Cross-Reference to Related Applications

[0001] This application claims priority to U.S. Provisional Patent Application having serial no. 62/892,053, which was filed on August 27, 2020, and is incorporated herein by reference in its entirety.

Background

[0002] Executing drilling rig tasks can include managing any number of hardware components, modifying user data, and the like. In some embodiments, the drilling rig tasks can include modifying or moving equipment, such as drilling rigs, for retrieving resources from geologic reservoirs, among others. In some examples, the drilling rig tasks can include multiple interrelated sub-tasks associated with drilling rigs that are completed in a particular sequence. Accordingly, drilling rig task management can involve identifying hardware components to be used to complete a drilling rig task, identifying a sequence for completing sub-tasks, identifying users corresponding to each sub-task, and the like. Therefore, a centralized automated drilling rig task management device can enable managing the various hardware components, data repositories, and users corresponding to drilling rig management related tasks.

Summary

[0003] A method for drilling rig task management is disclosed. The method includes providing work instructions to a plurality of users for executing a drilling rig task based on a digital hierarchy model. The digital hierarchy model defines a number of users to perform the drilling rig task and a duration of time for each user to perform the drilling rig task. The method also includes storing feedback and sensor data corresponding to the executed drilling rig activity. The feedback and the sensor data are collected from one or more sensors coupled to one or more digital assets for each user. The method further includes revising the digital hierarchy model based on the feedback and the sensor data. One or more subsequent drilling rig tasks are performed based on the revised digital hierarchy model.

[0004] A system for drilling rig task management is also disclosed. The system includes one or more processors, and a memory system comprising one or more non-transitory, computer-readable media storing instructions that, when executed by the processor, cause the computing system to perform operations. The operations include providing work instructions to a plurality of users for executing a drilling rig task based on a digital hierarchy model. The digital hierarchy model defines a number of users to perform the drilling rig task and a duration of time for each user to perform the drilling rig task. The operations include storing feedback and sensor data corresponding to the executed drilling rig activity. The feedback and the sensor data are collected from one or more sensors coupled to one or more digital assets for each user. The operations include revising the digital hierarchy model based on the feedback and the sensor data. One or more subsequent drilling rig tasks are performed based on the revised digital hierarchy model.

[0005] A non-transitory, computer-readable media storing instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations. The operations include providing work instructions to a plurality of users for executing a drilling rig task based on a digital hierarchy model. The digital hierarchy model defines a number of users to perform the drilling rig task and a duration of time for each user to perform the drilling rig task. The operations include storing feedback and sensor data corresponding to the executed drilling rig activity. The feedback and the sensor data are collected from one or more sensors coupled to one or more digital assets for each user. The operations include revising the digital hierarchy model based on the feedback and the sensor data. One or more subsequent drilling rig tasks are performed based on the revised digital hierarchy model.

[0006] Thus, the computing systems and methods disclosed herein are more effective methods for automated management of devices used to execute a drilling rig task that may, for example, correspond to a surface and a subsurface region. These computing systems and methods increase drilling rig task execution, effectiveness, efficiency, and accuracy. Such methods and computing systems may complement or replace conventional methods for executing drilling rig tasks. This summary is provided to introduce a selection of concepts that are further described below in the detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter. Brief Description of the Drawings

[0007] The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings. In the figures:

[0008] Figure 1 illustrates a simplified, schematic view of oilfield equipment, according to an embodiment.

[0009] Figure 2 illustrates a block diagram of various components of oilfield equipment, according to an embodiment.

[0010] Figure 3 illustrates a flowchart of a method for managing execution of drilling rig tasks, according to an embodiment.

[0011] Figure 4 illustrates a block diagram of a digital hierarchy model, according to an embodiment.

[0012] Figure 5 illustrates a flowchart of another method for managing execution of drilling rig tasks, according to an embodiment.

[0013] Figure 6 illustrates a schematic view of a computing system, according to an embodiment.

Detailed Description

[0014] In some embodiments, techniques herein are related to executing drilling rig tasks by managing resources through a networked digital user interface. For example, the techniques herein can include executing a drilling rig task based on a digital hierarchy model that can include information regarding the resources used to execute the drilling rig task, among others. The techniques can also include storing feedback and sensor data corresponding to the executed drilling rig task and revising the digital hierarchy model based on the feedback and the sensor data. Furthermore, the techniques herein can include transmitting the revised digital hierarchy model to a remote server.

[0015] In some embodiments, techniques herein can enable reducing the resources used in the mobilization of a land drilling rig. For example, executing a drilling rig task can include generating step by step work instructions that can be delegated for each user or group of users on the rig that work collectively to complete the overall job consisting of layered activities and sequential drilling rig tasks. In some examples, the overall job can be a rig move, and the like. Each user’s actions can communicate with one another and can connect to a real time and forward-looking device. [0016] In some examples, the techniques herein can minimize the amount of time to execute a drilling rig task. For example, the techniques herein can minimize the down time for moving a land drilling operation or setting up a new land drilling operation. The techniques herein can also enable resource management during execution of a drilling rig task such as creating a sequence for equipment to arrive or for equipment to leave, repairing equipment during operation of a land drilling operation, and the like.

[0017] Reference will now be made in detail to specific embodiments illustrated in the accompanying drawings and figures. In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the embodiments described herein. However, it will be apparent to one of ordinary skill in the art that embodiments may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.

[0018] It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are only used to distinguish one element from another. For example, a first object could be termed a second object or step, and, similarly, a second object could be termed a first object or step, without departing from the scope of the present disclosure.

[0019] The terminology used in the description of the techniques herein is for the purpose of describing particular embodiments only and is not intended to be limiting. As used in the description of the techniques herein and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will also be understood that the term “and/or” as used herein refers to and encompasses any and all possible combinations of one or more of the associated listed items. It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof. Further, as used herein, the term “if’ may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.

[0020] Figures 1 and 2, described below, provide introductory information corresponding to the various components of equipment used to retrieve resources from a geologic environment. In some embodiments, the equipment may be involved in the execution of a drilling rig task. For example, Figures 3 and 4 below describe various techniques for executing a drilling rig task, such as moving a rig, or modifying a rig, among others.

