SYSTEM AND METHOD FOR EVALUATING AND DISPLAYING DOWNHOLE TOOL STRING OPERABILITY CONDITIONS

A computer-implemented method/arrangement for rapidly assessing operable conditions of each constituent tool of a MWD tool string between two consecutive downhole runs of a drill string. The method includes filtering binary data downloaded from a recently pulled MWD tool string for data sets that each represent conditions indicative of the operational condition of each of the several tools of the MWD tool string. For each of the data sets, a processing algorithm is selected from a store of predetermined algorithms, based on characteristics of the respective data set. Each data set is substantially simultaneously processed with the algorithm selected for that data set. Based on respective tool-condition data output by each algorithm-processed data set, determining whether the tool that corresponds to the respective data set meets a predetermined operational capability requirement or threshold to be operated in a subsequent run downhole with the drill string.

TECHNICAL FIELD

The present disclosure generally relates to the evaluation of the performance of drilling tools, and more specifically recommending whether to rerun a drilling tool.

BACKGROUND

Oilfield operators perform a series of operations to obtain a producing well. Illustrative operations include drilling a borehole, obtaining logging measurements, inserting casing, cementing the casing in place, perforating the casing at selected points, and/or fracturing the formation. These operations generally require monitoring the drill tool. When a drill tool is active and downhole, monitoring its performance and operational condition can be difficult. Failure to properly monitor the drill tool can lead to inefficient operation, and even complete failure resulting in costly repairs and down time.

DETAILED DESCRIPTION

Certain aspects and examples of this disclosure are provided below. Some of these aspects and embodiments may be applied independently and some of them may be applied in combination as would be apparent to those of skill in the art. In the following description, for the purposes of explanation, specific details are set forth to provide a thorough understanding of embodiments of the application. However, it will be apparent that various embodiments may be practiced without these specific details. The figures and description are not intended to be restrictive.

In typical oil and gas drilling applications, a well bore is drilled to reach a reservoir. The well bore may include multiple changes in direction and may have sections that are vertical, slanted, or horizontal. A well bore casing is placed in the well bore to provide structure and support for the earthen well bore. The oil, gas, and/or other fluid deposit is then pumped out of the reservoir, through the well bore casing, and to the surface, where it is collected.

The well bore is often drilled using a drill string made up of tubular (e.g., drill pipe) and having a bottom hole assembly (“BHA”) that includes a drill bit at the distal end of the drill string. Drilling mud is conventionally circulated down the borehole through the drill string, out through the drill bit, and up an annulus between the tubular and the borehole wall. The drilling mud performs a number of functions, including cooling the drill bit and carrying cuttings to the surface. In some drilling systems, measurement while drilling (“MWD”) tool string or logging while drilling (“LWD”) tools are mounted in or close to the BHA to monitor the weight on bit, torque on bit, bending moment applied to the bit, and other related aspects of the drilling assembly. In this description, MWD and LWD are used interchangeably and the composition of the MWD tool string can include one or more constituent tools or sub-components. The MWD/LWD tool string provides information (data) to equipment at the surface and which can include real-time measurements of such things as weight, bending moment, vibration, and the like sensed by the MWD tool string. The data provided by the MWD tool string can be voluminous in nature because each of the measuring components of the tool string produces its own set(s) of data. The data provided by each component of the tool string will be relevant to certain diagnostic activities, but not to others. Therefore, when considering any one specific diagnostic activity or test, much of the received data is irrelevant for that particular analysis.

The presently disclosed technology provides solutions for efficiently processing the voluminous MWD/LWD data for assessing the operable condition of each of the constituent tools in the MWD tool string. More particular, these solutions enable the determination of whether individual components of the tool string meet predetermined operational metrics for continued use (next run downhole) in the drilling process without repair or refurbishment. Still further, these solutions provide for and facilitate a visible display representing the health and/or other sensed characteristics of the components of the MWD tool string. In these ways the present technology enhances the speed and efficiency of observing and evaluating the health and operating capabilities of the MWD tool string as a whole, or at the level of the tool sting's constituent components.

The instant descriptions are provided as exemplary examples only and are not intended to limit the scope, applicability, or configuration of the claimed methods and arrangements. Rather, disclosure of the technology via the exemplary examples provides those skilled in the art with sufficient description to enable their implementation of the solutions described herein. Regarding the present written description, the articles “a,” “an,” “the,” and “said” are intended to mean that there are one or more of the so-described elements. The terms “comprising,” “including,” and “having” are open-ended and are intended to be inclusive and mean that there may be additional elements other than those listed. Furthermore, any numerical examples in the following discussion are intended to be non-limiting, and thus additional numerical values, ranges, and percentages are within the scope of the disclosed examples.

