CROSS-REFERENCE TO RELATED PATENT APPLICATIONS

[0001] This application claims the benefit of priority of U.S. Provisional Patent Application No. 62/150,725 to Edward Peter Kenneth Bourgeau et al., filed on April 21, 2015, and entitled "Motion Compensation for Drill Pipe," which is hereby incorporated by reference.

TECHNICAL FIELD

[0002] This disclosure is related to methods and systems for performing drill pipe motion compensation. More specifically, this disclosure is related to methods and systems for performing drill pipe motion compensation with marine riser tensioning systems.

BACKGROUND

[0003] Drill pipes used in offshore drilling operations are often tested for numerous reasons. For example, after a well is drilled and cased, a drill pipe may be tested as part of a Drill Stem Test (DST) to examine the pressure, permeability, and the productive capability of the formation. The test also helps to determine if a well has found a commercially viable hydrocarbon reservoir. During a DST, the connected drill pipe and/or tubing connected to the drill pipe must remain stationary with respect to the well. Because the rig or vessel supporting the drill pipe is floating, there is a need to compensate for the motion of the vessel in the load path supporting the drill string. A DST can take many months to complete and the compensation system must operate reliably for the duration of the test. Failure of the compensation system can damage equipment, lead to activation of emergency counter measures, and require a restart of the DST, which takes considerable time.

[0004] Conventionally, several techniques are used in industry to compensate for vessel motion, all of them involving a dedicated compensation system in the load path supporting the drill string. One conventional technique includes using the drawworks to take up and pay out the cable supporting the drill pipe or tubing in synchronism with the vessel movement. This technique is often called active compensation, as it actively uses electrical power to move the drawworks. Another conventional technique includes using hydraulic pistons pressured by a large gas reservoir that maintains constant tension on the drill pipe or tubing. This system, often called a drill string compensator, is mounted onto the derrick and is supported by the drawworks travelling block. Yet another conventional technique includes using hydraulic pistons pressured by a large gas reservoir in a special frame designed specifically to support the tubing used during the DST. This technique is called a Compensating Coil Tubing Lift Frame (CCTLF).

[0005] Numerous drawback are associated with the aforementioned conventional techniques. For example, in the active compensation technique and the drill string compensator technique, because the drawworks is used to implement the compensation system, the drawworks may affect the DST. In addition, in the CCTLF technique, a special frame must be mounted on the vessel to implement the compensation system. BRIEF SUMMARY

[0006] Drill pipe motion compensation may be performed without the inherent drawbacks of conventional motion compensation systems by supporting the weight of a drill pipe with a marine riser pipe and compensating for motion on the drill pipe by controlling tension on one or more of a plurality of wires coupled to the marine riser pipe. Specifically, according to one embodiment, a method for performing drill pipe motion compensation includes supporting the weight of a drill pipe with a marine riser pipe. According to an embodiment, the marine riser pipe may be coupled to a well head on the seabed. In some embodiments, supporting the weight of the drill pipe with the marine riser pipe may include suspending the drill pipe on the marine riser pipe with a pipe holder. Supporting the weight of the drill pipe with the marine riser pipe may also include transferring the weight of the drill pipe to the marine riser pipe. According to an embodiment, transferring the weight of the drill pipe to the marine riser pipe comprises mechanically coupling to the pipe holder and the marine riser pipe a drill pipe support system, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe.

[0007] The method may also include compensating for motion on the drill pipe by controlling tension on one or more of a plurality of wires coupled to the marine riser pipe. In some embodiments, controlling the tension on the one or more of the plurality of wires may include maintaining constant the tension on the one or more of the plurality of wires.

[0008] In some embodiments, the method may also include sensing signals that are indicative of a load on the drill pipe or tension on one or more of the plurality of wires. According to an embodiment, controlling the tension on one or more of a plurality of wires may include adjusting the tension on one or more of the plurality of wires in response to the sensing of the signals.

[0009] According to an embodiment, the method may also include configuring the plurality of wires to collectively hold the weight of both the marine riser pipe and the drill pipe. In addition, in an embodiment, for each of the one or more of the plurality of wires, the tension may be controlled by one of a hydro-pneumatic tensioner and an electrical tensioner. In some embodiments, the method may also include coupling to the drill pipe a flexible tube, wherein the flexible tube flexes to accommodate for vessel movement and to reduce the amount of movement experienced by the drill pipe as compared to the vessel movement.

