Patent Grant
11795801
This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.
This disclosure relates generally to systems and methods for delivering an oilfield material (e.g., a slurry mixture, a diverting fluid, a fracturing fluid, a proppant, a proppant additive) to a well at a wellsite. Production of oil and gas from subterranean formations presents a myriad of challenges. One such challenge is the lack of permeability in certain formations. Often oil or gas-bearing formations, that may contain large quantities of oil or gas, do not produce at a desirable production rate due to low permeability. The low permeability may cause a poor flow rate of the sought-after hydrocarbons. To increase the flow rate, a stimulation treatment can be performed. One such stimulation treatment is hydraulic fracturing.
Hydraulic fracturing is a process whereby a subterranean hydrocarbon reservoir is stimulated to increase the permeability of the formation, thereby increasing the flow of hydrocarbons from the reservoir. Hydraulic fracturing includes pumping a fracturing fluid at a high pressure (e.g., in excess of 10,000 psi) to crack the formation and create larger passageways for hydrocarbon flow. The fracturing fluid may have proppants added thereto, such as sand or other solids that fill the cracks in the formation, so that, at the conclusion of the fracturing treatment, when the high pressure is released, the cracks remain propped open, thereby permitting the increased hydrocarbon flow possible through the produced cracks to continue into the wellbore.
To displace the fracturing fluid into the well, large wellsite operations generally employ a variety of positive displacement or other fluid delivering, large scale pumps. However, some fracturing fluids contain particles with diameters that may not easily pass through certain fracturing equipment (e.g., pumps). In some instances, these larger diameter particles contribute to premature wear and degradation of the fracturing equipment. In other instances, these large diameter particles may not be able to pass through fracturing equipment because clearances in the equipment are smaller than the particles. Moreover, maintaining and operating large-scale equipment capable of supplying the oil material having the large diameter particles may be cost prohibitive and less efficient to operate.
Various features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:
One or more specific embodiments of the present disclosure will be described below. These described embodiments are only exemplary of the various systems and methods described herein. Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification. It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another. Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.
The following definitions are provided in order to aid those skilled in the art in understanding the detailed description. The term “treatment”, or “treating”, refers to any subterranean operation that uses a fluid in conjunction with a desired function and/or for a desired purpose. The term “treatment” or “treating” does not imply any particular action by the fluid. The term “fracturing” refers to the process and methods of breaking down a geological formation and creating a fracture, i.e. the rock formation around a well bore, by pumping fluid at very high pressures (pressure above the determined closure pressure of the formation), in order to increase production rates from a hydrocarbon reservoir. The particular fracturing methods may include any suitable technologies.
The present disclosure relates to systems and methods for introducing an oilfield material, such as a slurry mixture, a diverting fluid, a fracturing fluid, proppant, or proppant additive, to a high-pressure side of a hydraulic well simulation system. The slurry mixture, diverting fluid, fracturing fluid, proppant, or proppant additive may contain larger particles (e.g., with a diameter size of greater than 5 mm), which may be injected into a dispensing device that is located between a missile trailer and a wellhead (e.g., a high-pressure injector line), or directly at the wellhead. The dispensing device holds the oilfield material in the device until it is displaced into a main treatment line or the wellbore, depending on where the dispensing device is disposed. For example, the dispensing device may be coupled to a frac-tree at the wellhead to provide the materials directly to the wellbore. Alternatively, the dispensing device may be disposed upstream of the wellhead.