[0021] Figure 1 shows an example of a geologic environment 120. In Figure 1, the geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults). As an example, the geologic environment 120 may be outfitted with any of a variety of sensors, detectors, actuators, etc. For example, equipment 122 may include communication circuitry to receive and/or to transmit information with respect to one or more networks 125. Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc. Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry. Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc. As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.). As an example, one or more satellites may be provided for purposes of communications, data acquisition, geolocation, etc. For example, Figure 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.). [0022] Figure 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 129. For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures. As an example, a well may be drilled for a reservoir that is laterally extensive. In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.). As an example, the equipment 127 and/or 128 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, injection, production, etc. As an example, the equipment 127 and/or 128 may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, production data (e.g., for one or more produced resources). As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.

[0023] Figure 1 also shows an example of equipment 170 and an example of equipment 180. Such equipment, which may be systems of components, may be suitable for use in the geologic environment 120. While the equipment 170 and 180 are illustrated as land-based, various components may be suitable for use in an offshore system. As shown in Figure 1, the equipment 180 can be mobile as carried by a vehicle; noting that the equipment 170 can be assembled, disassembled, transported and re-assembled, etc.

[0024] The equipment 170 includes a platform 171, a derrick 172, a crown block 173, a line 174, a traveling block assembly 175, drawworks 176 and a landing 177 (e.g., a monkeyboard). As an example, the line 174 may be controlled at least in part via the drawworks 176 such that the traveling block assembly 175 travels in a vertical direction with respect to the platform 171. For example, by drawing the line 174 in, the drawworks 176 may cause the line 174 to run through the crown block 173 and lift the traveling block assembly 175 skyward away from the platform 171; whereas, by allowing the line 174 out, the drawworks 176 may cause the line 174 to run through the crown block 173 and lower the traveling block assembly 175 toward the platform 171. Where the traveling block assembly 175 carries pipe (e.g., casing, etc.), tracking of movement of the traveling block assembly 175 may provide an indication as to how much pipe has been deployed. [0025] A derrick can be a structure used to support a crown block and a traveling block operatively coupled to the crown block at least in part via line. A derrick may be pyramidal in shape and offer a suitable strength-to-weight ratio. A derrick may be movable as a unit or in a piece by piece manner (e.g., to be assembled and disassembled).

[0026] As an example, drawworks may include a spool, brakes, a power source and assorted auxiliary devices. Drawworks may controllably reel out and reel in line. Line may be reeled over a crown block and coupled to a traveling block to gain mechanical advantage in a “block and tackle” or “pulley” fashion. Reeling out and in of line can cause a traveling block (e.g., and whatever may be hanging underneath it), to be lowered into or raised out of a bore. Reeling out of line may be powered by gravity and reeling in by a motor, an engine, etc. (e.g., an electric motor, a diesel engine, etc.).

[0027] As an example, a crown block can include a set of pulleys (e.g., sheaves) that can be located at or near a top of a derrick or a mast, over which line is threaded. A traveling block can include a set of sheaves that can be moved up and down in a derrick or a mast via line threaded in the set of sheaves of the traveling block and in the set of sheaves of a crown block. A crown block, a traveling block and a line can form a pulley system of a derrick or a mast, which may enable handling of heavy loads (e.g., drillstring, pipe, casing, liners, etc.) to be lifted out of or lowered into a bore. As an example, line may be about a centimeter to about five centimeters in diameter as, for example, steel cable. Through use of a set of sheaves, such line may carry loads heavier than the line could support as a single strand.

[0028] As an example, a derrick person may be a rig crew member that works on a platform attached to a derrick or a mast. A derrick can include a landing on which a derrick person may stand. As an example, such a landing may be about 10 meters or more above a rig floor. In an operation referred to as trip out of the hole (TOH), a derrick person may wear a safety harness that enables leaning out from the work landing (e.g., monkeyboard) to reach pipe in located at or near the center of a derrick or a mast and to throw a line around the pipe and pull it back into its storage location (e.g., fingerboards), for example, until it a time at which it may be desirable to run the pipe back into the bore. As an example, a rig may include automated pipe-handling equipment such that the derrick person controls the machinery rather than physically handling the pipe. [0029] As an example, a trip may refer to the act of pulling equipment from a bore and/or placing equipment in a bore. As an example, equipment may include a drillstring that can be pulled out of the hole and/or place or replaced in the hole. As an example, a pipe trip may be performed where a drill bit has dulled or has otherwise ceased to drill efficiently and is to be replaced.

[0030] Figure 2 shows an example of a wellsite system 200 (e.g., at a wellsite that may be onshore or offshore). As shown, the wellsite system 200 can include a mud tank 201 for holding mud and other material (e.g., where mud can be a drilling fluid), a suction line 203 that serves as an inlet to a mud pump 204 for pumping mud from the mud tank 201 such that mud flows to a vibrating hose (or line) 206, a drawworks 207 for winching drill line or drill lines 212, a standpipe 208 that receives mud from the vibrating hose 206, a kelly hose 209 that receives mud from the standpipe 208, a gooseneck or goosenecks 210, a traveling block 211, a crown block 213 for carrying the traveling block 211 via the drill line or drill lines 212 (see, e.g., the crown block 173 of Figure 1), a derrick 214 (see, e.g., the derrick 172 of Figure 1), a kelly 218 or a top drive 240, a kelly drive bushing 219, a rotary table 220, a drill floor 221, a bell nipple 222, one or more blowout preventors (BOPs) 223, a drillstring 225, a drill bit 226, a casing head 227 and a flow pipe 228 that carries mud and other material to, for example, the mud tank 201.

[0031] In the example system of Figure 2, a borehole 232 is formed in subsurface formations 230 by rotary drilling; noting that various example embodiments may also use directional drilling. [0032] As shown in the example of Figure 2, the drillstring 225 is suspended within the borehole 232 and has a drillstring assembly 250 that includes the drill bit 226 at its lower end. As an example, the drillstring assembly 250 may be a bottom hole assembly (BHA).

