perforating member 46) and can be configured to perforate the pressure diaphragm 48 in response to the passage of the injection valve 16 by the predetermined number of magnetic pulses

15th predefined, allowing a fluid communication path between chambers 64 and 66.

In the embodiment given in Figs 10a-10b, the injection valve 16 may also comprise a second sleeve 78, such that the second sleeve 78 is configured to isolate one or more chambers 66 from a well fluid in the annulus 20 annulus.

In one embodiment, the injection valve 16, as disclosed before, can be configured to allow exit

20 fluid selectively from it, for example, in response to sensing and/or passing through a predetermined number of predetermined magnetic signals, namely, a predetermined number of predetermined magnetic impulses as will be disclosed here. In one embodiment, the injection valve 16 can be configured to operate immediately upon passing through a predetermined number of predetermined magnetic pulse indices, for example, as will be detected via 100 MSS, providing a path for communication

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Fluid to/from the inflow passage 36 of the injection valve 16 through the ports (eg, orifices 28).

As used herein, the term “magnetic impulse function” refers to an identifiable and recognizable function of one or more magnetic features and/or properties (for example, with respect to time), 5 for example, as it is passed through at one or more of the Locations within the flow lane (such as the flow corridor 36) of a wellbore service system and/or a well tool (such as a wellbore service system 10 and/or an injection valve 16) to be detected by or a component of the well tool (for example, by

100 MSS). As will be disclosed here, the magnetic impulse can be effective in inducing a response from the well tool, for example to “energize” one or more components of the MSS 10 100, to trigger (and/or cause) the actuator 50 As will be revealed here, to increase the counter,

To reduce, counter, or combinations thereof. In one embodiment, the magnetic impulse can be distinguished as having any suitable type and/or form for variations of the magnetic field, eg, any suitable waveform or combination of waveforms, having suitable properties or combinations of suitable properties.

<p>15th In one embodiment, the magnetic pulse sign may be an analog signal. For example, in one embodiment, the magnetic pulse sign may comprise a waveform (eg, sinusoidal wave, square wave, triangle wave, saw tooth wave, pulse-width implied wave width modulated wave, and so on(</p>

20

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Has a predetermined frequency, for example, a sine waveform having a frequency of about 12 hertz (Hz), alternately, about 20 Hz, alternately, about 75 Hz, alternately, about 100 Hz, alternately , about 1 kilohertz (kHz), alternatively, about 10 yi

kHz, alternately, about 30 kHz, alternately, about 40 kHz, alternately, about 50 kHz, alternately, about 60 kHz, alternately, any other suitable frequency as to be given Shown by a normal skilled in the field immediately

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Land this discovery. In an alternative embodiment, the magnetic impulse sign can have a range of waveforms. For example, in one embodiment, the magnetic pulse may have a first waveform at a first frequency and a second waveform at a second frequency.

In an alternative embodiment, the magnetic pulse could be a digital signal, for example, a current

<p>5 bits, pulse string, magnetic stripe, and so on. In this embodiment, the magnetic impulse sign may be distinguished as comprising any suitable type and/or format for modulation, bit rate, encoding, encoder, protocol, any other suitable digital signal feature as would be perceived by ordinary people of skill in the art upon review of this detection, or a combination thereof. For example, in one embodiment, the magnetic pulse function can be configured to be modulated and/or encoded by frequency modulation.</p>

<p>10 FM (modulation), modulated frequency modulation embedding, run length-limited coding (RLL), or any other suitable modulation and/or coding technique as will be realized by ordinary skilled in the art immediately upon use In addition, in one embodiment, the magnetic impulse can be distinguished as comprising a digitally encoded message or data packet.</p>

<p>15th The magnetic pulse sign has a data packet that includes an address header portion and a data portion. Additionally, in this embodiment, the header head part can be uniquely assigned to one or more well tools (for example, injection valves 16) and/or the data part can include a single well tool instruction (for example, an operating signal (.</p>

In one embodiment, the magnetic impulse function may be produced by or created within a well tool or

<p>20 Another device placed within a flow lane, for example, the magnetic impulse indication can be produced by a magnetic device 38 (eg, ball, arrow, shot, stopper, and so on) which can be connected through the flow lane 36 of a syringe valve 16. For example, In the embodiments of Figures 7-8, the magnetic medium 38 may be circular 76 and may have one or more recesses 74. In the embodiments of Figures 15a-15b and 16a-16b, the magnetic medium may be</p>

25 Configuration of the magnetic medium 38 (eg a ball) to be delivered/transmitted through the flow path

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of the well tool and/or flowway 36 of the injection valve 16. Also, the magnetic device 38 is configured to release or radiate a magnetic field (may include magnetic impulse) to allow the magnetic field to interact with the injection valve 16 (for example, MSS 100 for one or more injection valves, such as injection valve 16A-E), as will be disclosed 5 here. In an additional or alternative embodiment, the magnetic pulse may be produced by one or more devices coupled to a tubular member, such as a string of tubes running and/or suspended in the wellbore via a drill cable.

In one embodiment, the magnetic medium 38 may generally comprise a permanent magnet, a direct current magnet, an electromagnet, or any combinations thereof. In an embodiment 10, the magnetic medium 38 may be made, or a part thereof, of a magnetic material ferrous (for example, a material subject to a magnetic field), such as iron, cobalt, nickel, steel, earth metal alloys,

ceramic magnets, nickel-iron alloys, rare-earth magnets (eg 15 Neodymium magnet, samarium-cobalt magnet),

Other known materials such as Hy-Mu-80 ®, Hipernon ®, Mumetal ®, Co-netic AA, Permalloy ® (which can all contain about 80% nickel, 15% iron iron, the rest being copper, molybdenum , chromium), any other suitable material as those of ordinary skill in the art will realize upon review of this disclosure, or 20 combinations thereof. For example, in one embodiment, the magnetic medium 38 may comprise a magnet, for example, a ceramic magnet or a rare earth magnet (for example, a neodymium magnet or a samarium-cobalt magnet). In this embodiment, the magnetic medium may comprise 38 on a surface having magnetic north pole polarity and a surface having magnetic south pole polarity and can be configured to produce a magnetic field, for example, the significance of magnetic pulse 25.