[0010] According to another embodiment, an apparatus includes: a drill pipe; a marine riser pipe configured to support the weight of the drill pipe; a plurality of wires coupled to the marine riser pipe; and one or more tensioners configured to compensate for motion on the drill pipe by controlling tension on one or more of the plurality of wires coupled to the marine riser pipe. The apparatus may also include a pipe holder configured to suspend the drill pipe on the marine riser pipe, wherein suspending the drill pipe on the marine riser pipe causes the marine riser pipe to support the weight of the drill pipe. The apparatus may further include a drill pipe support system coupled to the pipe holder and to the marine riser pipe, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe. According to an embodiment, controlling the tension on the one or more of the plurality of wires includes maintaining constant the tension on the one or more of the plurality of wires.

[0011] In some embodiments, the apparatus also includes one or more sensors coupled to the marine riser pipe and configured to sense signals that are indicative of a load on the drill pipe or tension on one or more of the plurality of wires. In one embodiment, the one or more sensors include at least one of an accelerometer and a load cell. The tensioners may be configured to adjust the tension on one or more of the plurality of wires in response to the sensing of the signals. According to an embodiment, each of the one or more tensioners may be one of a hydro- pneumatic tensioner and an electrical tensioner. In another embodiment, the plurality of wires are configured to collectively hold the weight of both the marine riser pipe and the drill pipe, and wherein the marine riser pipe is coupled to a well head on the seabed. According to some embodiments, the apparatus also includes a flexible tube coupled to the drill pipe, wherein the flexible tube is configured to flex to accommodate for vessel movement and to reduce the amount of movement experienced by the drill pipe as compared to the vessel movement. [0012] According to yet another embodiment, an apparatus includes a pipe holder coupled to a drill pipe and a marine riser pipe. The pipe holder may be configured to suspend the drill pipe on the marine riser pipe. The apparatus also includes a drill pipe support system coupled to the pipe holder and to the marine riser pipe, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe.

[0013] As used in this disclosure, the term "blowout preventer" includes, but is not limited to, a single blowout preventer, as well as a blowout preventer assembly that may include more than one blowout preventer (e.g., a blowout preventer stack).

[0014] The term "coupled" is defined as connected, although not necessarily directly, and not necessarily mechanically; two items that are "coupled" may be unitary with each other. The terms "a" and "an" are defined as one or more unless this disclosure explicitly requires otherwise. The term "substantially" is defined as largely but not necessarily wholly what is specified (and includes what is specified; e.g., substantially 90 degrees includes 90 degrees and substantially parallel includes parallel), as understood by a person of ordinary skill in the art. In any disclosed embodiment, the terms "substantially," "approximately," and "about" may be substituted with "within [a percentage] of what is specified, where the percentage includes .1, 1, 5, 10, and 20 percent.

[0015] Further, a device or system that is configured in a certain way is configured in at least that way, but it can also be configured in other ways than those specifically described.

[0016] The terms "comprise" (and any form of comprise, such as "comprises" and "comprising"), "have" (and any form of have, such as "has" and "having"), "include" (and any form of include, such as "includes" and "including"), and "contain" (and any form of contain, such as "contains" and "containing") are open-ended linking verbs. As a result, an apparatus that "comprises," "has," "includes," or "contains" one or more elements possesses those one or more elements, but is not limited to possessing only those elements. Likewise, a method that "comprises," "has," "includes," or "contains" one or more steps possesses those one or more steps, but is not limited to possessing only those one or more steps. [0017] The foregoing has outlined rather broadly certain features and technical advantages of embodiments of the present invention in order that the detailed description that follows may be better understood. Additional features and advantages will be described hereinafter that form the subject of the claims of the invention. It should be appreciated by those having ordinary skill in the art that the conception and specific embodiment disclosed may be readily utilized as a basis for modifying or designing other structures for carrying out the same or similar purposes. It should also be realized by those having ordinary skill in the art that such equivalent constructions do not depart from the spirit and scope of the invention as set forth in the appended claims. Additional features will be better understood from the following description when considered in connection with the accompanying figures. It is to be expressly understood, however, that each of the figures is provided for the purpose of illustration and description only and is not intended to limit the present invention.

