Patent Application
20170328188
The invention relates to a multistage high pressure fracturing system and tubular hydraulic valve (THV) system for connection to a completion string to enable isolation of a zone of interest within a well. In particular, the system enables access to a downhole formation for fracturing the zone of interest and for hydrocarbon production. The system generally incudes an electronic plug counting system, a plug capture system and a valve system wherein dropping a series of plugs down the completion string enables successive capture of individual plugs within individual THVs for subsequent fracturing operations.
In the oil and gas industry, during well completion operations, there is often a need to conduct different operations at various zones within the well in order to enhance production from the well. That is, within a particular well, there may be several zones of economic interest that after drilling and/or casing, the operator may wish to access the well directly and/or open the casing in order to conduct fracturing operations to promote the migration of hydrocarbons from the formation to the well for production.
In the past, there have been a number of techniques that operators have utilized in cased wells to isolate one or more zones of interest to enable access to the formation as well as to conduct fracturing operations. In the simplest situation, a cased well may simply need to be opened at an appropriate location to enable hydrocarbons to flow into the well. In this case, the casing of the well (and any associated cement) may be penetrated at the desired location such that interior of the well casing is exposed to the formation and hydrocarbons can migrate from the formation to the interior of the well.
While this basic technique has been utilized in the past, it has been generally recognized that the complexity of penetrating steel casing/cement at a desired zone is more complicated and more likely to be subject to complications than positioning specialized sections of casing adjacent a zone of interest and then opening that section after the well has been cased. Generally, if a specialized section of casing is positioned adjacent a zone of interest, various techniques can be utilized to effectively open one or more ports in a section of casing without the need to physically cut through the steel casing.
In other situations, particularly if there is a need to fracture one or more zones of the formation, systems and techniques have been developed to isolate particular sections of the well in order to both enable selective opening of specialized ports in the casing and conduct fracturing operations within a single zone.
One such technique is to incorporate packer elements and various specialized pieces equipment into one or more tubing strings, run the tubing string(s) into the well and conduct various hydraulic operations to effect opening of ports within the tubing strings.
Importantly, while these techniques have been effective, there has been a need for systems and methods that minimize the complexity of such systems. That is, any operation involving downhole equipment is expensive in terms of capital/rental cost and time required to complete such operations. Thus, to the extent that the complexity of the equipment can be reduced and/or the time/personnel required to conduct such operations, such systems can provide significant economic advantages to the operator.
In the past, such techniques of isolating sections of a well have included systems that utilize balls within a tubing string to enable successive areas of a tubing string to be isolated. In these systems, a ball is dropped/pumped down the tubing string where it may engage with specialized seats within the string and thereby seal off a lower section of the well from an upper section of the well. In the past, in order to ensure that a lower section is sealed before an upper section, a series of balls having different diameters are dropped down the tubing starting with a smallest diameter ball and progressing uphole with progressively larger balls. Typically, each ball may vary in diameter by ⅛th of an inch and will engage with a downhole seat sized to engage with a specific diameter ball only. While effective, this system is practically limited by the range in diameters in balls. That is, to enable 16 zones of interest to be isolated, the smallest ball would be 2 inches smaller in diameter compared to the largest ball. As a result, there are practical limitations in the number of zones that can be incorporated into a tubing string which thus limits the number of zones that can be fracturing. As a modern well may wish to conduct up to approximately 40 fracturing operations and possibly more than 40 fractures, current ball drop and capture systems cannot be incorporated into such wells.
Thus, there has been a need for a system that is not limited by the size of the balls being dropped and that can enable a significantly larger number of fracturing windows to be incorporated within a tubing string.
In accordance with the invention, there is provided a tubular hydraulic valve (THV) system for connection to a completion string to enable isolation of a zone of interest within a well, to enable access to a downhole formation for fracturing the zone of interest and for hydrocarbon production, the THV having an internal bore enabling a plug to pass through the THV, the THV comprising: an electronic plug counting system having an uphole end for connection to a completion string and a plug engagement system for engagement with a plug passing through the internal bore, the plug engagement system for counting successive plugs passing through the electronic plug counting system and for triggering a first hydraulic event when a pre-set number of plugs passing through the internal bore is reached; a valved plug capture system operatively connected to the electronic plug counting system, the electronic plug counting system responsive to the first hydraulic event to effect plug capture within the THV when the first hydraulic event is triggered; a valved frac port system operatively connected to the electronic plug counting system and plug capture system, the valved frac port system including a valve responsive to plug capture to open one or more frac ports to enable fluid flow from the internal bore to the exterior of the THV, and a valved plug release system, the plug release system operatively connected to and configured adjacent to the plug capture system and the valved frac port system, such that engagement of the plug release system releases a plug to allow the plug to travel freely either uphole or downhole.