[0033] The wellsite system 200 can provide for operation of the drillstring 225 and other operations. As shown, the wellsite system 200 includes the platform 171 and the derrick 214 positioned over the borehole 232. As mentioned, the wellsite system 200 can include the rotary table 220 where the drillstring 225 pass through an opening in the rotary table 220.

[0034] As shown in the example of Figure 2, the wellsite system 200 can include the kelly 218 and associated components, etc., or a top drive 240 and associated components. As to a kelly example, the kelly 218 may be a square or hexagonal metal/alloy bar with a hole drilled therein that serves as a mud flow path. The kelly 218 can be used to transmit rotary motion from the rotary table 220 via the kelly drive bushing 219 to the drillstring 225, while allowing the drillstring 225 to be lowered or raised during rotation. The kelly 218 can pass through the kelly drive bushing 219, which can be driven by the rotary table 220. As an example, the rotary table 220 can include a master bushing that operatively couples to the kelly drive bushing 219 such that rotation of the rotary table 220 can turn the kelly drive bushing 219 and hence the kelly 218. The kelly drive bushing 219 can include an inside profile matching an outside profile (e.g., square, hexagonal, etc.) of the kelly 218; however, with slightly larger dimensions so that the kelly 218 can freely move up and down inside the kelly drive bushing 219.

[0035] As to a top drive example, the top drive 240 can provide functions performed by a kelly and a rotary table. The top drive 240 can turn the drillstring 225. As an example, the top drive 240 can include one or more motors (e.g., electric and/or hydraulic) connected with appropriate gearing to a short section of pipe called a quill, that in turn may be screwed into a saver sub or the drill string 225 itself. The top drive 240 can be suspended from the traveling block 211, so the rotary mechanism is free to travel up and down the derrick 214. As an example, a top drive 240 may allow for drilling to be performed with more joint stands than a kelly/rotary table approach.

[0036] In the example of Figure 2, the mud tank 201 can hold mud, which can be one or more types of drilling fluids. As an example, a wellbore may be drilled to produce fluid, inject fluid or both (e.g., hydrocarbons, minerals, water, etc.).

[0037] In the example of Figure 2, the drillstring 225 (e.g., including one or more downhole tools) may be composed of a series of pipes threadably connected together to form a long tube with the drill bit 226 at the lower end thereof. As the drillstring 225 is advanced into a wellbore for drilling, at some point in time prior to or coincident with drilling, the mud may be pumped by the pump 204 from the mud tank 201 (e.g., or other source) via a the lines 206, 208 and 209 to a port of the kelly 218 or, for example, to a port of the top drive 240. The mud can then flow via a passage (e.g., or passages) in the drillstring 225 and out of ports located on the drill bit 226 (see, e.g., a directional arrow). As the mud exits the drillstring 225 via ports in the drill bit 226, it can then circulate upwardly through an annular region between an outer surface(s) of the drillstring

225 and surrounding wall(s) (e.g., open borehole, casing, etc.), as indicated by directional arrows. In such a manner, the mud lubricates the drill bit 226 and carries heat energy (e.g., frictional or other energy) and formation cuttings to the surface where the mud (e.g., and cuttings) may be returned to the mud tank 201, for example, for recirculation (e.g., with processing to remove cuttings, etc.).

[0038] The mud pumped by the pump 204 into the drillstring 225 may, after exiting the drillstring 225, form a mudcake that lines the wellbore which, among other functions, may reduce friction between the drillstring 225 and surrounding wall(s) (e.g., borehole, casing, etc.). A reduction in friction may facilitate advancing or retracting the drillstring 225. During a drilling operation, the entire drillstring 225 may be pulled from a wellbore and optionally replaced, for example, with a new or sharpened drill bit, a smaller diameter drill string, etc. As mentioned, the act of pulling a drill string out of a hole or replacing it in a hole is referred to as tripping. A trip may be referred to as an upward trip or an outward trip or as a downward trip or an inward trip depending on trip direction.

[0039] As an example, consider a downward trip where upon arrival of the drill bit 226 of the drillstring 225 at a bottom of a wellbore, pumping of the mud commences to lubricate the drill bit

226 for purposes of drilling to enlarge the wellbore. As mentioned, the mud can be pumped by the pump 204 into a passage of the drillstring 225 and, upon filling of the passage, the mud may be used as a transmission medium to transmit energy, for example, energy that may encode information as in mud-pulse telemetry.

[0040] As an example, mud-pulse telemetry equipment may include a downhole device configured to effect changes in pressure in the mud to create an acoustic wave or waves upon which information may modulated. In such an example, information from downhole equipment (e.g., one or more modules of the drillstring 225) may be transmitted uphole to an uphole device, which may relay such information to other equipment for processing, control, etc.

[0041] As an example, telemetry equipment may operate via transmission of energy via the drillstring 225 itself. For example, consider a signal generator that imparts coded energy signals to the drillstring 225 and repeaters that may receive such energy and repeat it to further transmit the coded energy signals (e.g., information, etc.).

[0042] As an example, the drillstring 225 may be fitted with telemetry equipment 252 that includes a rotatable drive shaft, a turbine impeller mechanically coupled to the drive shaft such that the mud can cause the turbine impeller to rotate, a modulator rotor mechanically coupled to the drive shaft such that rotation of the turbine impeller causes said modulator rotor to rotate, a modulator stator mounted adjacent to or proximate to the modulator rotor such that rotation of the modulator rotor relative to the modulator stator creates pressure pulses in the mud, and a controllable brake for selectively braking rotation of the modulator rotor to modulate pressure pulses. In such example, an alternator may be coupled to the aforementioned drive shaft where the alternator includes at least one stator winding electrically coupled to a control circuit to selectively short the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake rotation of the modulator rotor to modulate the pressure pulses in the mud. [0043] In the example of Figure 2, an uphole control and/or data acquisition system 262 may include circuitry to sense pressure pulses generated by telemetry equipment 252 and, for example, communicate sensed pressure pulses or information derived therefrom for process, control, etc. [0044] The assembly 250 of the illustrated example includes a logging-while-drilling (LWD) module 254, a measuring-while-drilling (MWD) module 256, an optional module 258, a roto- steerable system and motor 260, and the drill bit 226.