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In an additional or alternative embodiment, the magnetic medium 38 may also comprise an electromagnet comprising an electronic circuit comprising a current or a power source (for example, current from one or more batteries, a power production device, a wire line, Thus), an insulated electrical coil (for example, a copper wire

<p>5 insulated copper wire by a set of windings placed side by side), a ferromagnetic core (such as an iron rod), and/or any other suitable electrical or magnetic components as will be recognized by ordinary skillful in the fields upon review In one embodiment, the electromagnet may be configured to provide adjustable and/or variable magnetic polarity.</p>

<p>10 In one embodiment, the magnetic device 38 (comprising magnet and/or electromagnet) may be configured to engage with one or more injection valves 16 and/or to disengage with one or more injection valves 16.</p>

Without being bound by theory, according to Ampere's circular law, an isolated electric coil can temporarily produce a magnetic field while an electric current flows through it and can stop the magnetic field emission

<p>15th when the current stops. In addition, applying direct current (DC) to the electric coil can create a constant polarity magnetic field and reverse the direction of the current flow to reverse the magnetic polarity of the magnetic field. In one embodiment, the magnetic medium 38 may comprise an electrically connected insulated coil in an electronic circuit (for example, via a current source), resulting in the formation of an electromagnet or a DC magnet. In an embodiment</p>

<p>20 Further, the electronic circuit can be configured to provide alternating and/or varying current, for example, for the purpose of providing an alternating and/or varying magnetic field (for example, the magnetic field varies with current flowing through the electric coil). In this embodiment, the circuit can be configured to provide alternating and/or varying current. electronics to generate a pulsed magnetic signal (for example, by flowing an electric current through an electric coil), for example, a magnetic signal repeated over a period of time. Also, in an embodiment, it can be</p>

<p>25 The electronic circuit is also configured to generate a magnetic signal that has a built-in digital signal, a packet</p>

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data, an analog waveform (for example, a sinusoidal waveform), and/or any appropriate magnetic impulse function as those of ordinary skill in the field will perceive once this detection is reviewed. In addition, in this embodiment, a metal core may be placed inside the coil electromagnet, which increases the magnetic flux (for example, magnetic field) of the electromagnet.

5 In one embodiment, the MSS 100 generally comprises a magnetic sensor 40 and an electronic circuit 42, as shown in Figures 15b and 16b. In one embodiment, the magnetic sensor 40 and/or the electronic circuit 42 may be wholly or partly incorporated into the injection valve 16 by any suitable means as will be recognized by those of ordinary skill in the art upon review of this disclosure. For example, in one embodiment, the magnetic sensor 40 and/or 10 electronic circuit 42 may be housed, individually or separately, within a cavity in the housing of the 30 injection valve 16.

Additionally, in this embodiment, one or more of the 100 MSS components (eg, magnetic sensor 40 and/or electronic circuit 42) may be positioned such that there is no line-of-sight contact (eg, line-of-sight propagation) with The flow path 36 of the injection valve 16. For example, in embodiments in Figures 15b and 16b, the MSS 15 100 is positioned so that diffusion into the line of sight is prevented by a baffle 104 (for example, a

conductive, reflective material, layer of metallic material, and so on). In an alternative embodiment, as would be perceived by those of ordinary skill in the art, at least part of the magnetic sensor 40 and/or electronic circuit 42, for example, may be located outside the injection valve housing 30 16. It should be understood that the scope of this detection is not limited to any specific body, specific location, or number of magnetic sensors 20 magnetic 40 and/or electronic circuits 42. For example, although embodiments in Figures 15b and 16b show that a 100 MSS comprises many distributed components (for example, one magnetic sensor 40 and one electronic circuit 42), in an alternative embodiment, an identical MSS could include components identical in a single, unitary component; alternatively, the functions performed by these components (for example, a magnetic sensor) can be distributed

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40 and electronic circuit 42) across any suitable number and/or configuration of similar components, as those of ordinary skill in the art will realize upon review of this disclosure.

In one embodiment, when the magnetic sensor 40 and electronic circuit 42 comprise distributed components, the electronic circuit 42 can be configured to communicate with the magnetic sensor 40 and/or

5 Driver 50 via an appropriate signal duct, for example, via one or more appropriate wires. Examples of suitable wiring include, but are not limited to, insulated steel core copper wire, insulated stranded copper wire, unsheathed twisted pair, optical fiber cables, coaxial cables, and any other suitable wire as will be recognized by ordinary skilled in the art upon review of this disclosure. , or combinations thereof. In addition, in an embodiment, . can be configured

<p>10 Electronic circuit 42 To communicate with the magnetic sensor 40 magnetic sensor and/or actuator 50 via an appropriate signal transmission protocol. Examples of an appropriate signaling protocol include, but are not limited to, an encoded digital signal.</p>

In one embodiment, the magnetic sensor 40 may have any suitable type and/or make of a device capable of detecting a magnetic field (eg, magnetic pulse function) in close proximity

<p>15th Magnetic sensor is preset 40 (eg, inside the inflow passage 36 of the injection valve 16). Appropriate magneto sensors can include, but are not limited to, a magneto-resistive sensor, a giant magneto-resistive GMR (giant magneto-resistive GMR) sensor resistive), MEMS sensor, Hall effect sensor, inductive coil sensor, superconducting quantum interference sensor</p>

<p>20 SQUID (microelectromechanical systems), or similar. In an additional embodiment, the magnetic sensor 40 can be configured to combine with one or more permanent magnets, for example, to create a magnetic field that can be distributed by a magnetic medium (for example, the magnetic medium 38).</p>

In one embodiment, the magnetic sensor can be configured 40 etc. Mark appropriate to the . signal

<p>25 Detected magnetism, such as the magnetic pulse function. For example, in one</p>

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embodiments, the magnetic sensor 40 can be configured to convert a magnetic field into an appropriate electrical signal. In one embodiment, a suitable electrical signal may include a varied analog voltage or current signal representing a magnetic field and/or a change in the magnetic field through which the magnetic sensor 40. In an alternative embodiment, the appropriate electrical signal may include 5 coded voltage signals Digital in response to the magnetic field and/or change in the magnetic field experienced by the magnetic sensor 40.

In one embodiment, the magnetic sensor 40 may be placed to detect magnetic fields and/or changes in the magnetic field within a pass 36. For example, in the embodiment in Figure 12, the magnetic sensor 40 is fitted into an insertable unit, such as a plug 80 10 Appropriately installed inside housing 30 very close to aisle 36. In this embodiment, can

The magnetic sensor 40 is separated from the flow path 36 by a pressure barrier 82 that has a relatively low magnetic permeability (eg, a relatively low tendency to support magnetic field formation). In one embodiment, the pressure barrier 82 can be integrally configured as part of a seal 80. In an alternative embodiment, the pressure barrier 82 may have 15 separate components.