BRIEF DESCRIPTION OF THE DRAWINGS

[0018] For a more complete understanding of the disclosed systems and methods, reference is now made to the following descriptions taken in conjunction with the accompanying drawings. In the appended figures, similar components or features may have the same reference label. Further, various components of the same type may be distinguished by following the reference label with a second label that distinguishes among the similar components. If just the first reference label is used in the specification, the description is applicable to any one or more of the similar components having the same first reference label irrespective of the second reference label.

[0019] FIG. 1A is a block diagram illustrating a drill pipe motion compensation system according to one embodiment of the disclosure.

[0020] FIG. IB is a block diagram illustrating a first side view of the drill pipe motion compensation system illustrated in FIG. 1A according to one embodiment of the disclosure.

[0021] FIG. 1C is a block diagram illustrating a second side view of the drill pipe motion compensation system illustrated in FIG. 1A according to one embodiment of the disclosure.

[0022] FIG. 2 is a flow chart illustrating a method for performing drill pipe motion compensation according to one embodiment of the disclosure.

DETAILED DESCRIPTION

[0023] A drill pipe motion compensation system may be configured to support the weight of the drill pipe on a marine riser pipe that is fixed to the seabed on the lower end and fixed to a rig/vessel, on the upper end, via a system that compensates for vessel motion, such as a marine riser tensioning system or marine riser system. The vessel motion compensation system of the drill pipe motion compensation system that compensates for motion with respect to the marine riser pipe, and the drill pipe supported by the marine riser pipe, may be configured to control tension on one or more of a plurality of wires coupled to the marine riser pipe. The drill pipe motion compensation system disclosed herein may exhibit numerous advantages over conventional drill pipe motion compensation systems. For example, the drill pipe motion compensation system disclosed herein may place the load of the drill string at a lower center of gravity, thus improving vessel stability. In addition, because the drill pipe is suspended on the marine riser, the drill pipe motion compensation system disclosed herein may leave the drawworks available to manage other activities, such as making up pipe or other inventory control matters. Moreover, the drill pipe motion compensation system disclosed herein may use a reliable and existing compensating system that is in continuous duty while drilling.

[0024] FIG. 1A is a block diagram illustrating a drill pipe motion compensation system according to one embodiment of the disclosure. FIGS. IB and 1C provide side views of the drill pipe motion compensation system illustrated in FIG. 1A. A drill pipe motion compensation system 100 may include a drill pipe 102 and a marine riser pipe 104. As used herein, a pipe may refer to a single pipe or a string of pipes coupled together, for example, a string of pipes coupled together to function as a single pipe.

[0025] Marine riser pipe 104 may be configured to support the weight of drill pipe 102. For example, system 100 may include a pipe holder 106 and a drill pipe support system 114 to aid marine riser pipe 104 to support the weight of drill pipe 102. As shown in FIG. 1A, drill pipe 102 may be inserted within pipe holder 106. According to an embodiment, pipe holder 106 may be configured to suspend drill pipe 102 on marine riser pipe 104. Suspension of drill pipe 102 on marine riser pipe 104 by pipe holder 106 may cause marine riser pipe 104 to support the weight of drill pipe 102. Additionally, configuring pipe holder 106 to suspend drill pipe 102 on marine riser pipe 104 may also configure pipe holder 106 to couple drill pipe 102 on marine riser pipe 104 so as to maintain drill pipe 102 substantially stationary with respect to a well head 180 on the seabed 190. In particular, because marine riser pipe 104 is maintained substantially stationary with respect to well head 180, suspending drill pipe 102 on marine riser pipe 104 causes drill pipe 102 to also be maintained substantially stationary with respect to well head 180. Although pipe holder 106 is illustrated as a cylindrical pipe horizontally enclosing drill pipe 102, one of skill in the art will readily recognize that pipe holder 106 may be any shape so long as it performs all the functions of pipe holder 106 as described in this disclosure.

[0026] Drill pipe support system 114 may provide additional support for pipe holder 106 as it suspends drill pipe 102 on marine riser pipe 104. Drill pipe support system 114 may also aid in the transfer of the weight of the drill pipe 102 to marine riser pipe 104. In one embodiment, such as the embodiment illustrated in FIG. 1, drill pipe support system 114 may include beams 114A-114D. However, one of skill in the art will readily recognize that drill pipe support system 114 may be implemented with other support systems other than a beam support system and that the invention as described in the appended claims is not limited to a beam support system so long as the support systems, whether directly or indirectly, support the operations of the drill pipe support system as described herein.