[0045] The LWD module 254 may be housed in a suitable type of drill collar and can contain one or a plurality of selected types of logging tools. It will also be understood that more than one LWD and/or MWD module can be employed, for example, as represented at by the module 256 of the drillstring assembly 250. Where the position of an LWD module is mentioned, as an example, it may refer to a module at the position of the LWD module 254, the module 256, etc. An LWD module can include capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment. In the illustrated example, the LWD module 254 may include a seismic measuring device.

[0046] The MWD module 256 may be housed in a suitable type of drill collar and can contain one or more devices for measuring characteristics of the drillstring 225 and the drill bit 226. As an example, the MWD module 256 may include equipment for generating electrical power, for example, to power various components of the drillstring 225. As an example, the MWD module 256 may include the telemetry equipment 252, for example, where the turbine impeller can generate power by flow of the mud; it being understood that other power and/or battery systems may be employed for purposes of powering various components. As an example, the MWD module 256 may include one or more of the following types of measuring devices: a weight-on- bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.

[0047] Figure 2 also shows some examples of types of holes that may be drilled. For example, consider a slant hole 272, an S-shaped hole 274, a deep inclined hole 276 and a horizontal hole 278.

[0048] As an example, a drilling operation can include directional drilling where, for example, at least a portion of a well includes a curved axis. For example, consider a radius that defines curvature where an inclination with regard to the vertical may vary until reaching an angle between about 30 degrees and about 60 degrees or, for example, an angle to about 90 degrees or possibly greater than about 90 degrees.

[0049] As an example, a directional well can include several shapes where each of the shapes may aim to meet particular operational demands. As an example, a drilling process may be performed on the basis of information as and when it is relayed to a drilling engineer. As an example, inclination and/or direction may be modified based on information received during a drilling process. [0050] As an example, deviation of a bore may be accomplished in part by use of a downhole motor and/or a turbine. As to a motor, for example, a drillstring can include a positive displacement motor (PDM).

[0051] As an example, a system may be a steerable system and include equipment to perform method such as geosteering. As an example, a steerable system can include a PDM or of a turbine on a lower part of a drillstring which, just above a drill bit, a bent sub can be mounted. As an example, above a PDM, MWD equipment that provides real time or near real time data of interest (e.g., inclination, direction, pressure, temperature, real weight on the drill bit, torque stress, etc.) and/or LWD equipment may be installed. As to the latter, LWD equipment can make it possible to send to the surface various types of data of interest, including for example, geological data (e.g., gamma ray log, resistivity, density and sonic logs, etc.).

[0052] The coupling of sensors providing information on the course of a well trajectory, in real time or near real time, with, for example, one or more logs characterizing the formations from a geological viewpoint, can allow for implementing a geosteering method. Such a method can include navigating a subsurface environment, for example, to follow a desired route to reach a desired target or targets.

[0053] As an example, a drillstring can include an azimuthal density neutron (AND) tool for measuring density and porosity; a MWD tool for measuring inclination, azimuth and shocks; a compensated dual resistivity (CDR) tool for measuring resistivity and gamma ray related phenomena; one or more variable gauge stabilizers; one or more bend joints; and a geosteering tool, which may include a motor and optionally equipment for measuring and/or responding to one or more of inclination, resistivity and gamma ray related phenomena.

[0054] As an example, geosteering can include intentional directional control of a wellbore based on results of downhole geological logging measurements in a manner that aims to keep a directional wellbore within a desired region, zone (e.g., a pay zone), etc. As an example, geosteering may include directing a wellbore to keep the wellbore in a particular section of a reservoir, for example, to minimize gas and/or water breakthrough and, for example, to maximize economic production from a well that includes the wellbore.

[0055] Referring again to Figure 2, the wellsite system 200 can include one or more sensors 264 that are operatively coupled to the control and/or data acquisition system 262. As an example, a sensor or sensors may be at surface locations. As an example, a sensor or sensors may be at downhole locations. As an example, a sensor or sensors may be at one or more remote locations that are not within a distance of the order of about one hundred meters from the wellsite system 200. As an example, a sensor or sensor may be at an offset wellsite where the wellsite system 200 and the offset wellsite are in a common field (e.g., oil and/or gas field).

[0056] As an example, one or more of the sensors 264 can be provided for tracking pipe, tracking movement of at least a portion of a drillstring, etc.

[0057] As an example, the system 200 can include one or more sensors 266 that can sense and/or transmit signals to a fluid conduit such as a drilling fluid conduit (e.g., a drilling mud conduit). For example, in the system 200, the one or more sensors 266 can be operatively coupled to portions of the standpipe 208 through which mud flows. As an example, a downhole tool can generate pulses that can travel through the mud and be sensed by one or more of the one or more sensors 266. In such an example, the downhole tool can include associated circuitry such as, for example, encoding circuitry that can encode signals, for example, to reduce demands as to transmission. As an example, circuitry at the surface may include decoding circuitry to decode encoded information transmitted at least in part via mud-pulse telemetry. As an example, circuitry at the surface may include encoder circuitry and/or decoder circuitry and circuitry downhole may include encoder circuitry and/or decoder circuitry. As an example, the system 200 can include a transmitter that can generate signals that can be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.