In another embodiment, the system further includes a first hydraulic channel between the electronic plug counting system and the plug capture system and wherein downhole movement of the plug piston opens the first hydraulic channel allowing hydraulic fluid to flow to a plug capture piston within the plug capture system and wherein the plug capture piston is responsive to the flow of hydraulic fluid through the first hydraulic channel to cause downhole movement of the plug capture piston.
In one embodiment, downhole movement of the plug capture piston narrows a portion of the internal bore within the plug capture system to prevent a plug from passing through the plug capture system.
In yet another embodiment, the system further includes a plug capture lock operatively connected to the plug capture system, the plug capture lock for engagement with the plug capture piston to prevent full uphole movement of the plug capture piston.
In one embodiment, the system may also include a valve piston and wherein when the plug capture system has retained a plug, the valve piston is exposed to hydraulic fluid within the internal bore to cause downhole movement of the valve system to open a valve.
In another embodiment, the electronic plug counting system includes a processor, a memory element, and power system operatively connected to a plug engagement system and to an electronically actuated solenoid valve or electric motor for controlling the flow of hydraulic fluid through a hydraulic channel wherein a plug passing through the internal bore is counted by the processor and when a pre-set number of plugs are counted, the processor opens the electronically actuated solenoid valve or causes the electric motor to engage, thereby triggering the first hydraulic event. In an embodiment, the processor memory element is pre-programmed with the plug count that the electronically actuated solenoid valve or electric motor is intended to be triggered on.
In an embodiment, the memory element can be associated with or connected to the processor and can be configured as non-volatile memory and can be programmed with the plug pass count corresponding to a particular frac stage. In an embodiment, the electronic plug counting system can be configured to count each plug that passes. Then, based on a pre-configured count, the electronic plug counting system can actuate the configured engagement system. The engagement system can be configured as an electronically actuated solenoid valve or as an electric motor based system. Whatever engagement system is configured, it will actuate after the pre-configured count has occurred. In a further embodiment, the programming stored on the memory element associated with the processor can include backup programming such that after a power cycle or other downtime event, the electronic plug counting system can resume operation. Based on the event that occurred, such as a power cycle, the program code that is run may change from what was originally set. Alternatively, the same code can be configured to resume once operation of the electronic plug counting system has been restored. If this is the case, if any plugs were missed, the system would engage on the next plug. In an alternate embodiment, the programming can be configured to take no further actions after a power cycle or other downtime event.
In another embodiment, the plug engagement system includes at least one movable pin in operative engagement with an electrical circuit, wherein engagement of a plug with the at least one pin as the plug passes through the internal bore moves the pin and connects or disconnects the electrical circuit and sends a signal to the processor that a plug has passed. The plug engagement system may include two movable pins spaced apart longitudinally in the internal bore, each pin in operative engagement with an electrical circuit, the two pins enabling the processor to determine the direction a plug has moved in the internal bore. The two pins may be spaced apart longitudinally to enable a passing plug to disengage one of the pins before engaging the other pin. The two pins may be out of phase with each other along the internal bore.
In another embodiment, another sensor type can be configured to count plugs that pass by the system. The configured sensor types can include acoustic sensors, magnetic sensors, optical sensors, radar based sensors, flow sensors, pressure sensors, or laser based sensors, each of which can be configured to detect a “count” when a plug or frac ball passes by.
In an embodiment, multiple sensors and/or sensors of different types can be configured at the same time to ensure that accurate plug counts are achieved. Alternatively, multiple plug counting systems can be configured and the counts from each system can be compared before triggering the electronically actuated solenoid valve or electric motor to engage the valved plug and/or ball capture systems.