The wellsite system enables remote operation of the dispensing device, thereby enabling multi-stage hydraulic fracturing operations. The dispensing device may utilize flow control elements (e.g., valves, pumps, etc.) and a control system to enable the dispensing device to dispense oilfield materials throughout the duration of a fracturing treatment. In one embodiment, the larger particle slurries may be provided to the dispensing device via a plurality of valves disposed along the dispensing device. The valves may be actuated to fill the dispensing device, store the oilfield materials in the dispensing device, and/or dispense the oilfield materials from the dispensing device. A control system may remotely control the dispensing device through several continuous multistage fracturing treatments. It may be appreciated that the disclosed embodiments of the dispensing device may be controlled remotely or at the wellsite 10. The dispensing device and the control system may be further understood with reference to
By way of introduction,
The treating lines 24 may be fluidly coupled to a dispensing device 26. The dispensing device 26 may be controlled by the control system 22. The dispensing device 26 may be used to dispense the oilfield material with a larger particle size (e.g., diameter size of greater than 5 mm), such as a slurry mixture, a diverting fluid, a fracturing fluid, proppant, or proppant additive, to the treating line 24 or to the wellhead 20. The dispensing device 26 may include a high-pressure inlet that is fluidly coupled to the pump unit trailers 16. The dispensing device 26 may also include a pressure outlet that is fluidly coupled to the treating line 24 and/or the wellhead 20. As described above, the dispensing device 26 may be disposed at a location between the manifold (e.g., missile) trailer 18 and/or the battery of pump unit trailers 16 and the wellhead 20.
The control system 22 includes a memory 28 and a processor 30. The memory 28 may store program instructions that are loadable and executable on the processor(s) 30, as well as data generated during the execution of these programs. Depending on the configuration and type of the control system 22, the memory 28 may be volatile (such as random access memory (RAM)) and/or non-volatile (such as read-only memory (ROM), flash memory, etc.). The computing device or server may also include additional removable storage and/or non-removable storage including, but not limited to, magnetic storage, optical disks, and/or tape storage. The disk drives and their associated computer-readable media may provide non-volatile storage of computer-readable instructions, data structures, program modules, and other data for the computing devices. In some implementations, the memory 28 may include multiple different types of memory, such as static random access memory (SRAM), dynamic random access memory (DRAM), or ROM.
To control the actuation of the flow control elements, the control system 22 may receive signals from one or more sensors 27 disposed throughout the wellsite system 10. For example, the wellsite system 10 may include sensors 27 that measure a line pressure (e.g., treating line pressure, injector line pressure), flow sensors (e.g., to measure flow rate of the slurry mixture), displacement sensors (e.g., to sense a valve position), level sensors (e.g., to measure a storage tank level), concentration sensors (e.g., to measure a proppant concentration of the slurry mixture), or other suitable sensors. It may be appreciated that one or more of the sensors 27 may function as transducer (e.g., to receive a signal and retransmit in a different form). Other sensors 27 may output data indicative of operating conditions throughout the wellsite 10. The sensors 27 may output data to the control system 22 to adjust operation of the various embodiments of the dispensing devices 26, as explained in further detail below with reference to
After the material chamber 32 is filled with the oilfield materials, the oilfield materials are moved through the material chamber 32 via introducing a high-pressure fluid (e.g., a sand/water mixture to the material chamber 32). The material chamber 32 includes an inlet 36 (e.g., a high pressure inlet from a pump truck) and an outlet 38 (e.g., a high pressure outlet to the main treating line 24). The material chamber 32 uses one or more isolation devices (e.g., valves 40, gate valves) to fill the material chamber 32 with a high pressure fluid (e.g., a sand/water mixture) from the high pressure inlet 36 to move the oilfield materials from the inlet 36 to the outlet 38 of the material chamber 32.
The valves 40 may be manually operated or remotely controlled via the control system 22. For example, the control system 22 may receive one or more signals from the position sensors 27, which are communicatively coupled to the valves 40. For example, the control system 22 may control actuation of the valves 40 to control the rate at which the oilfield materials (e.g., the slurry mixture 34) are introduced to the material chamber 32. In some embodiments, the rate at which the oilfield materials are introduced to the material chamber 32 may vary based at least in part on a stage of fracturing operations (e.g., a first stage of a multi-stage fracturing operation).
The control system 22 may be used to control the amount of oilfield materials that fill the material chamber 32. For example, the control system 22 may fill the material chamber 32 to a desired volume through the material chamber fill line 41 by opening the inlet valve 42 (e.g., a gate valve). The control system 22 may control the flow rate at which the material chamber 32 is filled by controlling the level, which the inlet valve 42 is opened. Once the desired volume of the oilfield material has filled the material chamber 32, the control system 22 may close the inlet valve 42. The control system 22 may then receive an indication (e.g., a signal) that a desired process condition (e.g., a pressure reading associated with the material chamber 32, concentration of the proppant, etc.) is met. The control system 22 may also open a relief valve to enable the pressure in the material chamber 32 to vent to the atmosphere. The control system 22 may then open the isolation devices (e.g., valves 40) associated with the inlet 36 and the outlet 38 to enable the high-pressure fluid (e.g., a sand/water mixture) to be pumped into the material chamber 32. As described above, the oilfield material may be pumped into the main lines 24 and/or into the wellbore at the wellhead 20.