Materials of low magnetic permeability suitable for pressure barrier 82 may include Inconel and other alloys with a high content of nickel and chromium, stainless steels (such as 300 series stainless steel, duplex stainless steel, and so on). Alloys with magnetic permeability rates of 20 from about 1 × 10-6, for example. Aluminum (for example, a magnetic permeability of about 10-6 × 1.26), plastics, ceramics, glass, composite materials (for example, carbon fiber, etc.) magnetism.

Without being restricted by theory, it is the advantage of making pressure barrier 82 from low ferromagnetic material 25 that housing 30 can be made of high ferromagnetic material at low cost

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relatively (such as steel, which has a magnetic permeability of about 4 x 9, for example), but the magnetic fields produced by the magnetic medium 38 in pass 36 can be detected by the magnetic sensor 40 through the pressure barrier 8 2. That is, the magnetic field can 5 That the magnetic flux (for example, a magnetic field) easily passes through the pressure barrier with a relatively low magnetic permeability 82 without distorting it significantly.

In some examples, a material with a relatively high magnetic permeability 84 can be provided near the magnetic sensor 40 and/or a pressure barrier 82, for example, to focus the magnetic flux toward the magnetic sensor 40. For example, a permanent magnet can also be used to tilt the magnetic flux, for example, so that the magnetic flux is within 10 of the magnetic sensor linear detection range 40.

In some examples, the material with a relatively high magnetic permeability 84 surrounding the magnetic sensor 40 can block or protect the magnetic sensor 40 from other fields

14 Other magnetism, such as that produced by magnetism in the ground surrounding the wellbore. For example, a material 84 allows only a focused window of 15 magnetic fields to pass through it, and only from a preferred direction. Without being bound by theory, this is useful to prevent

Other unfavorable magnetic fields from contributing to the magnetic field that the magnetic sensor passes through 40, thus preventing its exit.

Referring now to Figures 13 and 14, the pressure barrier 82 is in the form of a bushing which is received in housing 30. Additionally, in this embodiment, the magneto sensor 40 is placed in a 20 86 orifice formed within the housing 30, such that the magneto sensor 40 is in close proximity from

Passage 36, separated from the pass only by a relatively low magnetic permeability pressure barrier 82. In this embodiment, the magnetic sensor 40 can be attached directly to the outer cylindrical surface of the pressure barrier 82.

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In the embodiment in Figure 14, the magnifying position of the magnetic sensor 40 is depicted. In this example, the magnetic sensor 40 of the electronic circuit 42 is installed in the slot 86. For example, in this embodiment, one or more of the magnetic sensors 40 can be attached to a board A small circle containing the hybrid electrons.

<p>5 In an embodiment, the MSS 100 may include several sensors, for example, for the purpose of error detection and/or redundancy when a magnetic pulse is detected. In one embodiment, several sensors may be used to detect the magnetic field(s) in an axial, radial or circumferential direction. Detecting the magnetic field(s) in many directions can increase the perforation that the pulsed sign 10 will be detected magnetism, regardless of direction. Thus, it must be realized that the detection field is not limited to any specific position or number of magnetic sensors 40. Additionally, in one embodiment, several sensors (such as Magnetic Sensor 40) may be used to determine the direction of travel of one or more magnetic devices , for example, as disclosed in U.S. Order Serial No. _____ [Holder Number: HES 2012-IP-065477U1] by Walton</p>

<p>15th et al., issued under the title "Dual Magnetic Sensor Actuation Assembly", which is included for reference in its entirety.</p>

. In one embodiment, the electronic circuit 42 can generally be configured to receive an electrical signal from

Magnetic sensor 40 (for example, which may indicate a magnetic signal has been received

by magnetic sensor 40) and to determine whether the changes in the electrical signal

<p>20 (therefore, changes in the magnetic signal detected by the magnetic sensor 40) indicate a predetermined magnetic impulse function (for example, one of the</p>

At least one predetermined magnetic pulse that the electronic circuit 42 has been configured/programmed to determine).

<p>25 The specific circuit can be configured to realize it, the electronic circuit 42 etc. can be configured to produce one or more responses</p>

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Occasion. For example, in one embodiment, in response to the perception of a predetermined magnetic pulse function, the electronic circuit 42 can be configured to activate (for example, to enter an active mode), to sleep (for example, to enter a low power consumption mode), etc. A running signal to the operator 50, or combinations thereof.

<p>5 Additionally or alternatively, in one embodiment, the electronic circuit 42 may be configured to determine whether the magnetic sensor 40 has gone through a predetermined number of predetermined magnetic pulse indices. For example, in one embodiment, in response to the perception of a pre-determined magnetic impulse, the electronic circuit 42 can be configured to record and/or count the number of predetermined magnetic impulsive signs that the magnetic sensors 40. In one</p>

<p>10 embodiments, the electronic circuit 42 can be configured to increase and/or decrease a counter (for example, a digital counter, a program variable stored in a memory medium, and so on) in response to the passage of a predetermined magnetic impulse function (for example, through a magnetic medium 38) (for example, through a magnetic medium) The example, as disclosed in the U.S. Application Serial Number: _______ [Pserve number:-HES-2012-IP-065477U1], is included here for reference in its entirety. In one embodiment, it could be</p>

<p>15th Two or more pre-determined magnetospheres received and perceived by the magnetic sensor 40 and electronic circuit 42 are the same (for example, the magnetospheres have the same quantitative and/or qualitative features, as disclosed here); alternatively , two or more predefined magnetic pulse indices received and perceived by the magnetic sensor 40 and electronic circuit 42 can be different (on</p>

<p>20 (e.g., the magnetic pulse markers have different qualitative and/or quantitative features). In one embodiment, once the electronic circuit 42 has been identified, the magnetic sensor 40 has passed the predetermined number of predetermined magnetic pulse markers, the electronic circuit 42 can be configured etc. to produce an appropriate response, as For example, in one embodiment, the electronic circuit etc. can be configured to produce an appropriate response once the passage of the magnetic sensor 40 is determined by about 1,</p>

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2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 15, 20, 30, 35, 40 or more of the preset magnetic pulse functions.

In one embodiment, the electronic circuit 42 can be preprogrammed (for example, before it is placed inside the injection valve 16 and/or before the injection valve 16 is placed in a wellbore) to respond to one or more

<p>5 More than the specified magnetic impulse indices. In an additional or alternative embodiment, the electronic circuit 42 can be configured to be programmed (eg, via a well tool), for example, after being placed inside the injection valve 16.</p>

In one embodiment, the electronic circuit 42 may comprise a group of functional units.