[0058] As an example, one or more portions of a drillstring may become stuck. The term stuck can refer to one or more of varying degrees of inability to move or remove a drill string from a bore. As an example, in a stuck condition, it might be possible to rotate pipe or lower it back into a bore or, for example, in a stuck condition, there may be an inability to move the drillstring axially in the bore, though some amount of rotation may be possible. As an example, in a stuck condition, there may be an inability to move at least a portion of the drillstring axially and rotationally. [0059] As to the term “stuck pipe”, the can refer to a portion of a drillstring that cannot be rotated or moved axially. As an example, a condition referred to as “differential sticking” can be a condition whereby the drillstring cannot be moved (e.g., rotated or reciprocated) along the axis of the bore. Differential sticking may occur when high-contact forces caused by low reservoir pressures, high wellbore pressures, or both, are exerted over a sufficiently large area of the drillstring. Differential sticking can have time and financial cost. [0060] As an example, a sticking force can be a product of the differential pressure between the wellbore and the reservoir and the area that the differential pressure is acting upon. This means that a relatively low differential pressure (delta p) applied over a large working area can be just as effective in sticking pipe as can a high differential pressure applied over a small area.

[0061] As an example, a condition referred to as “mechanical sticking” can be a condition where limiting or prevention of motion of the drillstring by a mechanism other than differential pressure sticking occurs. Mechanical sticking can be caused, for example, by one or more of junk in the hole, wellbore geometry anomalies, cement, keyseats or a buildup of cuttings in the annulus. [0062] Figure 3 is a process flow diagram of an example method 300 for executing a drilling rig task. The method 300 can be implemented with any suitable computing device such as the computer system 501A of Figure 5, among others.

[0063] At block 302, a computing device can execute a drilling rig task based on a digital hierarchy model. As discussed in greater detail below in relation to Figure 4, the digital hierarchy model can include any number of tasks, sub-tasks, activities, sub-activities, work instructions (i.e., instructions for performing at least part of a task, sub-task, activity, or sub-activity), and the like. In some examples, completion of the tasks, activities, sub-tasks, and sub-activities based on the work instructions results in completing a drilling rig job or task, such as a rig move, among others. In some embodiments, any number of tasks, activities, sub-tasks, and sub-activities can be completed either simultaneously or sequentially. For example, some tasks, activities, sub-tasks, and sub -activities can be interdependent. As such, initiation of a subsequent task, activity, sub task, or sub-activity may be dependent on completion of a previous task, activity, sub-task, or sub activity. In some embodiments, the digital hierarchy defines a number of users to perform each drilling rig task and a duration of time for each user to perform each drilling rig task. In some examples, the drilling rig task can include extracting oil or gas from a reservoir by assembling a new rig, or the drilling rig task can include extracting the oil or the gas from the reservoir by moving an existing rig to a new location. In some embodiments, the drilling rig task can also include actions performed while operating a land rig. For example, the drilling rig task can include installing new equipment, repairing existing equipment, and the like.

[0064] In some embodiments, the computing device can generate the digital hierarchy model based on a recording session of a set of users that previously executed the drilling rig task, or a set of users simulating the drilling rig task in a training session. For example, the computing device can monitor sensor data collected as users perform any suitable number of actions related to a drilling rig task. The computing device can store the sensor data for each user and analyze the sensor data to determine an average amount of time to perform each action by the user. In some examples, the computing device can aggregate the average amount of time to perform each action and determine an average amount of time to perform a drilling rig task or activity based on the corresponding number of actions and time to complete each action. The computing device can also determine a sequence of actions to perform each drilling rig task or activity.

[0065] In some embodiments, the computing device can automatically detect a drilling rig task from a rig, or any other suitable equipment. For example, the computing device can detect malfunctioning equipment while drilling a borehole or while producing oil and gas from a borehole. The computing device can generate a digital hierarchy model to replace the malfunctioning equipment based on the expected actions corresponding to the drilling rig task of replacing the malfunctioning equipment.

[0066] At block 304, the computing device can store feedback and sensor data corresponding to the executed drilling rig task. In some examples, the feedback and the sensor data are collected from sensors coupled to digital assets for each user. In some embodiments, the digital assets are attached to each user performing the drilling rig task. The digital assets include a wireless transceiver, a digital display or digital viewable, a digital camera, an audio receiver, and a transmitter, among others. In some embodiments, the digital assets can also include an accelerometer, a global positioning system (GPS) sensor, and the like. In some examples, the sensor data can include a location of a user performing a drilling rig task, a heart rate of each user performing the drilling rig task, a speed at which each user is traveling while performing the drilling rig task, a body temperature of each user performing the drilling rig task, or a combination thereof. The various sensors of the digital asset can also enable zone management described in greater detail below in relation to block 308.

[0067] In some embodiments, each user is associated with defined roles. For example, the defined roles can indicate a set of tools that each user is certified to operate. The digital assets can confirm that each user performing the drilling rig task is certified to operate a tool associated with the drilling rig task. For example, the digital asset assigned to each user can be a wearable device that stores information indicating a user’s credentials, certifications, and/or capabilities such as training, physical size, and the like. In some embodiments, a device managing execution of a drilling rig task can provide defined work instructions to each user. For example, at the beginning of a shift for executing the drilling rig task, the current open activities and sub-tasks that can be completed by each role can be shown. Each sub-task and work instruction can include sequential actions and may be completed prior to initiating other drilling rig tasks or activities. The techniques herein enable each user to determine what devices to be used to complete a portion of a sub-task. [0068] In some embodiments, the feedback can include information related to execution of a drilling rig task. For example, the feedback can include user input corresponding to the drilling rig task, an image captured during execution of the drilling rig task, an image captured following execution of the drilling rig task, video captured during execution of the drilling rig task, or video captured following execution of the drilling rig task. In some examples, the user input can include a suggestion to reduce or increase a number of resources to complete a drilling rig task or activity. For example, the feedback can suggest modifying a number of users and/or devices used to complete a drilling rig task or activity.

[0069] Still at block 304, in some embodiments, the computing device can capture each user action, a timestamp, and any changes to the initial drilling rig task or sub-tasks, among others. In some examples, this information can be reviewed and used to revise subsequent drilling rig tasks. In some examples, live reporting back to central command centers can allow for accurate communication of ongoing activities without interruption of daily activities of those performing the work.

[0070] In some embodiments, the computing device can detect when each user has completed a sub-task. The techniques can also provide applicable Job Safety Analysis (JSA) before execution of a drilling rig task. In some examples, a user is associated with each action taken to execute a sub-task. By opening and confirming that the JSA has been read, the user’s name can be linked to that JSA showing that this part of the process has been completed. This can allow for managing each action taken to complete each sub-task by each user.