The valves 40 may be manually operated or remotely controlled via the control system 22. As described above, the control system 22 may receive one or more signals from the position sensors 27 which are communicatively coupled to the valves 40. The oilfield materials (e.g., the slurry mixture 34) may be stored in a middle portion 60 of the fill line 50 until the oilfield materials are ready to be provided to the wellbore. For example, when both a forward valve 42 (e.g., plug valve) and a rear valve 44 (e.g., plug valve) are open, the oilfield materials may be directed from the fill line 50 in a direction (as indicated by arrows 62) to the wellhead 20. It may be appreciated that the valves 40 (e.g., the forward valve 42, the rear valve 44) may be remotely or manually controlled to flush and/or clean the fill line 50.
As described with reference to
The one or more material fill lines 76 may include an inlet 72 to receive the oilfield materials (e.g., the slurry mixture 34). The material chamber 32 receives the oilfield materials (e.g., the slurry mixture 34) from the one or more material fill lines 76, which are fluidly coupled to the material chamber 32 and store the oilfield materials until they are released to the material chamber 32. The flow of oilfield materials (e.g., the slurry mixture 34) to the material chamber 32 may be controlled via one or more isolation devices (e.g., one or more gate valves 78).
The gate valves 78 associated with the material fill line (e.g., 78a, 78b) may control the flow of the oilfield materials (e.g., the slurry mixture 34) from the material fill line 76 to the material chamber 32. As described above with reference to
The material chamber 32 also includes an inlet 73 (e.g., a high pressure inlet from a pump truck) and an outlet 74 (e.g., a high-pressure outlet to the main treating line 24). After the material chamber 32 is filled with the oilfield materials, the oilfield materials are moved through the material chamber 32 via the high-pressure fluid (e.g., a sand/water mixture). The flow of the high-pressure fluid may be controlled via actuation of the valves 78c, 78d that are associated with the material chamber 32. The material chamber 32 may use a material chamber overflow line 75 that is fluidly coupled to the material chamber 32. In some embodiments, the material chamber overflow line 75 may reduce the amount of high pressure fluid in the material chamber 32, to reduce the concentration of proppant in the slurry mixture 34, and so forth.
The control system 22 may fill the material chamber fill line 76 to a desired volume through the material chamber fill line 76 by opening the inlet valve 78a, 78b (e.g., gate valves). The control system 22 may control the flow rate at which the material chamber fill line 76 is filled by controlling the level which the valves 78a, 78b are opened. Once the desired volume of the oilfield material (e.g., slurry mixture 34) has filled the material chamber fill line 76, the control system 22 may close the gate valves 78a, 78b. The control system 22 may then receive an indication (e.g., a signal) that a desired process condition (e.g., a pressure reading associated with the material chamber fill line 76, concentration of the proppant, etc.) is met. The control system 22 may then open the isolation devices (e.g., valves 78c, 78d) associated with the inlet 73 and the outlet 74 and the material chamber 32 to enable the high pressure fluid (e.g., a sand/water mixture) to be pumped into the material chamber 32. As described above, the oilfield material may be pumped into the main lines 24 and/or into the wellbore at the wellhead 20.
The amount of the slurry mixture 34 that may be pumped into the vertical material chamber 82 may range from approximately 1 gallon to over 20 gallons of fluid. The oilfield materials may be loaded into the vertical material chamber 82 via a material chamber fill line 86. The oilfield materials (e.g., the slurry mixture 34) may be pumped into the material chamber fill line 86. The material chamber fill line 86 may include an inlet 91 and a material chamber overflow line 93. As may be appreciated, the material chamber overflow line 93 may be used to adjust the amount of oilfield materials that are filled into the material chamber line 86. The flow of the oilfield materials (e.g., the slurry mixture 34) may be controlled via one or more gate valves 94 associated with the material chamber fill line 86.