In one embodiment, a functional unit (for example, an integrated circuit

<p>10 IC (circuit ((one function, for example, works like a microphone or bumper. The unit can take place</p>

Functionality Many functions on one slide. A functional unit can have a group

Components (for example, transistors, resistors, capacitors, diodes, and/or inductors) on an IC that can perform a specified function. A functional unit can have a specified set of inputs,

<p>15th A defined set of outputs, and an interface (for example, an electrical interface, a logical interface, and/or other interfaces) with other functional units of the IC and/or external components. In some embodiments, the functional unit may include a TICARART. for a single function (for example, many fluctuations or aggregators on a single chip) or can have two or more different types of functional units that can act together to provide the functional unit</p>

<p>20 its full function. For example, a microprocessor or microcontroller can include functional units such as an arithmetic logic unit (ALU), one or more floating-point units (FPUs), one or more load or storage units, One or more prediction submodules, one or more memory controllers, and other modules In some embodiments, a functional unit may be subdivided into component functional units.</p>

<p>25 A microprocessor or a microcontroller as a whole can be seen as a functional unit of an IC, for example, if</p>

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The microprocessor is involved in a circuit with at least one other functional unit (for example, a temporary memory unit).

Functional units may include, for example, a multiprocessor, a math processor, a state machine, a DSP digital signal processor, a receiver,

<p>5 transmitter, transceiver, logical unit, logical element, relay, demultiplexer, switching unit, switching element, input/output I/O input, terminal controller, bus, bus controller, register, combination logical element storage unit, programmable logic device, memory unit, neural network, sensor circuit, control circuit, analog to digital ADC converter, digital to analog converter</p>

<p>10 (DAC), oscillator, memory, filter, amplifier, mixer, modulator, demodulator, and/or other suitable means as will be recognized by ordinary skilled in the art.</p>

In the embodiments given in Figure 15a-15b and 16a-16b, an electronic circuit 42 may comprise a set of distributed components and/or functional units and each functional unit may be connected to one or more other functional units via an appropriate signal path, for example

<p>15th example, via one or more electrical connections, as will be disclosed here. In an alternative embodiment, the electronic unit 42 may comprise a single, unitary or unallocated component capable of performing the functionality disclosed herein.</p>

In one embodiment, the electronic circuit 42 may be configured to sample an electrical signal (eg

For example, an electrical signal from the magnetic sensor 40) at an appropriate rate. For example, in

<p>20 One embodiment, the electronic circuit sample rate may be 42 about 1 Hz, alternately, about 4 Hz, alternately, about 8 Hz, alternately, about 12 Hz, alternately, about 20 Hz, alternately , about 100 Hz, alternatively, about 1 kilo</p>

Hz, alternatively, about

10 kHz, alternatively, about 100 kHz, as

Alternate, about 1 megahertz (MHz), alternatively, any suitable sample rate that can be realized by

<p>25 Those with ordinary skill in the field immediately upon reviewing this disclosure. In addition, in one</p>

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embodiments, the electronic circuit 42 can be configured to filter, amplify, de-embed, encode, encode, validate, detect errors, correct errors, and perform any other operation suitable for signal processing as ordinary skilled in the field will realize once they have reviewed this detection, or a combination thereof. For example, in one embodiment, the electronic circuit 42 can be configured to remove

5 Include and validate the electrical signal received from the magnetic sensor 40, for example, for the purpose of determining whether the electrical signal received from the magnetic sensor 40 indicates the presence of a pre-defined magnetic pulse. Additionally, in one embodiment, the electronic circuit can be configured to realize many different magnetic impulse indices. For example, an electronic signal can be configured to determine if the electrical signal indicates

<p>10 received from the magnetic sensor 40 indicates the presence of one of several predefined magnetic pulse functions. Furthermore, in an embodiment, the electronic circuit 42 can be configured to record and/or count the number of predetermined magnetic pulses that the magnetic sensor 40 passes through.</p>

In one embodiment, the electronic circuit 42 etc. can be configured to output a voltage or current signal to

<p>15th Trigger 50 in response to the presence of pre-set magnetic pulse markers. For example, in one embodiment, the electronic circuit 42 can be configured to transfer its output from a low-voltage signal (eg, about zero volts (V)) to a high-voltage signal (eg, about 5 volts) in response to the passage of the specified magnetic impulse In an alternative embodiment, the electronic circuit 42 can be configured to transmit its output from a high-voltage signal (for example, about 5 V).</p>

<p>20 (V) to a low-voltage signal (eg, about zero volts) in response to the passage of the sign</p>

Preset magnetic pulse.

In addition, in one embodiment, the electronic circuit 42 can be configured to operate in either a “sleep” or low power consumption mode, or alternatively in an active or active mode. The electronic circuit 42 can be configured to enter active mode (for example, to 'energize') in response to a signal

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A predetermined magnetic pulse, for example, as disclosed here. This method can help prevent misidentification of external magnetic fields as magnetic impulses.

In one embodiment, the electronic circuit 42 may be supplied with electrical power via a power source. For example, in one embodiment, the injection valve 16 may also have a battery comprising 5 therein, a powertrain, or combinations thereof. In this embodiment, the power source and/or the power generation device may supply power to the electronic circuit 42, to the magnetic sensor 40, to the actuator 50, or a combination thereof, for example, for the purpose of operating the electronic circuit 42, to the magnetic sensor 40, to operator 50, or combinations thereof. In one embodiment, the powertrain may comprise a generator, such as a turbine generator adapted to convert fluid motion into power

<p>10 electric; Alternatively, an electrolyte generator, which can be configured to convert differences in temperature into electrical energy. In these embodiments, the power generation device may be carried, attached, included in or appropriately coupled to the well tool and/or component thereof. Appropriate power generation methods, such as a turbine generator and a thermoelectric generator, are disclosed in US Patent No. 8,162,050 to Roddy et al., which is incorporated herein for reference in its entirety. prepare the cell</p>

<p>15th Galvanic is an example of a power source and/or a means of generating power. In one embodiment, the power source and/or the power generation device may be sufficient to power an electronic circuit 42, magnetic sensor 40, actuator 50, or combinations thereof. For example, the power source and/or the power generation device may supply power in the range of about 0.5 W to about 10 W, alternatively, from about 0.50.5 W to about 1.0 W.</p>

<p>20 One or more embodiments of MSS (eg, MSS 100), well tool (eg, injection valve 16) comprising MSS 100, and/or wellbore service system comprising well tool are disclosed herein. (eg, such as injection valve 16) comprising 100 MSS, and one or more embodiments of a wellbore servicing method using said 16 injection valve, such as 100MSS and/or this system are also disclosed. In one embodiment, 25 could include The method of servicing a well bore is generally based on the steps of laying a string of pipes (eg</p>

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example, such as a series of tubing 12) has an injection valve 16 (for example, an injection valve 16A-E, as shown in Figure 1) with 100 MSS embedded within it in a wellbore (for example, such as a wellbore 14), inserting A magnetic medium 38 in the piping chain 12 and through one or more injection valves 16, and transmission of the injection valve 16 to allow fluid communication between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 when a predetermined magnetic impulse function is perceived (for example, Magnetic impulse function defined by valve initialization/programming injections 16 for identification (.