Further, the memory element can include programming to direct the behavior of the electronically actuated solenoid valve or electric motor after actuation or after a plug and/or ball capture event has occurred. For example, the electronically actuated solenoid valve or electric motor can be configured to cycle at a pre-programmed time interval or upon the occurrence of another event. Another event can include, for example, if another plug and/or frac ball was observed by the electronic plug counting system. In this embodiment, upon the observation of the plug and/or frac ball, the electronically actuated solenoid valve or electric motor can cycle to initiate another change in the system, such as the closing of the electronically actuated solenoid valve or alternatively the actuation of another configured electronically actuated solenoid valve or electric motor.
In a further embodiment, the time between the processor determining the pre-set number of plugs have been counted and the triggering of the first hydraulic event is programmable.
In another embodiment, the invention provides a tubular hydraulic valve system for connection to a tubing string to isolate a zone of interest within a well, to access a downhole formation for fracturing the zone of interest and for hydrocarbon production, the tubular hydraulic valve system comprising: an outer sleeve having uphole and downhole connectors for attaching the tubular hydraulic valve system to a tubing string, the outer sleeve containing: an electronic plug counting system within the outer sleeve, in an embodiment, the electronic plug counting system having: at least one plug interaction surface for detecting the movement of a plug past the electronic plug counting system or another sensor for detecting the movement of a plug past the electronic plug counting system; and, a hydraulic activation system operable to activate a plug capture system when a pre-set number of plugs have moved past the electronic plug counting system; wherein the plug capture system is operatively connected to the electronic plug counting system and is responsive to the hydraulic activation system to activate a plug retention surface and thereby retain a plug within the plug capture system and seal the downhole section of the tubing string from the uphole section of the tubing string at the plug; and, a valve system operatively connected to the plug capture system, the valve system including a valve operatively connected to at least one opening in the outer sleeve and wherein the valve system is responsive to a hydraulic fluid pressure to open the valve when a plug is retained in the plug capture system.
In another aspect, the invention provides a method for activating a hydraulic valve in a completion string having a plurality of tubular hydraulic valves (THV) as in claim 1 and corresponding packer elements incorporated therein, comprising the steps of: a) pressurizing the completion string to a first pressure to set the packer elements within the well; b) increasing the pressure within the completion string to a second pressure level sufficient to effect rupture of a first shear pin within a THV; c) dropping a plug into the completion string, the plug for successive engagement with electronic plug counting systems within each THV and wherein if engagement of a plug with a THV triggers a first hydraulic event, the first shear pin ruptures to effect plug capture within the THV and valve opening; and d) increasing the pressure within the completion string to a third pressure level to effect well fracturing.
In one embodiment, each of steps b)-d) are repeated for each THV within the completion string.
The invention is described with reference to the accompanying figures in which:
With reference to the figures, a multistage fracturing device (MFD) or tubular hydraulic valve (THV) 10 and methods of operating a MFD or THV are described.
For the purposes of description herein, the MFD or THV 10 includes a plurality of sub-systems that may be configured to a casing or completion tubing string 20 together with appropriate packer elements 10a to enable the isolation of particular zones within a formation 8a as shown in
It should also be noted that the system may be utilized without packer elements in situations for example where the completion string is cemented in place. While the following description assumes the use of packer elements 10a, this is not intended to be limiting.
As described in detail below, the MFD includes generally includes an electronic ball counting and valve actuation sub-system 12, a valved ball-capture sub-system 14 and a valved ball release sub-system 16 as shown schematically in
It should be noted that the description utilizes various terms interchangeably with other terms for the purposes of functional description and/or to represent examples of specific embodiments. Importantly, the use of one term as compared to another is not intended to be limiting with regards to the scope of interpretation by those skilled in the art. For example, the description refers to the system as a multistage fracturing device (MFD) which is synonymous to a tubular hydraulic valve (THV) as well as to a “ball” or “plug” where a ball is but one example of a plug.
With reference to
After a zone 8a has been fractured, further balls are successively introduced into the completion tubing to enable successive MFDs to be opened and fracturing operations to be completed within other zones. As a result, each of the zones of interest within the well 8 can be successively fractured. The balls may be designed such that over a period of time, typically a few days, the ball will at least partially dissolve such that its diameter is eroded and it will fall to the bottom of the well. Thus, after all fracturing operations have been completed all the zones of the well are then opened to the interior of the completion tubing to enable production of the well through the completion tubing.
The lowermost zone of the completion string may not require an MFD 10. A simple hydraulic valve that opens on pressure can be utilized at the lowermost zone (not shown) to initially establish circulation and to enable fracturing of the lowermost zone.