[0027] Drill pipe support system may be mechanically coupled to pipe holder 106 and marine riser pipe 104. For example, in one embodiment, such as the embodiment illustrated in FIG. 1, beams 114A-114D may be mechanically coupled to pipe holder 106 and marine riser pipe 104. In one embodiment, beam supports 114A-114D may be coupled directly to marine riser pipe 104. In another embodiment, beam supports 114A-114D may be coupled to marine riser pipe 104 by coupling to tension ring 116 coupled to the marine riser pipe 104.

[0028] Drill pipe support system 114 may be configured to, along with pipe holder 106, transfer the weight of drill pipe 102 to marine riser pipe 104. For example, as shown in the embodiment illustrated in FIG. 1, beam supports 114A-114D may be configured to, along with pipe holder 106, transfer the weight of drill pipe 102 to marine riser pipe 104. In one embodiment, when drill pipe 102 is lowered through pipe holder 106, pipe holder 106 and beams 114A-114D that are connected to marine riser pipe 104 may transfer the load from drill pipe 102 being supported by pipe holder 106 and beams 114A-114D to marine riser pipe 104. The load of both the marine riser pipe 104 and the supported drill pipe 102 may then be transferred from the marine riser pipe 104 to the vessel via tension ring 116 that is coupled to the marine riser pipe 104 and to tensioning wires 108A-108D that are connected to the vessel via tensioners 110A-110D. For example, as illustrated in FIG. 1, tension ring 116 may be coupled to marine riser pipe 104 and include a plurality of wire hooks 120A-120D. In some embodiments, tension ring 116 may be a ring-shaped load bearing device coupled to marine riser pipe 104. By coupling the plurality of wires 108A-108D to the plurality of wire hooks 120A-120D on tension ring 116, the weight of both the drill pipe 102 and the marine riser pipe 104 may be transferred, via the plurality of wires 108A-108D, to the vessel structure on which tensioners 110 are located.

[0029] System 100 also includes a plurality of wires 108A-108D coupled to marine riser pipe 104, and one or more tensioners 110A-110D. As illustrated in FIG. 1, the plurality of wires 108A-108D may couple to marine riser pipe 104 by coupling to tension ring 116, which is coupled to marine riser pipe 104. For example, tension ring 116 that is coupled to marine riser pipe 104 may include a plurality of wire hooks 120A-120D. Each of the plurality of wires 108A-108D may then couple to marine riser pipe 104 by coupling to at least one of the plurality of wire hooks 120A-120D. As illustrated in FIG. 1, the plurality of wires 108 may couple from the one or more tensioners 110 to the plurality of wire hooks 120 via turn-down sheaves 170. Specifically, the plurality of wires 108A-108D may couple from tensioners 110A-110D, over turn-down sheaves 170A-170D, to wire hooks 120A-120D. In some embodiments, the turn-down sheaves 170A-170D may be coupled to a vessel structure 112 that is coupled to a vessel on which the tensioners 110A- 110D are located.

[0030] According to some embodiments, the plurality of wires 108 may be configured to collectively hold and support the weight of both the marine riser pipe 104 and the drill pipe 102 and to maintain and vary tension in the marine riser pipe 104. In addition, each one of the plurality of wires 108 may be mechanically coupled to a distinct tensioner 110. Each of the one or more tensioners 110 may be coupled to a vessel structure 112. Vessel structure 112 may be a structure that is fixed to a vessel on which system 100 is located. In an embodiment, vessel structure 112 may move with the vessel so as to experience substantially the same vessel movement as the vessel itself.

[0031] According to some embodiments, one or more tensioners 110 may be configured to compensate for motion on drill pipe 102 by controlling tension on one or more of the plurality of wires 108 coupled to the marine riser pipe 104. For example, one or more tensioners 110 may control the tension on one or more of the plurality of wires 108 to maintain constant the tension on the one or more of the plurality of wires 108. In some embodiments, control of the tension on one of the plurality of wires 108 may include adjusting, by a tensioner 110, the length of the wire 108.

[0032] In certain embodiments, a tensioner may be a hydro-pneumatic tensioner or an electrical tensioner. Thus, one or more tensioners 110 may include a combination of one or more electrical tensioners and one or more hydro-pneumatic tensioners. For example, in the embodiment illustrated in FIG. 1A, tensioners 110A and HOC are electrical tensioners while tensioners HOB and HOD are hydro -pneumatic tensioners. In another embodiment, one or more tensioners 110 may consist entirely of hydro-pneumatic tensioners. In yet another embodiment, one or more tensioners 110 may consist entirely of electrical tensioners.