As will be disclosed here, the MSS 100 can control fluid communication via the tubular member 12 and/or the injection valve 16 during the wellbore service operation. For example, as will be

<p>10 disclosed here, during the tubular member 12 in the wellbore step 14, the MSS 100 can be configured to not allow fluid contact between the flow lane 36 of the injection valve 16 and the wellbore 14, for example, by not operating the actuator 50 causing bushing ( For example, bushing 32) in position 1 with respect to housing 30, as will be disclosed here. Also, for example, during injection valve positioning step 16 to allow fluid communication between the flow passage</p>

15th 36 of the injection valve 16 and the outside of the injection valve 16 (for example, once you realize the significance

pre-set magnetic pulse) MSS 100 can be configured to allow fluid communication between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16, for example, by operating the actuator 50 causing the bushing 32 to be moved to the second position relative to the housing 30, as will be detected about it here.

20 An embodiment of a wellbore servicing method using a combination of 16A-E injection valves is disclosed here for Figure 1. While the following embodiment of this method is provided as an example of the method, those of ordinary skill in the art will realize once they have reviewed this disclosure that there are many other methods and/or alternatives to this method. Consequently, this disclosure should not be construed as being limited to the methods disclosed herein.

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In one embodiment, the placement of tubular member 12 comprising one or more injection valves 16 (eg, injection valves 16a-e) comprising 100 MSS embedded therein into a borehole 14 may include the formation and/or assembly of tubular member components 12, for example, when the tubular member 12 is extended into the wellbore 14. For example, with reference to Figure 51, a set of injection valves is included (for example, injection valves 16a-e), which

Each includes 100 MSSs in tubular member 12 via an appropriate adapter as ordinary skilled in the art will realize once they review this disclosure.

In one embodiment, tubular member 12 and/or injection valves 16A-16E may be extended in the wellbore 14 to a preferred depth and may be located near one or more subterranean formation regions.

10 (such as zones 22a-22d). In one embodiment, the tubular member 12 may be extended into the wellbore 14 with injection valves 16a-16e configured in the first configuration, for example, with the bushing 32 in the first position relative to the housing 30, as disclosed In this embodiment with the injection valves 16A-16E in the first configuration, each valve will prevent fluid communication between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 (eg, wellbore 14).

15th For example, as shown in Figures 15a-15b, when the injection valve 16 is configured in the first configuration, fluid contact between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 can be prevented through the orifices 28.

Optionally, in an embodiment, once the injection valve 16 and/or the wellbore service system 10 are positioned, the 100 MSS can be programmed or reprogrammed to respond to a predetermined magnetic impulse function 20. For example, in one embodiment, a second well tool (for example,

A tool on a chain drive, magnetic device, and so on) with 100 MSS to program or reprogram 100 MSS, for example, via a data package containing command instructions (for example, initialization). Alternatively, in one embodiment, it can be programmed 100 MSS prior to inclusion in a wellbore servicing system 10 and/or prior to the placement of a wellbore servicing system 10 within a wellbore 14.

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In one embodiment, one or more magnetic devices may be connected through the flow path 36 of the 16A-E injection valve (eg, via the axial flow borehole of the wellbore service system 10) and can be pumped down the well to operate one or more 16A-E injection valves 16e magnetically, and optionally engaged in. For example, in one embodiment, a pump can be

5 A magnetic device 38 in the axial flow borehole of a wellbore service system 10, for example, with a fluid extension connected through one or more pumps generally placed on the ground.

In one embodiment, the magnetic device 38 may be configured to release and/or transmit the magnetic pulse during the review of the axial flow borehole of a wellbore service system 10. For example, in one embodiment, the magnetic device 38 may transmit the magnetic pulse which can

<p>10 Specifically and/or uniquely associated with one or more 16A-E injection valves (eg, a signal perceived by one or more 16A-E valves, specifically, a pre-determined magnetic impulse). Adapt the magnetic medium 38 to target and/or provide selective operation to one or more injection valves 16, which aids in fluid communication between the flow path of one or more injection valves and the outside of one or more injection valves.</p>

<p>15th Over injection valves. Alternatively, a magnetic device such as a magnetic device 38 may be configured to emit and/or transmit a magnetic signal (for example, a magnetic impulse) that is not the magnetic impulse associated with a specific valve 16.</p>

For example, with reference to Figure 1, the magnetic medium can release a signal (for example, a magnetic impulse) that represents the pre-determined magnetic impulse associated with

<p>20 with one or more injection valves 16A-E. As an example, the magnetic device may emit a signal representing the pre-determined magnetic impulse function associated with fuses 16A, 16B, 16C and 16D but not associated with fuse 16E.</p>

In one embodiment, the injection valve transmission 16 may include such that it permits fluid communication between the flow passage 36 of the injection valve 16 and the outside of the injection valve 16 when a predetermined number is realized.

<p>25 From pre-set magnetic pulse indices to move the injection valve 16 from the first shape to the shape</p>

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the second, for example, by moving the sleeve 32 from the first position to the second position with respect to housing 30, as shown in Figures 16a-16b. In one embodiment, the injection valve 16 and/or 100 MSS can pass and respond to a predetermined magnetic impulse, for example, as it can be fired upon contact with one or more magnetic means 38 via

<p>5 The wellbore service system 10 (for example, via injection valves 16A-E). For example, in this embodiment, once a magnetic impulse is perceived, 100 MSS (eg via an electrical actuation signal output) can operate Actuator 50, allowing and/or causing bushing 32 with respect to housing 30 and to move from the first position to the second position with respect to housing 30. In an alternative embodiment, a set of magnetic means is introduced into the wellbore service system 10</p>

10 It can record 100 MSS (for example, within a memory device of an electronic circuit 42) and/or calculate (for example, via the algorithm a counter stored on an electronic circuit 42) the number of predetermined magnetic pulses that have been passed. In this embodiment 100 MSS can trigger the trigger 50 in response to passing a predetermined amount (number) of preset magneto impulses.