As shown in
The operation and components of each of the sub-systems is described in greater detail below where
As shown in
The action of the electronic counting system 12 engaging the electronically actuated solenoid 87 or electric motor (depending on the embodiment) will open a pathway for fluid being pumped downhole to actuate the valved ball capture sub-system 14. More particularly, the electronically actuated solenoid or electric motor will open a channel (as shown by element 86 in
In an embodiment, a further hydraulic channel can be configured such that it is contained within valve sleeve and allows hydraulic fluid to by-pass the valved ball capture system 14 to the ball release system 16.
The valved ball capture sub-system 14 includes a frac piston 62.
In one embodiment, the ball capture system 14 generally includes a collet ball seat 60 having collet ball seat fingers 60a. The collet ball seat 60 is operatively connected to frac piston 62.
As explained in greater detail below and shown in
In operation, as described above, the hydraulic fluid pressurizes pressure chamber 62a uphole of frac piston 62. Chamber pressurization causes shear pins 62b to shear, enabling downhole movement of the frac piston and the inward movement of the collet ball seat fingers 60a (
If a ball has not been captured within the ball capture system, maintaining or increasing the pressure within the tubing string does not enable the frac piston 62 to move and cause premature opening of hydraulic ports 67 in a zone where a ball has not been captured. More specifically, this is prevented in a non-triggered MFD because hydraulic fluid cannot flow into chamber 62a.
After a ball has been retained in the collet ball seat 60, increasing the pressure within the completion tubing will result in additional pressurization against the uphole surface of the frac piston 62. The frac piston is retained against the main outer housing 42 by shear pin(s) 62b. When a threshold pressure is exerted on frac piston 62, shear pin(s) 62b will shear, thereby allowing frac piston 62 to move in a downhole direction, thus causing the formation of a ball seat, as discussed above. Further downhole movement at that point is prevented by shear pin(s) 94b, as reflected in
As a result, as the electronic ball count system 12 causes activation of the ball capture system 14 at the correct pre-set number, a ball 18 is retained within the collet ball seat, thus sealing off positions downhole of the ball. At that point, due to the seal created by ball 18, pressure will increase uphole from the ball seat. Once that increasing pressure has reached a threshold level, shear pin(s) 94b will shear (as shown in
In an embodiment, the ball can be retained by alternate configurations of a collet ball seat other than that shown in the figures. For example, the collet ball seat can have more or less collet ball seat fingers than those that are shown configured. The fingers can also differ in shape, structure, and material makeup from those shown in the Figures.
In other embodiments, ball capture system 14 may use configurations other than collet fingers, as described above. For example, as shown in
The same concept could be embodied by virtually any mechanical structure that constricts its inner diameter as it moves axially downward through the inner bore of the MFD. Such structures could include a cylindrical metal tube that would buckle inward when compressed, possibly by cutting axial slots in the middle of the tube which would cause it to bias inward.
In other embodiments, the ball seat could be formed via rotation, rather than compression. For example, as shown in
Other rotational embodiments are certainly possible beyond that illustrated in
In an embodiment and as illustrated in
In an embodiment and as illustrated in
Upon completion of a fracturing operation within a particular zone and the partial relaxation of pressure, the process is repeated by dropping a further ball which based on the pre-set counter setting of the immediately adjacent uphole MFD 10 will capture the further ball at that uphole position. The process is repeated for each of the MFDs present in the completion tubing string.
After completion of the fracturing operations, it is important that the balls are all released to fall to the bottom of the well or flow to the surface, thus ensuring that the entire string is opened to the formation at all zones.
As known, the balls can be dissolvable such that over a period of few days, the outer surface of the ball will erode such that it will fall from the collet ball seat arms 60a.
The electronic counting system 12 will typically enable 1-40 or even more zones to be individually isolated for treatment. In order to ensure a proper pre-set number, as the completion tubing string is being assembled at surface, each MFD 10 will be set to trigger based on the intended MFD position in the well. That is, if the string includes 10 MFDs, the lowermost MFD will trigger with the first ball and uppermost MFD will trigger with the 10th ball. Thus, in an embodiment, each electronic counting system 12 will have its electronically actuated valve set to trigger on a pre-determined and pre-programmed ball count.