After the material fill chamber 86 is filled with the oilfield materials (e.g., the slurry mixture 34), the control system 22 may close the valve 94 associated with the material fill chamber 86 and the vertical material chamber 82 is filled with the oilfield materials. It may be appreciated that the vertical material chamber 82 may be filled in part via gravitational forces, air, and/or a liquid. The vertical material chamber 82 includes a high-pressure inlet 88 to fluidly couple to a pump unit trailer 16 and a high-pressure outlet 92 that is fluidly coupled to the main line 24 and/or at the wellhead 20.
The control system 22 may control actuation of the valves 94 to control the rate at which the oilfield materials (e.g., the slurry mixture 34) are introduced to the vertical material chamber 82 and/or the material fill chamber 86. For example, the control system 22 may open the valve 94 associated with the high-pressure inlet 88 and the high-pressure outlet 92 to introduce the high-pressure fluid material (e.g., the sand/water mixture) into the vertical chamber 82. Introducing the high-pressure fluid may push the oilfield materials through the vertical material chamber 82 along a flow path 90. The oilfield materials are then pumped from the vertical material chamber 82 through the high-pressure outlet 92. The high-pressure outlet 92 may be fluidly coupled to the main line 24 or to a location at the wellhead 20 to flow the oilfield materials into the wellbore.
As may be appreciated, the control system 22 may fill the vertical material chamber 82 to a desired volume through the material fill chamber 86. The control system 22 may control the flow rate at which the vertical material chamber 82 is filled by controlling the level, which the gate valve 94 is opened. Once the desired volume of the oilfield material (e.g., slurry mixture 34) has filled the vertical material chamber 82, the control system 22 may close the gate valve 94 associated with the vertical material chamber 82. The control system 22 may then receive an indication (e.g., a signal) that a desired process condition (e.g., a pressure reading associated with the material chamber 32, concentration of the proppant, etc.) is met. The control system 22 may then open the isolation devices (e.g., valves 94) associated with the inlet 88 and the outlet 92 to enable the high pressure fluid (e.g., a sand/water mixture) to be pumped into the material chamber 32 to push the oilfield materials along the flow path 90.
The piston rod 100 may be moved in a first direction 106 to introduce (e.g., via suction) the oilfield materials to the material chamber 96 from the storage tank 104. It may be appreciated that moving the piston rod 100 in a second direction 108 opposite the first direction may push the oilfield materials out of the material chamber 96 via an outlet 109 that is fluidly coupled to the main line 24 and/or at a location near the wellhead 20. The distance the piston rod 100 is moved in the direction 108 may be determined in part by a position sensor 27 that is coupled to the piston rod 100. The sensors 27 may also be used to measure the amount of oilfield materials, which are introduced to the material chamber 96.
The piston assembly 98 may be manually operated or remotely controlled via the control system 22. The control system 22 may control actuation of the valves 110 and/or components of the piston assembly 98. The control system 22 may control the flow rate at which the material chamber 96 is filled by controlling the level which the valves 110 associated with the piston assembly 98, including the inlet 99, are opened. Once the desired volume of the oilfield material (e.g., slurry mixture 34) has filled the material chamber 96, the control system 22 may close one or more of the valves 110 associated with the inlet 99 to stop the flow of the oilfield materials into the material chamber 96. The control system 22 may then receive an indication (e.g., a signal) that a desired process condition (e.g., a volume reading associated with the material chamber 96, concentration of the proppant, etc.) is met. The control system 22 may then actuate the piston rod 100 within the cylinder 102 in the direction 108 to push the oilfield materials from the material chamber 96 to the main flow line 24 or to the wellbore via a location at the wellhead 20.