15th Alternatively, in one embodiment, a magnetic device 38 may be connected via an injection valve ^y

(eg one of the 16A-E syringe valves) and may not elicit a response, eg, where the magnetic medium emits a magnetic impulse different from the predetermined magnetic impulse associated with said specific syringe valve.

Continuing to refer to the example in which the magnetic medium gives off a signal that is an impulse function

20 Predetermined magnetism associated with valves 16a, 16b, 16c, and 16d Once the predetermined magnetic signification is recognized, the 16d valve can be configured to operate with the goal of allowing a fluid contact path, for example, the 16d valve reaches the predetermined number of predetermined magnetic impulses (at e.g. 1 predefined magnetic pulse function). Also, fuses 16A-16C can be configured to increment their associated counter, but not to turn on fuses 16

25 16 c.

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In one embodiment, when one or more injection valves 16 are configured to deliver a service fluid, as disclosed herein, an appropriate wellbore service fluid may be delivered to the subterranean formation zone associated with that valve. Non-limiting examples given of a suitable well bore servicing fluid include, but are not limited to, fracturing fluid, hydraulic perforating or jetting fluid, acidifying fluid, and the like or

5 combinations of them. The wellbore service fluid can be delivered at an appropriate rate and pressure for an appropriate duration. For example, a wellbore servicing fluid may be delivered at a rate and/or pressure sufficient to initiate or extend the fluid's path (eg, perforation or fracturing) within the aquifer and/or an area of ​​it.

In one embodiment, when a preferred amount of service fluid is delivered through a first 16 valve, the actuator may stop the delivery. Optionally, the treated area can be isolated, at

10 For example, by a mechanical seal, a sand plug, or the like, or by a ball or stopper. The process of moving a valve from the first body to the second body (for example, by inserting several magnetic devices) and delivering a service across the open valve(s) 16 can be repeated for one or more valves, and their associated formation areas.

For example, continuing to refer to the example disclosed for Fig. 1, 15 the method may further comprise the connection of a second magnetic medium through the tubing chain 12. In one embodiment, the second magnetic medium may be configured to trigger a predetermined magnetic impulse function which can be be similar, alternatively different from, the pre-determined magnetic impulse function triggered by the first magnetic means. In one embodiment, once the predetermined magnetic significance triggered by the second magnetic device is realised, 20 valves 16a, 16b, and 16c can be configured to increment the associated counter, causing the valve 16a to travel from

The first set to the second setting while valves 16B and 16C remain unoperated. With valve 16a in the first configuration, a borehole service fluid may be delivered, for example, at sufficient rate and/or pressure to initiate and/or extend a fault within the subsurface formation, via valve 16a.

When a preferred amount of service fluid is connected through valve 16a, the actuator 25 can stop the connection through valve 16a and a third magnetic medium can be connected through the tubular chain

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10

15

20

25

12. In one embodiment, the third magnetic means may be configured to trigger a pre-determined magnetic impulse function which can be identical, alternatively different from, the pre-determined magnetic impulse function triggered by the first magnetic means and/or the second magnetic medium. In one embodiment, once the predetermined magnetic significance triggered by the third magnetic medium is realized, valves 16B and 16C can be configured to increment their associated counter, causing valves 16B and 16C to move from the first configuration to the second configuration. Additionally or alternatively, in an embodiment, once the pre-determined magnetic significance of

Released by the third magnetic medium, valve 16a can be configured to move from a second body to a third body, for example, where valve 16a does not provide a path for fluid communication to the subterranean formation. With valves 16B and 16C in the first configuration, a borehole service fluid may be delivered, for example, at sufficient rate and/or pressure to initiate and/or extend a fault within the aquifer, via valves 16B and 16C.

In one embodiment, a well tool such as an injection valve 16, a wellbore service system such as a wellbore servicing system 10 comprising a 16 injection valve comprising 100 MSS, such as a 100 MS, a wellbore servicing method using a wellbore service system 10 and/or a wellbore servicing system 10 and/or Such as a 16-injection valve comprising 100 MSS, or combinations thereof characteristically in performing a wellbore servicing operation. For example, conventional wellbore servicing systems with a combination of well tools (for example, injection valves) may be limited to sequential operation of a combination of well tools in a bottom-up direction, for example, from the end of an existing wellbore service system Downhole to the tip of the uphole wellbore service system. In an embodiment, as disclosed before, the MSS allows the operator to selectively actuate one or more injection valves, for example, by introducing one or more magnetic devices having a magnetic impulse function uniquely associated with one or more of injection valves. Thus, MSS can be used to provide improved performance during a borehole operation, for example, by allowing several injection valves to be operated largely synchronously and/or to operate selectively in a preferred sequence.

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In addition, conventional well tools can be configured to operate upon going through a change in a magnetic field (for example, via a magnetic medium) or a predetermined number of changes in a magnetic field (for example, through a combination of magnetic means). In these embodiments In conventional, the magnetic medium may not have a magnetic impulse indicative and may be subjected to

5 Conventional well instruments result in false positive readings. In one embodiment, MSS can reduce accidental operation (or failures to operate) of an injection valve, for example, as a result of sensing a false positive magnetic medium and thus provide improved reliability of the wellbore service system and/or well tool.

It must be realized that the many embodiments described before can be used in many directions, such as diagonal, inverted, horizontal, vertical, and so on, and in many forms, without departing from the principles of

This disclosure. The embodiments are described as examples of useful uses of the disclosure concepts, which are not limited to any specific details of these embodiments.

Of course, those skilled in the art, once taking into account the above description of illustrative embodiments of the disclosure, can easily realize that many modifications, additions,

15th Replacements, omissions, and other changes to specific embodiments, and such changes are within the concepts of this disclosure. Thus, it should be noted that the previous detailed description is presented by way of illustration and example only, and the content and scope of the invention are determined only by the appended claims and their equivalent.