In an alternative embodiment, multiple MFDs can be configured to open at approximately the same time. This configuration may be referred to as a “cluster sleeve.” In a cluster sleeve configuration, one MFD is used that operates substantially as described above. This MFD may be referred as the lowermost MFD. Uphole from the lowermost MFD, one or more MFDs are used with certain variations from the structure and operation described above. These MFDs may be referred to as the modified MFDs. The modified MFDs do not include collet ball seat 60 (or collet ball seat fingers 60a). In one embodiment of a cluster sleeve configuration, the modified MFDs also do not include shear pin(s) 94b, or only a reduced number and/or strength of shear pin(s) 94b.
In a cluster sleeve configuration, the lowermost MFD and modified MFDs are set such that the electronic counting system 12 of each MFD is configured to be triggered by the same ball. For example, if the electronic counting system of the lowermost MFD is configured to be activated after the tenth ball has been counted, then the electronic counting systems of the modified MFDs will also be activated after they have counted the tenth ball.
Because the modified MFDs do not include collet ball seat 60, even after the electronic counting system has been activated, the ball will not be captured by any of the modified MFDs. Instead, the ball will continue downhole, where it will be captured by the lowermost MFD after being counted by the electronic counting system of the lowermost MFD. Once the ball is captured, the lowermost MFD will operate substantially as described above.
In the cluster sleeve configuration where the modified MFDs have no (or fewer and/or weaker) shear pin(s) 94b, even though a ball has not been captured, hydraulic ports 67 in the modified MFDs will open shortly after the electronic counting system 12 has been activated. This is due to the relative absence of shear pin(s) 94b within the modified MFDs.
In the cluster sleeve configuration where the modified MFDs do include approximately the same number and strength of shear pin(s) 94b as the lowermost MFD, hydraulic ports 67 in the modified MFDs will not open until a ball has been captured in the lowermost MFD and pressure has increased to the point that shear pin(s) 94b will shear. Thus, in this embodiment, hydraulic ports 67 would open in all of the MFDs—both the modified MFDs and the lowermost MFD—at approximately the same time.
In either embodiment of the cluster sleeve configuration, once the electronic counting system 12 within each MFD has counted the preset number of balls, the lowermost MFD has captured a ball, and the pressure within the lowermost MFD has increased the point that shear pin(s) 94b have been sheared and hydraulic ports 67 have been opened in the lowermost MFD, hydraulic ports 67 will be open in every MFD within the cluster sleeve configuration at the same time.
As a result, when pressure is further increased to the level desired for hydraulic fracturing operations, fluid will be discharged from hydraulic ports 67 of every MFD in the cluster sleeve configuration at approximately the same time. In this way, any number of different stages can be treated simultaneously. For example, if a cluster sleeve configuration included a lowermost MFD and three modified MFDs, four stages would be fractured at the same time.
In another embodiment as shown in
In an embodiment, and as shown in
In an embodiment, the electronic counting system 12 can be configured with only one counting pin or alternatively with a larger number of pins than two if desired. Multiple pins can be configured for more accurate counting or in the event that one or more pins are damaged, the other pins can then still determined a reliable count. Alternatively, as mentioned above, other sensors can be configured and a combination of sensors can be configured, including multiple of the same sensor when desired. The counts from the various sensor types and/or same sensor types can then be compared by the processor which can either use a voting system of comparison or another method depending on what program is optimal for a given downhole environment and system.
In an embodiment, the first and second pin are preferably out of phase (not in line) with each other along the inner bore, and preferably are phased at 180 degrees from each other. While the first and second pin may be in phase/in line with each other, having them out of phase provides more even wear on the balls as they pass by the pins and provides room in the tool for the biasing means and other parts related to the electronic counting system.
In an embodiment where two pins are configured,
In another embodiment, rather than first and second pins that are spaced axially apart, the electronic counting system utilizes two pairs of pins. For each pair, both pins are located at the same axial location along the inner bore of the main internal housing and, similar to the embodiment described above, the pairs of pins are axially spaced apart far enough to allow the first pair of pins to close after the ball has passed through before the second pair of pins is opened. The pins may also be circumferentially spaced apart around the inner bore of the main internal housing. For example, the first pair of pins may be located at 0° and 180° respectively, while the second pair may be located at 90° and 270°. Other similar embodiments are possible, including designs that use more than two pins at each axial location, pins located at more than two separate axial locations, or a different number of pins at one axial location versus another.