[0033] In some embodiments, the plurality of wires 108 and the one or more tensioners 110, which may include a combination of one or more electrical tensioners and one or more hydro -pneumatic tensioners, may be operated together as part of a riser tensioning system. A riser tensioning system including the plurality of wires 108 and tensioners 110 may include a controller. The controller may be coupled to tensioners 110 and may be configured to control tensioners 110 to control tension on one or more of the plurality of wires 108. Altogether, the controller, the one or more tensioners 110, and the plurality of wires 108 may function as a riser tensioning system, such as the enhanced riser control system disclosed in U.S. Patent Application No. 13/715,412, which is incorporated herein by reference. As noted above, the plurality of wires 108 may be configured to collectively hold and support the weight of both the marine riser pipe 104 and the drill pipe 102. Therefore, a riser tensioning system that includes tensioners 110 and the plurality of wires 108 may be configured to support the weight of both the marine riser pipe 104 and the drill pipe 102.

[0034] System 100 also includes one or more sensors 160. In some embodiments, the one or more sensors 160 may be coupled to marine riser pipe 104. For example, in one embodiment, the one or more sensors 160 may be coupled directly to marine riser pipe 104 or to tension ring 116, which is coupled to marine riser pipe 104. In another embodiment, sensors 160 may be coupled to at least one of the marine riser pipe 104, drill pipe 102, and pipe holder 106. Sensors 160 may include at least one of an accelerometer and a load cell. In some embodiments, sensors 160 may be configured to sense signals that are indicative of a load on drill pipe 102 or tension on one or more of the plurality of wires 108 supporting the weight of the marine riser pipe 104 and drill pipe 102. For example, sensors 160 may include one or more accelerometers to sense vibrations on the marine riser pipe 104 and/or to detect whether marine riser pipe 104 has been disconnected. In addition, sensors 160 may also include one or more load cells to sense tension forces on the plurality of wires 108. Thus, in some embodiments, one or more of tensioners 110 may be configured to adjust the tension on one or more of the plurality of wires 108 in response to the sensing of the signals by sensors 160. For example, a riser tensioning system part of system 100, such as the enhanced riser control system disclosed in U.S. Patent Application No. 13/715,412, may include a controller coupled to sensors 160 and configured to receive signals from sensors 160. The controller may be configured to process the signals from sensors 160. Based on the processing of the signals received by the sensors, the controller, which is also coupled to the one or more tensioners 110, may control the one or more tensioners 110 to adjust the tension on one or more of the plurality of wires 108 in response to the sensing of the signals by sensors 160.

[0035] According to an embodiment, controlling the tension on one or more of the plurality of wires 108 includes varying the tension on the one or more of the plurality of wires 108 in response to signals from, for example an accelerometer sensor 160, when the marine riser pipe 104 vibrates or when the marine riser pipe 104 is disconnected from the drill floor. In another embodiment, in response to, for example signals from load cell sensors 160 which measure the tension force on wires 108 to determine the weight of the drill pipe 102 on marine riser pipe 104, the tensioners 110 can be adjusted as the drill pipe load is applied.

[0036] According to some embodiments, system 100 also includes a flexible tube 130 coupled to the drill pipe 102. The flexible tube 130 may also be coupled to the vessel on which system 100 is located. In some embodiments, flexible tube 130 may be configured to flex to accommodate for vessel movement. Flexible tube 130 may also be configured to flex to reduce the amount of movement experienced by the drill pipe 102 as compared to the vessel movement. In some embodiments, system 100 may include a valve manifold 150 which may be configured to couple flexible tube 130 to drill pipe 102. System 100 may also include a second flexible tube 140 coupled to pipe holder 106 and configured to allow mud to return from the marine riser annulus.

[0037] As illustrated in FIG. 1, well head 180 may be enclosed by a blowout preventer (BOP) 182. In addition, BOP 182 may be coupled to a lower marine riser package (LMRP) 184. Marine riser pipe 104 may be configured to couple to BOP 182 and/or LMRP 184 in additional to well head 180. In particular, in some embodiments, the lower end of marine riser pipe 104 may be pinned to the seabed 190 so that it does not move with respect to the well 180. Additionally, the top of marine riser pipe 104 may be controlled via the tensioners so as to not move vertically with respect to the seabed 190.