Additional detection

20 The following are illustrative, unrestricted embodiments of the present disclosure:

A first embodiment, is a borehole service tool comprising:

a housing comprising one or more outlets and generally defining a flow lane;

operator placed inside the housing;

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Magnetic Sense System (MSS) comprising a magnetic sensor in signal contact with an electronic circuit placed inside the housing and coupled to the actuator; and

The bushing is sliding in the housing and moved from the first position to the second position;

where, the bushing is allowed to move from the first position to the second position once the actuator is turned on, and

5 The trigger is triggered upon realization of a predetermined amount of predefined magnetic pulse indices via MSS.

A second embodiment is a wellbore servicing device of the first embodiment, where, when the sleeve is in the first position, the sleeve is primed to block the path of fluid communication through one or more of the housing ports, and when the sleeve is in the second position, the sleeve is primed to allow fluid communication Via 10 one or more housing outlets.

A third embodiment, a wellbore servicing device according to one of embodiments 1 through 2, where, when the bushing is in the first position, the bushing is configured to allow a path of fluid communication through one or more ports of the housing, and when the sleeve is in the second position, the Sleeves to prevent fluid contact through one or more housing ports.

15th embodiment four, is a wellbore servicing device according to one of embodiments I to III, wherein the wellbore servicing tool further comprises a metal layer placed between the axial flow hole of the housing and the magnetic sensor.

A fifth embodiment, a wellbore servicing device according to one of embodiments one through four, wherein the wellbore servicing tool further comprises a layer of conductive material placed between the axial flow hole 20 of the housing and the magnetic sensor.

A sixth embodiment is a wellbore servicing tool according to one of the first through fifth embodiments, wherein a predetermined amount of predetermined magneto impulses include a single, predetermined magnetic pulse uniquely assigned to the well tool only.

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A seventh embodiment is a wellbore servicing tool according to one of the first to sixth embodiments, where the predetermined quantity of predetermined magnetic impulses is one.

An eighth embodiment, is a wellbore servicing tool according to one of embodiments I to VII, wherein the predetermined quantity of the predetermined magnetic impulse is on at least two of the 5 predetermined magnetospheres.

A ninth embodiment is a wellbore servicing tool in accordance with one of the first through eight embodiments, wherein the MSS is programmable via a second well tool.

A tenth embodiment is a wellbore servicing instrument according to one of the first through IX embodiments, where the magnetic pulse is a digital signal.

10 An eleventh embodiment is a wellbore servicing instrument according to one of the first to tenth embodiments, the digital signal is modulated and/or encoded via frequency modulation FM (frequency modulation), modified frequency modulation MFM (modified frequency modulation), cycle-length defined encoder RLL run length-limited), or combinations thereof.

embodiment twelfth, is a wellbore servicing instrument according to one of the embodiments I to XI XI, wherein the magnetic pulse is an analog signal comprising one or more of the predetermined frequencies.

embodiment thirteenth, is a wellbore servicing instrument according to one of the first through twelfth embodiments, wherein the analog signal has a sine waveform or square waveform.

Fourteen embodiment, is a borehole service system that includes:

20 tubular string placed inside a borehole; And

First well tool included in the pipeline and includes:

a first housing that includes one or more of the first ports and generally defines a first flow lane;

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The actuator of the first thread inside the first housing;

A first magnetic indication system (MSS) comprising a first magnetic sensor and first electronic circuit placed inside the housing and coupled to the actuator, and

The first sleeve is slipped into the first housing and moves from the first position to the second position 5,

where, the first sleeve moves from the first position to the second position as soon as the first trigger is turned on, and

The first trigger is triggered when a predetermined amount of preset magnetic pulse indices are realized via the first MSS.

embodiment fifteen, is a wellbore service system of embodiment fourteen, wherein, when the first bushing is in the first position, the first bushing is configured to block the fluid communication path through

One or more of the first ports of the first housing, and when the first sleeve is in the second position, the first sleeve is configured to allow fluid communication through one or more of the first ports of the first housing.

embodiment sixteen, is a wellbore servicing system according to one of the fourteenth to fifteenth embodiments, wherein, when the first sleeve is in the first position, the first sleeve is primed

To allow the path of fluid communication through one or more of the first ports of the first housing, and when the first sleeve is in the second position, the first sleeve is configured to prevent fluid communication through one or more of the first ports of the first housing.

Seventeenth embodiment, is a wellbore servicing system according to one of the fourteenth to twenty-sixteenth embodiments, wherein the first well tool further comprises a metallic layer placed between the first axial flow hole of the housing and the first magnetic sensor.

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Eighth embodiment, is a wellbore servicing system according to one of the fourteenth through seventeenth embodiments, wherein the predetermined magnetic impulse is uniquely assigned to the first well tool.

embodiment nineteenth, is a wellbore service system according to one of the fourteenth to fiveteenth embodiments, wherein the predetermined quantity of the predetermined magnetic impulse indices

One.

Embodiment Twenty, is a wellbore service tool according to one of the fourteenth to nineteenth embodiments, wherein the predetermined quantity of the predetermined magnetic impulse function is at least two.

10 Twenty-first embodiment, is a wellbore service system according to one of the fourteenth to twentieth embodiments, wherein the first MSS is programmable via a second well tool.

Twenty-second embodiment, is a wellbore servicing system according to one of the fourteenth through twenty-first, wherein the magnetic impulse has a digital signal.

Twenty-third embodiment, is a wellbore servicing system according to one of the fourteen to

15th Twenty-second, where the magnetic pulse sign has an analog signal that includes one or more of the predetermined frequencies.

Embodiment Twenty-Four, is a wellbore servicing system of embodiment 23, wherein the analog signal has a sine waveform or square waveform.

embodiment twenty-fifth, is a wellbore service system according to one of the fourteen 20 to twenty four embodiments, which also includes a second well tool embedded within the pipeline and includes

On:

a housing comprising one or more outlets and generally defining a flow lane;

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operator placed inside the housing;

MSS comprising a first magnetic sensor and electronic circuit placed inside the housing and coupled to the actuator, and

The bushing is sliding in the housing and moved from the first position to the second position;

Where, when the sleeve is in the first position, the sleeve is configured to block the path of fluid communication through one or more housing ports, and when the sleeve is in the second position, the sleeve is configured to allow fluid communication through one or more housing ports.

where, the bushing moves from the first position to the second position as soon as the actuator is turned on, and

10

15

The trigger is triggered when a predetermined amount of predefined magnetic pulse indices are realized via MSS.

embodiment 26, is a wellbore service system of embodiment 25, which also includes a first magnetic device configured to release a first magnetic impulse signal.

embodiment twenty-seventh, is a wellbore service system of embodiment 26, wherein the pre-determined magnetic impulse function is realized by the first well tool.