[0071] At block 306, the computing device can revise the digital hierarchy model based on the feedback and the sensor data. In some embodiments, the computing device can revise the digital hierarchy model to include fewer users or additional users assigned to the drilling rig task to be executed. In some examples, the computing device can also reassign users to perform different roles corresponding to the drilling rig task, identify users with dual role capabilities, and the like. For example, the digital hierarchy model can be revised to include a different number of users associated with constructing rig equipment such as a drilling platform, a derrick, a crown block, a line, a traveling block assembly, drawworks, a landing, or any combination thereof. In some embodiments, the digital hierarchy model can be revised to indicate that a particular user is trained to perform construction of multiple pieces of rig equipment. For example, a role of a user in a digital hierarchy model can be revised to manage two separate sub-tasks associated with constructing a drilling platform and constructing a crown block, among others.

[0072] In some examples, the digital hierarchy model can be revised to remove users from particular roles based on the feedback and the sensor data. For example, the digital hierarchy model can prevent any number of users from constructing a particular piece of rig equipment if the user previously performed a task, sub-task, activity, or sub-activity corresponding to the piece of rig equipment and feedback and/or sensor data indicated that the task, sub-task, activity, or sub activity was performed incorrectly. For example, a user who maintained an incorrect position or location during a task, sub-task, activity, or sub-activity can be disqualified and removed from subsequent tasks, sub-tasks, activities, or sub-activities.

[0073] In some embodiments, a planner view for a well site manager or device can allow changes to be made to personnel drilling rig tasks if the workload of one user is greater than other users. The device can then communicate a dynamic work flow to any number of users indicating the execution view of the drilling rig task, wherein the execution view can include work instructions, images of a completed drilling rig task, tools to be used, and the like.

[0074] At block 308, the computing device can perform subsequent drilling rig tasks based on the revised digital hierarchy. In some embodiments, the computing device can also transmit the feedback and the sensor data from the digital assets to a remote server in real-time.

[0075] In some examples, the computing device can generate notifications based on the revised digital hierarchy and transmit the notifications to users during the execution of subsequent drilling rig tasks. For example, the computing device can transmit a notification to a selected user performing a drilling rig task based on a drilling rig task zone. In some embodiments, the drilling rig task zone can include an area in which the selected user is performing the drilling rig task or an adjacent area in which a second drilling rig task is being performed. In some examples, the notification can include a warning to the selected user. For example, the warning can indicate a high risk of residual damage from other activities being performed by other users. In some examples, the residual damage can include a falling object or a high risk of a valve malfunction due to an adjusted pressure of material flowing through the valve, among others.

[0076] In some embodiments, the computing device can also generate a user interface to display the digital hierarchy model. In some examples, the user interface includes drilling rig task information for the drilling rig task. The drilling rig task information can include a tool to complete the drilling rig task, a location for each user during the execution of the drilling rig task, and an image of a completed drilling rig task or a piece of equipment corresponding to the completed drilling rig task, among others. The user interface can enable verifying that a drilling rig task has been completed as expected. For example, the image can include a rotated valve, among other equipment. In some embodiments, the computing device can execute a machine learning technique to determine the rotated value is in an expected orientation based on the image. For example, the machine learning technique can be trained with images of the valve in various orientations and the trained machine learning technique can identify an amount of rotation of the valve. In some examples, the computing device can also execute a machine learning technique to determine a piece of equipment from an image captured by a user corresponds to the drilling rig task. For example, the machine learning technique can be trained to identify any number of tools and equipment associated with completing a drilling rig task. The trained machine learning technique can analyze images to determine if unnecessary tools or equipment are present in the environment in which a drilling rig task is being executed.

[0077] It is to be understood that the blocks of Figure 3 can be performed in any suitable order. Additionally, Figure 3 can include additional or fewer blocks. For example, the computing device can also forward a notification from a first user performing the drilling rig task to a second user performing the drilling rig task, wherein the notification indicates an environmental hazard. The environmental hazard can include toxic gases in an area, rising water, a danger of falling objects, and the like.

[0078] Figure 4 is a block diagram of an example digital hierarchy model. In some embodiments, a device, such as the computer system 501A of Figure 5, can generate the digital hierarchy model 400 based on the sequential workflows identified for various drilling rig tasks. The digital hierarchy model 400 can include activities 402, sub -activities 404, tasks 406, sub-tasks 408, and work instructions 410, which can be identified for any suitable job 412 such as a rig move, among others. After the initial identification of a job 412 to be completed, each work instruction 410 can be assigned information such as a personnel role, tools, and time applied to each activity 402, sub activity 404, task 406, and sub-task 408. In some examples, a device can track each task 406 and activity 402 of the move, and as the tasks 406 and activities 402 are closed, the overall percentage of the rig move completion increases. In some embodiments, activities 402 can be broken into simultaneous operations whereas tasks 406 may involve sequential sub-tasks 408 to be completed. [0079] In some examples, the activity 402 can include a rig down or a rig up action. The sub activities 404 for each activity 402 can include a center section action and a backyard action, among others. For example, the sub-activity 404 related to a center section can include tasks 406 such as lowering a sub, lowering a mast, disassembling a mast, disassembling a sub, and the like. In some embodiments, the sub-activity 404 related to a backyard action can include tasks 406 such as disassembling fluids, and disassembling power components, among others. In some embodiments, each task 406 can include any number of sub-tasks. For example, a task 406 for lowering a sub can correspond to a sub-task 408 that includes powering an HPU, removing a locking pin, and using a remote, among others. In some embodiments, a task 406 for lowering a mast can include sub-tasks 408 such as placing a mast stand, powering an HPU, and removing a rear shoe pin, among others. In some examples, each sub-task 408 can include work instructions 410 that include checklists that an individual would perform or oversee, among others. The work instructions 410 can include ensuring a tank has hydraulic fluid, filling a gas tank, starting an HPU, installing a memory car, and the like.