[0038] In view of the systems shown and described herein, methodologies that may be implemented in accordance with the disclosed subject matter will be better appreciated with reference to various functional block diagrams. While, for purposes of simplicity of explanation, methodologies are shown and described as a series of acts/blocks, it is to be understood and appreciated that the claimed subject matter is not limited by the number or order of blocks, as some blocks may occur in different orders and/or at substantially the same time with other blocks from what is depicted and described herein. Moreover, not all illustrated blocks may be required to implement methodologies described herein. It is to be appreciated that functionality associated with blocks may be implemented by software, hardware, a combination thereof or any other suitable means (e.g. device, system, process, or component). Additionally, it should be further appreciated that methodologies disclosed throughout this specification are capable of being stored on an article of manufacture to facilitate transporting and transferring such methodologies to various devices. Those skilled in the art will understand and appreciate that a methodology could alternatively be represented as a series of interrelated states or events, such as in a state diagram.

[0039] FIG. 2 is a flow chart illustrating a method for performing drill pipe motion compensation according to one embodiment of the disclosure. Method 200 may be implemented with the systems described with respect to FIGS. 1A-1C. Method 200 includes, at block 202, supporting the weight of a drill pipe with a marine riser pipe. According to an embodiment, the marine riser pipe may be coupled to a well head on the seabed. In some embodiments, supporting the weight of the drill pipe with the marine riser pipe may include suspending the drill pipe on the marine riser pipe with a pipe holder. Supporting the weight of the drill pipe with the marine riser pipe may also include transferring the weight of the drill pipe to the marine riser pipe. According to an embodiment, transferring the weight of the drill pipe to the marine riser pipe may include mechanically coupling to the pipe holder and the marine riser pipe a drill pipe support system, wherein the drill pipe support system and the pipe holder are configured to transfer the weight of the drill pipe to the marine riser pipe.

[0040] At block 204, method 200 includes compensating for motion on the drill pipe by controlling tension on one or more of a plurality of wires coupled to the marine riser pipe. In some embodiments, controlling the tension on the one or more of the plurality of wires may include maintaining constant the tension on the one or more of the plurality of wires.

[0041] In some embodiments, a method for performing drill pipe motion compensation may also include sensing signals that are indicative of a load on the drill pipe or tension on one or more of the plurality of wires. According to an embodiment, controlling the tension on one or more of a plurality of wires may include adjusting the tension on one or more of the plurality of wires in response to the sensing of the signals.

[0042] According to an embodiment, a method for performing motion compensation may also include configuring the plurality of wires to collectively hold and support the weight of both the marine riser pipe and the drill pipe. In addition, in an embodiment, for each of the one or more of the plurality of wires, the tension may be controlled by one of a hydro-pneumatic tensioner and an electrical tensioner. In some embodiments, a method for performing drill pipe motion compensation may also include coupling to the drill pipe a flexible tube, wherein the flexible tube flexes to accommodate for vessel movement and to reduce the amount of movement experienced by the drill pipe as compared to the vessel movement.

[0043] The schematic flow chart diagram of FIG. 2 is generally set forth as a logical flow chart diagram. As such, the depicted order and labeled steps are indicative of aspects of the disclosed method. Other steps and methods may be conceived that are equivalent in function, logic, or effect to one or more steps, or portions thereof, of the illustrated method. Additionally, the format and symbols employed are provided to explain the logical steps of the method and are understood not to limit the scope of the method. Although various arrow types and line types may be employed in the flow chart diagram, they are understood not to limit the scope of the corresponding method. Indeed, some arrows or other connectors may be used to indicate only the logical flow of the method. For instance, an arrow may indicate a waiting or monitoring period of unspecified duration between enumerated steps of the depicted method. Additionally, the order in which a particular method occurs may or may not strictly adhere to the order of the corresponding steps shown.

[0044] While the embodiments of the disclosure described herein have been described with reference to numerous specific details, one of ordinary skill in the art will recognize that the embodiments of the disclosure can be embodied in other specific forms without departing from the spirit of the embodiments of the disclosure. Thus, one of ordinary skill in the art would understand that the embodiments described herein are not to be limited by the foregoing illustrative details, but rather are to be defined by the appended claims.

[0045] Although the present disclosure and certain representative advantages have been described in detail, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the disclosure as defined by the appended claims. Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the present disclosure, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.