The control system 22 may control the valves 110 associated with the material chamber 113 and/or the actuation of the dart 114 within the material chamber 112. The control system 22 may fill the material chamber 112 to a desired volume through the fill line 116 by opening the valve 110 associated with the fill line 116. The control system 22 may control the flow rate and/or the volume of the material to the material chamber 112. As the material chamber 112 fills with the oilfield materials, the control system 22 may control the movement of the dart 114. The control system 22 may move the dart towards the inlet 118 of the material chamber 112. Once the control system 22 receives an indication (e.g., a signal) that a desired process condition (e.g., a pressure reading associated with the material chamber 112) is met, then the control system 22 may open the valve 110 associated with the inlet 118 to enable the flow of the high pressure fluid (e.g., the sand/water mixture) into the material chamber 112. The control system 22 may also open the valve 110 associated with the outlet 122 to enable the flow of the oilfield materials out of the material chamber 112. As described above, the control system 22 may control the actuation of the dart 114 to move the dart along the material chamber 112 towards the outlet 122. The oilfield materials may be pumped into the main lines 24 and/or into the wellbore at the wellhead 20.
The balls 134 may be made of a soluble material (e.g., polyvinyl alcohol, etc.) to store the oilfield materials. The soluble material of the balls 134 may be dissolved when the balls 134 are released into the flow path indicated by arrows 136. The balls 134 may be retained in the ball launcher until the balls 134 are released via a trigger (e.g., a time-delay trigger, a desired concentration, etc.). The soluble materials the balls 134 are made of may dissolve when the balls 134 come into contact with the high-pressure fluid (e.g., sand/water), thereby releasing the oilfield materials to the main line 24 and/or the wellbore. That is, the high-pressure fluid introduced via a high pressure inlet 138 may flow towards a high-pressure outlet 140 to dissolve an outer coating of the balls 134, which are made from the soluble materials so that the oilfield materials (e.g., the slurry mixture 34) can be released into the wellbore.
When the trigger is activated, the control system 22 may release one or more of the balls 134 from the ball launcher 130 to the outlet 127. The control system 22 may receive an indication (e.g., a signal) that the trigger is activated. The control system 22 may determine the number of balls 134 to be released, the desired concentration of oilfield materials (e.g., slurry mixture 34) to be met, an amount of time to release the balls 134, and so forth. The control system 22 may then release the balls 134 from the ball launcher 130 by actuating one or more cams 142 associated with the balls 134 in a direction 144 towards the outlet 127. The control system 22 then deploys the balls 134 along the flow path indicated by the arrows 136. The control system 22 may monitor one or more process conditions (e.g., the amount of time the balls 134 are deployed, the amount of soluble materials released from the balls 134, etc.) until the desired condition is met, at which point the control system 22 may stop the deployment of the balls 134 from the ball launcher 130. The control system 22 may monitor the process conditions until more oilfield materials are to be released into the main line 24 and/or the wellbore.
The screw mechanism 150 includes a plurality of threads 154 and a base unit 156. The screw mechanism 150 may include one or more material loading inlets 162. The material inlets 162 may receive oilfield materials, which can be stored in a material chamber 158 until they are driven from the material chamber 158 via an electric motor 164. The electric motor 164 moves the threads 154 through the material chamber 158 to push the oilfield materials through the material chamber 158.
The control system 22 may control the flow of the oilfield materials (e.g., the flow rate of the oilfield materials, the amount of the oilfield materials) through the material inlets 162 and/or the operation of the screw mechanism 150. The control system 22 may open the material loading inlets 162 to fill the material chamber 158 with the oilfield materials. The control system 22 may receive an indication (e.g., a signal) that a trigger to release the oilfield materials is activated. The control system 22 may determine the amount of the oilfield materials to be released, such as by determining the desired concentration of oilfield materials (e.g., slurry mixture 34) to be met or an amount of time to release the oilfield materials. The control system 22 may then activate the motor 164 to drive the threads 154 of the screw mechanism 150. The oilfield materials are then moved from the material chamber 158 and come into contact with the high-pressure fluid (e.g., sand/water mixture). The control system 22 then deploys the materials along the flow path indicated by the arrows 160. The control system 22 may monitor one or more process conditions (e.g., the amount of soluble materials released from the material chamber 158, etc.) until the desired condition is met, at which point the control system 22 may stop the motor 164 so that the oilfield materials are suspended in the material chamber 158. The control system 22 may monitor the process conditions until more of the oilfield materials are to be released into the main line 24 and/or the wellbore and begin operating the screw mechanism 150 again.