[0080] In some embodiments, a task 406 can include constructing a rig. A sub-task 408 can include setting up the various components of the rig such as the mud tank, drawworks, crown block, and the like. In some examples, the work instructions 410 can indicate each action to perform to set-up the components of the sub-tasks 408. In some embodiments, an activity 402 can include pulling equipment from a borehole or placing equipment in a borehole. For example, an activity 402 can include managing a pipe trip, among others. In some embodiments, work instructions 410 can indicate a position of a user during a sub-task 408 or sub-activity, and/or a description of actions to be performed, such as tools to be used, valves to be rotated, and the like. In some embodiments, a sub-task 408 can include setting up a spool, brakes, and a power source. The sub-task 408 can be associated with a task 406 of setting up drawworks. In some embodiments, the sub-task 408 can include the reeling of line over a crown block and/or coupling the line to a traveling block. In some examples, the sub-task 408 can include constructing a bottom hole assembly and/or attaching the bottom hole assembly to a drill string. Accordingly, activities 402 and tasks 406 can correspond to actions performed to set up a rig or during the operation of a rig. [0081] In some examples, by utilizing detailed work instructions 410 for each role on location, new users can integrate into their roles for a rig move. Typically, new users spend a significant amount of time around a rig and learn the rig extensively before being able to perform stand-alone tasks during a rig move. With rig moves occurring sporadically throughout the year, it is no guarantee that a new user will see enough rig moves to become competent within a period of time. The techniques herein enable new users to perform tasks 406 and activities 402 without extensive on-site training. For example, techniques herein enable virtual reality training environments. Furthermore, the techniques herein can also automate determining if ordered parts or equipment associated with a rig move are to be sent to the old rig location or the new rig location, depending on the status of the rig move.

[0082] It is to be understood that the digital hierarchy model 400 of Figure 4 is an example digital hierarchical model. In other examples, the digital hierarchy model 400 can include any number of additional or fewer tasks 406, activities 402, sub-activities 404, sub-tasks 408, and work instructions 410. In some examples, the tasks 406, activities 402, sub-activities 404, sub-tasks 408, and work instructions 410 can include managing any combination of the components illustrated in Figures 1 and 2. In some embodiments, a device can automate the execution of a task 406 with equipment that contains various parts and pieces that may need new components, as well as long time durations to complete the maintenance task. This can reduce the down time associated with performing these maintenance tasks during drilling operations, as well as optimize the time when parts should be sent to the rig site.

[0083] Figure 5 illustrates a flowchart of another method 500 for drilling task execution management, according to an embodiment. The method 500 may be a more detailed example of the method 300 discussed above, and thus methods 300 and 500 should not be considered mutually exclusive. The method 500 may include generating a digital hierarchy model (e.g., Figure 4) for executing one or more drilling activities, as at 502. In general, the digital hierarchy model may be generated based on historical data, e.g., previous iterations of completing the same or similar tasks. Since many tasks on a drilling rig are repeated many times, there may be a database of data to call upon, using various statistical analyses, in order to develop the digital hierarchy model. As described above and shown in Figure 4, the digital hierarchy model may begin, at its root, with a job 412. The job 412 may be partitioned into activities 402 (e.g., move a rig, assemble a rig, disassemble a rig, etc.).

[0084] Specialized knowledge from experienced workers might be required to accomplish such an activity from start to finish. To avoid calling for such expertise, the digital hierarchy model may partition the activities 402 into tasks 406 and partition the tasks 406 into sequence-dependent sub tasks 408, as at 504. Alternatively or additionally, the activities 402 may be partitioned into sub activities 404 and tasks 406. Both of these partitioning schemes may be considered partitioning the activities into tasks 406 (e.g., if a task 406 is sequence-dependent, it is referred to as a sub-task 408).

[0085] Examples of such tasks that may be involved in moving the rig may include surveying a destination path, e.g., using drones, and disconnecting the electrical and hydraulic connections in sequence, e.g., by concerted action of multiple workers, truck loads may be organized. After the move, the rig is reassembled in reverse order.

[0086] Work instructions may be associated with completing the tasks, as at 506. The instructions may be sequential, supplied to a specific person, e.g., working in a team, and may be relatively simple, as compared to activities or even tasks. Accordingly, the individual worker and/or a team of workers may carry out complex tasks with relatively little specialized knowledge or experience. Moreover, the instructions may set forth personnel, rules, tools, and time associated with the instructions and/or task. Such rules may include, for example in a rig-down operation, ensuring the hydraulic pump is off, locking out, bleeding pressure, verifying pressure is at 0, and disconnecting hydraulic lines.

[0087] Generating the model at 502 may further include assigning times for completing the tasks based on the historical data, as at 508. As noted above, this may be based on an average amount of time taken to perform the same or similar tasks previously, but may also use other statistical methods and/or may take into account additional factors such as different available tools, different worker experience, etc. In some embodiments, the digital hierarchy model may be generated on- the-fly, e.g., immediately before the activity is to commence; however, in other embodiments, the model may be generated before the activity is ready to be performed (e.g., as a standard template). [0088] The method 500 may proceed to assigning users to the tasks, as at 510. As noted above, the users may be assigned based on a user’s credentials (or otherwise being enabled) to operate various tools that may be called for to complete a particular task. The users may also be assigned based on an individual’s available capacity, supervisor rating, expertise, past experience, etc. [0089] Before the user commences performing a task, in some embodiments, job safety analysis (JSA) information may be provided to the user assigned to the task, as at 512. Such JSAs may provide safety data to the user to avoid hazards. Once the JSA is read or otherwise completed, the user may provide input at 514 that the JSA has been reviewed.

[0090] In response to the JSA being completed (or any other trigger), the method 500 may include providing the work instructions to the users for completion of the tasks assigned thereto, as at 516. As noted above, some activities or tasks are or include multiple sub-tasks that are sequence dependent, i.e., completion of a second task cannot start until after a first task is completed. Accordingly, the work instructions may be provided based on such sequence, to enforce the execution of tasks in the sequence. That is, the instructions for completion of the second sub-task may not be provided until the first sub-task is complete. The instructions may be provided to the user on a remote or mobile computing device, e.g., in a just-in-time basis, so that the user receives an instruction when it is time to follow that instruction.