This alternative embodiment utilizing two pairs of pins is useful to reduce the likelihood that the electronic counting system will count objects other than balls or other devices designed to induce a count. For example, if coiled tubing is inserted into the well, an electronic counting system utilizing only a single pin at each axial location could inaccurately count the coiled tubing as a ball, in the event that the coiled tubing contacted the single pins, thus causing the first and second electrical circuits to open (or close). Utilizing pairs of pins as described in the preceding paragraph should ensure that the electronic counting system will only count balls or other specially designed tools or devices that have the same approximate diameter as the inner bore of the main internal housing.
When either the first or second electrical circuit open or close, a signal is passed (via wires or wirelessly) to a solenoid processor in the tool using electrical pins. In one embodiment, when a signal is passed to the processor that the first electrical circuit has opened then closed, followed shortly by the second electrical circuit opening and closing, the processor interprets this as a ball passing downhole. Alternatively, if the pins are biased in the open position, the signal to determine that a ball has passed downhole may be the first electrical circuit followed by the second electrical circuit closing then opening. The processor keeps a count number for the passing balls. Upon reaching a pre-determined count number, the processor signals a solenoid valve assembly to open, allowing fluid to enter a cavity, thereby setting the tool to capture a ball which, as with the non-electronic system described above, allows a valve in the MFD to be opened to allow fracturing operations to occur. The electronic counting system may include more than one solenoid valve assembly for redundancy and to enable the setting process to occur faster. It may be preferable to isolate the pins of the electronic counting system from the fluid that is used for hydraulic fracturing. For example, the pins may be located in an annular space that is filled with oil and isolated from the fracturing fluid using a diaphragm or other sealing device. Isolating the pins may avoid excessive current leakage if the pins are surrounded by the water that makes up a large portion of the fracturing fluid.
Referring to
The electronic counter system is not limited to a maximum number of ball counts and therefore has no limit on the number of fracturing stages that the MFD can be used for. The response time after a ball has passed the pins to the setting of the setting of the solenoid valve system can also be programmed as desired. This is particularly useful when it is desired to open more than one MFD with a single ball to simultaneously fracture more than one zone of interest. For example, the time between a ball passing an upper MFD and the setting of the upper MFD solenoid valve system can be delayed enough to allow the ball to pass through without being captured, after which the MFD is set. When the ball is captured by a lower MFD and pressure is applied downhole, both the upper and lower MFD will open, allowing fracturing to occur simultaneously in the zones adjacent both the upper and lower MFD.
Additionally, the electronic counter system can distinguish between a ball flowing downhole and ball flowing uphole. This is particularly useful when the direction of flow in a wellbore must be reversed due to a screen out (flow suddenly stopping in the wellbore) or the fracture failing to initiate. In both cases, the well is “opened up” and allowed to flow in the reverse direction back to the surface. After the desired amount of time, the flow direction is changed again to flow downhole in an attempt to start or restart the fracturing process. When flow is reversed, the balls often flow uphole with the fluid, passing the counting system in a reverse direction. The counting system will know a ball has moved uphole since the second pin will be triggered before the first pin. The processor may be programmed to not count an uphole flowing ball, or to count it as a negative. That is, when the ball moves downhole past the two pins it is counted as one, when the ball flows back uphole past the two pins, the count returns to zero, and when the ball moves back downhole past the two pins, it is again counted as one. This ensures that the count number is accurate despite the occurrence of reverse flow in the wellbore.
After setting the packers and prior to dropping a first ball for a MFD, well bore circulation may have to be established by increasing pressure (perhaps up to 3000 psi or more) to hydraulically shift open an annular communication device in the toe of the well. Once circulation is established, a series of balls may be dropped until one of them is captured by the MFD. Once a ball has been captured, pressure will increase until the hydraulic ports open, which may be in the range of 2500-4500 psi, depending on the shear pin configuration. Once the hydraulic ports in the MFD have opened, fracturing will typically occur in the range of 4000-10,000 psi.
Although the present invention has been described and illustrated with respect to preferred embodiments and preferred uses thereof, it is not to be so limited since modifications and changes can be made therein which are within the full, intended scope of the invention as understood by those skilled in the art.
| Number | Date | Country | |
|---|---|---|---|
| Parent | 15002532 | Jan 2016 | US |
| Child | 15668353 | US |