In some embodiments, the dispensing device 26 may include a plurality of the screw mechanisms 150 disposed around a central borehole allowing various oilfield materials (e.g., proppant, diversion material, fibers, etc.) to be driven into the wellbore. The various screw mechanisms 150 may introduce different amounts of the oilfield materials to create a desired composition to be dispersed into the wellbore. In other words, the dispensing device 26 (e.g., the screw mechanism 150) enables the oilfield materials to be blended directly at the wellhead 20 or the main line 24. It may be appreciated that the screw mechanisms 150 may be disposed upstream from the wellbore along the main line or be coupled to a frac-tree, as described further with reference to
The screw mechanism 150 includes the high-pressure inlet 170 to receive high-pressure fluid material (e.g., sand/water mixture), which may push the oilfield materials from the inlet 170 along a flow path indicated by arrow 172 to an outlet 174. The outlet 174 may be directly coupled to the wellhead 20 to flow the oilfield materials into the wellbore.
As described above with reference to
The control system 22 may control the flow of the oilfield materials (e.g., the composition of the oilfield materials that are blended together, the flow rate of the oilfield materials, the amount of the oilfield materials) through the material inlets 162 and/or the operation of the screw mechanism 150. The control system 22 may open the material loading inlets 162 to fill the material chamber 158 with the oilfield materials. The control system 22 may receive an indication (e.g., a signal) that a trigger to release the oilfield materials is activated. The control system 22 may determine the amount of the oilfield materials to be released, such as by determining the desired composition of oilfield materials (e.g., slurry mixture 34). The control system 22 may then activate the motor 164 to drive the threads 154 of the screw mechanism 150. Each of the oilfield materials are then dispensed from their respective material chambers 158 to form the oilfield materials of the desired composition. The oilfield materials then come into contact with the high-pressure fluid (e.g., sand/water mixture). The control system 22 then deploys the materials along the flow path indicated by the arrows 174. The control system 22 may monitor one or more process conditions (e.g., the amount of soluble materials released from the material chamber 158, etc.) until the desired condition is met, at which point the control system 22 may stop the motor 164 so that the oilfield materials are suspended in the material chamber 158. The control system 22 may monitor the process conditions until more of the oilfield materials are to be released into the main line 24 and/or the wellbore and begin operating the screw mechanism 150 again.
At the outlet 109 of the piston assembly 98, the high-pressure inlet 170 receives the oilfield materials dispensed from the piston assembly 98. The high-pressure inlet 170 introduces high-pressure fluid material through the inlet and along the 172 flow path to the outlet 174. As described above, the outlet 174 may be directly coupled to the wellhead 20 to introduce the oilfield materials into the wellbore.
As may be appreciated, the control system 22 may be used to control the volume of the oilfield materials introduced to the piston assembly 98, as described above with reference to
At the outlet 122 of the dispensing device 26 (e.g., the material chamber 112 and the dart 114), the high-pressure inlet 170 receives the oilfield materials dispensed from the material chamber 112. The high-pressure inlet 170 introduces high-pressure fluid material through the inlet and along the 172 flow path to the outlet 174. As described above, the outlet 174 may be directly coupled to the wellhead 20 to introduce the oilfield materials into the wellbore.
As may be appreciated, the control system 22 may be used to control the actuation of the dart 114 thereby controlling the volume of the oilfield materials introduced to the material chamber 112, as described above with reference to
While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein. However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.
The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical. Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ” or “step for [perform]ing [a function] . . . ”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f). However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).
This application is Divisional of U.S. application Ser. No. 15/834,866 filed Dec. 7, 2017 which claims priority to and benefit from U.S. Provisional Application No. 62/432,301, filed Dec. 9, 2016, the contents of which are incorporated by reference in their entirety.
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| Number | Date | Country | |
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| 20210340851 A1 | Nov 2021 | US |
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| Number | Date | Country | |
|---|---|---|---|
| Parent | 15834866 | Dec 2017 | US |
| Child | 17326408 | US |