[0091] Furthermore, the method 500 may include the ability to monitor and correct the user as the user performs tasks in accordance with the instructions. For example, the method 500 may include receiving user input and/or sensor feedback that a user has begun execution of a task, as at 518. The sensor feedback may be provided by rig sensors, e.g., at the drawworks, crown block, top drive, etc., which may generally indicate a change in rig state. The sensor feedback may also or instead be from digital assets associated directly with individual users or individual tasks, e.g., a camera, GPS, smart phone, tablet, or radiofrequency identification (RFID) tag, indicating that a user has entered a certain area or is performing a certain task.

[0092] In some embodiments, the method 500 may include communicating with such a digital asset to monitor the user’s work progress, as at 520. In some cases, this may include providing video or still images to a centralized command center, which may be staffed with experts able to quickly determine if a user is performing an operation correctly. In some embodiments, machine learning may be employed to verify operations based on visual images/video, e.g., to determine if a valve is properly rotated, etc.

[0093] The method 500 may also include receiving user input and/or sensor feedback indicating that a user has completed execution of the task (or an individual work instruction), as at 522. This may proceed, for example, by a user checking off boxes or otherwise indicating that a work instruction of a task, or the task itself, is complete. Additionally or alternatively, rig sensors and/or digital assets associated with the user may be employed to automatically verify and/or independently determine completion of an instruction and/or task.

[0094] Once a task is completed, if additional tasks to which the user is assigned are yet to be completed, the method 500 may loop back to providing a JSA for the next task or otherwise providing work instructions for the next task. Otherwise, the method 500 may be configured to assign the user to another task. Further, the method 500 may be configured to provide a load balancing feature among the rig workers. Thus, for example, if a first rig worker has available capacity and another has reached or is exceeding capacity, one or more tasks assigned to the second rig worker may be reassigned to the first rig worker, as at 524 Such load-balancing may be based at least in part on the time allotted for the individual tasks. The load-balancing may also be based on a historical completion time associated with the individual worker. In this way, individual worker non-productive time may be reduced.

[0095] In addition, the execution of the tasks as part of the method 500 may be added to the historical data for subsequent uses/generations of the digital hierarchy model. As such, the model 526 may be updated/adjusted based on the experience with each individual task completion. Further, the model itself may be updated on the fly, in real-time, depending on, for example, how well the model is anticipating completion times (e.g., if completion times are consistently taking longer than allotted, the time-allotment may be changed; moreover, other drilling factors may be flagged as causing the delays).

[0096] In some embodiments, maintenance may be scheduled based on the digital hierarchy model. For example, the scheduling of tasks may reveal downtime for a particular piece of equipment, i.e., when it is not being used, e.g., because it is associated with a second sub-task and a first sub-task is being performed. Accordingly, the method 500 may include scheduling maintenance at such an opportune time, which may avoid non-productive rig time by performing maintenance when the piece of rig equipment is not otherwise in use. Further, the digital hierarchy model may be configured to determine a location of the rig, e.g., by scheduling moves. Thus, supplies, parts, personnel, etc., may be scheduled for delivery in the future where the rig will be located. [0097] In some embodiments, the methods of the present disclosure may be executed by a computing system. Figure 6 illustrates an example of such a computing system 600, in accordance with some embodiments. The computing system 600 may include a computer or computer system 601A, which may be an individual computer system 601A or an arrangement of distributed computer systems. The computer system 601A includes one or more analysis modules 602 that are configured to perform various drilling rig tasks according to some embodiments, such as one or more methods disclosed herein. To perform these various drilling rig tasks, the analysis module 602 executes independently, or in coordination with, one or more processors 604, which is (or are) connected to one or more storage media 606. The processor(s) 604 is (or are) also connected to a network interface 607 to allow the computer system 601 A to communicate over a data network 609 with one or more additional computer systems and/or computing systems, such as 60 IB, 601C, and/or 60 ID (note that computer systems 60 IB, 601C and/or 60 ID may or may not share the same architecture as computer system 601A, and may be located in different physical locations, e.g., computer systems 601 A and 601B may be located in a processing facility, while in communication with one or more computer systems such as 601C and/or 60 ID that are located in one or more data centers, and/or located in varying countries on different continents).

[0098] A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.

[0099] The storage media 606 may be implemented as one or more non-transitory computer- readable or machine-readable storage media. Note that while in the example embodiment of Figure 6 storage media 606 is depicted as within computer system 601A, in some embodiments, storage media 606 may be distributed within and/or across multiple internal and/or external enclosures of computing system 601A and/or additional computing systems. Storage media 606 may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY ^® disks, or other types of optical storage, or other types of storage devices. Note that the instructions discussed above may be provided on one non-transitory computer-readable or machine-readable storage medium, or alternatively, may be provided on multiple non-transitory computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes. Such non-transitory computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture). An article or article of manufacture may refer to any manufactured single component or multiple components. The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.

[0100] In some embodiments, the computing system 600 contains one or more task manager module(s) 608. In the example of computing system 600, computer system 601 A includes the task manager module 608. In some embodiments, a single task manager module may be used to perform some or all aspects of one or more embodiments of the methods disclosed herein. In alternate embodiments, a plurality of task manager modules may be used to perform some or all aspects of methods herein.

[0101] It should be appreciated that computing system 600 is one example of a computing system, and that computing system 600 may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of Figure 6, and/or computing system 600 may have a different configuration or arrangement of the components depicted in Figure 6. The various components shown in Figure 6 may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.

[0102] Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices. These modules, combinations of these modules, and/or their combination with general hardware are all included within the scope of protection of the embodiments herein. [0103] The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously. The embodiments were chosen and described in order to explain at least some of the principles of the disclosure and their practical applications, to thereby enable others skilled in the art to utilize the disclosed methods and systems and various embodiments with various modifications as are suited to the particular use contemplated.