Twenty-eighth embodiment, is a wellbore servicing system according to the twenty-seventh embodiment, where the perception of the first magnetic impulse by the first well tool is effective in operating the actuator.

Twenty-ninth embodiment, a wellbore service system according to one of the twenty-seventh to twenty-eighth embodiments, where the perception of the first magnetic impulse is by the well tool

20 The first is effective in increasing the counter.

embodiment thirtieth, is a wellbore service system of embodiment 27, wherein the pre-determined magnetic impulse function of the first is not perceived by the second well tool.

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Embodiment Thirty-One, is a wellbore service system of embodiment 27, wherein the first pre-determined magnetic impulse is perceived by the second well tool.

Thirty-second embodiment, is a wellbore service system of the thirty-first embodiment, which also includes a second magnetic device configured to release a second magnetic impulse signal.

5 Embodiment Thirty-Third, is a wellbore service system of the thirty-second embodiment, wherein the second pre-determined magnetic impulse is not perceived by the first well tool.

embodiment thirty-four, is a wellbore servicing system of embodiment thirty-two, where no

Realize the second magnetic impulse function predetermined by the first well tool.

The fifth and third embodiment , is a wellbore servicing system for the thirty-fourth embodiment, where the

10 The realization of the second magnetic impulse function by the first well tool is effective in operating the actuator.

The thirty-sixth embodiment, is a wellbore service system according to the thirty-fourth embodiment, where the perception of the first magnetic impulse by the first well tool is effective in increasing the counter.

embodiment thirty-seven, is a wellbore servicing system of embodiment 26, wherein the magnetic medium comprises an alternating current electromagnet.

15th embodiment thirty-eight, is a wellbore servicing system of embodiment 26, wherein the magnetic medium comprises a direct current electromagnet.

Thirty-ninth embodiment, is a wellbore servicing system of one of the twenty-sixth through thirty-eighth, wherein the magnetic medium comprises a direct current electromagnet and an alternating current magnet.

20 Embodiment Forty, is a wellbore servicing method that includes:

Placement of a tube series comprising a well instrument comprising a magnetic MSS signature system, in which the well instrument is configured to either allow a fluid communication path between

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the outer part of the well tool and axial flow hole of the well tool or to prevent the path of fluid communication between the outer part of the well tool and the axial flow hole of the well tool;

Inserting a magnetic medium into the axial flow hole of the borehole, the magnetic medium sending a magnetic signal;

5 Well Tool Operation When a pre-determined magnetic significance is realized via MSS, the well tool is reconfigured to alter the path of fluid communication between the outside of the well tool and the axial flow bore of the well tool.

embodiment forty-first, is a wellbore servicing method of embodiment forty, wherein actuation of the tool includes allowing fluid communication over the fluid communication path where previously prohibited

10 Fluid communication via the fluid communication path.

Embodiment forty-second, is a wellbore servicing method according to one of the forty-first embodiments, wherein actuation of the tool involves preventing fluid communication over the fluid communication path where fluid communication over the fluid communication path has previously been permitted.

embodiment forty-third, is a wellbore servicing method according to one of the forty-second embodiments 15 through the forty-second, wherein the MSS comprises a magnetic sensor and electronic circuit.

embodiment forty-four, is a wellbore servicing method according to one of the forty-fourth to forty-third, wherein the well tool further comprises a metal layer placed between the axial flow hole of the housing and the magnetic sensor.

embodiment forty-fifth, is a wellbore servicing method according to one of the forty-fifth embodiments

20 The forty-four, where the pre-determined magnetic pulse function is uniquely customized

borehole tool.

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embodiment forty-sixth, is a wellbore servicing method according to one of the forty-fifth embodiments, wherein the predetermined magnetic impulse has a predetermined amount of magnetic impulse.

embodiment forty-seventh, is a wellbore servicing method according to one of the forty-sixth embodiments 5 through the forty-sixth, wherein the MSS is programmable via a second well tool.

embodiment forty-eighth, is a wellbore servicing method according to one of the forty- forty-seventh embodiments, wherein the transfer of the well tool from the first body to the second body involves actuating an actuator upon realization of a predetermined magnetic impulse function.

embodiment forty-ninth, is a wellbore servicing method of embodiment forty-eighth, wherein 10 operation of the actuator moves a bushing from a first position to a second position.

Embodiment Fifty, is a wellbore servicing method according to one of the forty- forty-ninth embodiments, in which the well tool does not respond to a magnetic device that sends a magnetic signal not including the predetermined magnetic impulse.

While embodiments of the invention have been illustrated and described, modifications may be made by the proponents of

15th Skill in the field without deviating from the field of invention and the information contained therein. The embodiments described here are illustrative only, and are not intended to limit. Many changes and modifications can be made to the invention disclosed herein and they fall within the scope of the invention. When publicly disclosing numerical domains or limitations, be aware that the declared domains or limitations include repeating domains or limitations to the same extent that they fall within the publicly stated ranges or limitations (for example,

20 The range from about 1 to about 10 includes 2, 3, 4 and so on; and greater than 0.10 includes 0.11, 0.12, 0.13, and so on). For example, whenever a numeric range with a lower bound, Rl, and an upper bound, Ru, is detected, any number that falls within the range is specifically detected. Specifically, In particular, detect the following numbers within the range: R=Rl +k* (Ru-Rl), where k is a variable ranging from 1 percent to 100 percent in 1 percent increments, that is, be

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k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, ..... 50 in

percent, 51 percent, 52 percent, ...., 95 percent, 96 percent, 97 percent, 98

percent, 99 percent, or 100 percent. Furthermore, any numeric range identified with two R numbers as specified above is also specifically disclosed. The use of the term “optionally 5” in relation to any element of an element of protection is intended to mean that the said element is needed, or alternatively no such element. Both alternatives are intended to fall within the scope of the element of protection. It should be recognized that the use of larger terms such as includes, includes, by, and so provides support for narrower terms such as consists of, mainly consists of, mainly includes, and so on.

10 Accordingly, the scope of protection is not limited to the above description but is limited only to the elements of protection

the following, whose scope includes all equivalents of the object of protection items. Each claim is included in the specification as an embodiment of the present invention. Thus, the protection items represent another description which is yi

In addition to embodiments of the current invention. Discussion of a reference in the detailed description of embodiments does not constitute an acknowledgment that it represents art prior to the present invention, and in particular any reference that may have a publication date after the 15 precedence date of this application. The disclosure contents of all patents, patent applications, and publications cited herein are included by reference, to the extent that illustrative, procedural or other details are provided supplementary to those described herein.

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