Further, while this disclosure describes a land-based drilling system, it will be understood that the equipment and techniques described herein are applicable in sea-based systems, multilateral wells, all types of drilling systems, all types of rigs, measurement while drilling (MWD)/logging while drilling (LWD) environments, wired drill pipe environments, coiled tubing (wired and unwired) environments, wireline environments, and similar settings and environments.

The disclosure now turns toFIGS.1A-B, andFIG.2to provide a brief introductory description of the larger systems that can be employed to practice the concepts, methods, and techniques disclosed herein. A more detailed description of the methods and systems for implementing the improved semblance processing techniques of the disclosed technology will then follow.

FIG.1Adepicts an illustrative drilling environment100. As illustrated, drilling platform102supports derrick104having traveling block106for raising and lowering drill string108. Kelly110supports drill string108as it is lowered through rotary table112. Drill bit114is driven by a downhole motor and/or rotation of drill string108. As bit114rotates, it creates a borehole116that passes through various formations118. Pump120circulates drilling fluid through a feed pipe122to Kelly110, downhole through the interior of drill string108, through orifices in drill bit114, back to the surface via the annulus around drill string108, and into retention pit124. The drilling fluid transports cuttings from the borehole into pit124and aids in maintaining borehole integrity.

Downhole tool126can take the form of a drill collar (i.e., a thick-walled tubular that provides weight and rigidity to aid the drilling process) or other arrangements known in the art. Further, downhole tool126can include various sensor and/or telemetry devices, including but not limited to: acoustic (e.g., sonic, ultrasonic, etc.) logging tools and/or one or more magnetic directional sensors (e.g., magnetometers, etc.). In this manner, as bit114extends the borehole through formations118, the bottom-hole assembly (e.g., directional systems, and acoustic logging tools) can collect various types of logging data. For example, acoustic logging tools can include transmitters (e.g., monopole, dipole, quadrupole, etc.) to generate and transmit acoustic signals/waves into the borehole environment. These acoustic signals subsequently propagate in and along the borehole and surrounding formation and create acoustic signal responses or waveforms that are received/recorded by evenly spaced receivers. These receivers may be arranged in an array and can be evenly spaced apart to facilitate capturing and processing acoustic response signals at specific intervals. The acoustic response signals are further analyzed to determine borehole and adjacent formation properties and/or characteristics.

For purposes of communication, a downhole telemetry sub128can be included in the bottom-hole assembly to transfer measurement data to surface receiver130and to receive commands from the surface. In some implementations, mud pulse telemetry may be used for transferring tool measurements to surface receivers and receiving commands from the surface; however, other telemetry techniques can also be used without departing from the scope of the disclosed technology. In some embodiments, telemetry sub128can store logging data for later download at the surface when the logging assembly is recovered. These logging and telemetry assemblies consume power, which must often be routed through the directional sensor section of the drill string, and which can produce stray EM fields which interfere with the magnetic sensors.

At the surface, surface receiver130can receive and uplink signal from downhole telemetry sub128and can communicate the signal to data acquisition module132. Module132can include one or more processors, storage mediums, input devices, output devices, software, and the like as described in further detail below. Module132can collect, store, and/or process the data received from tool126as described herein.

At various times during the drilling process, such as between two consecutive downhole runs, drill string108may be removed from the borehole as shown in example environment101, illustrated inFIG.1B. Once drill string108has been removed, logging operations can be conducted using a logging tool134(i.e., a sensing instrument sonde) suspended by a conveyance142. In one or more embodiments, the conveyance142can take the form of a cable having conductors for transporting power to the tool and telemetry from the tool to the surface. Logging tool134may have pads and/or centralizing springs to maintain the tool near the central axis of the borehole or to bias the tool towards the borehole wall as the tool is moved downhole or toward the surface.

Logging tool134can include various directional and/or acoustic logging instruments that collect data within borehole116. A logging facility144includes a computer system, such as those described with reference toFIG.6, discussed below, for collecting, storing, and/or processing the measurements gathered by logging tool134. In one or more embodiments, the conveyance142of logging tool134can be at least one of wires, conductive or non-conductive cable (e.g., slickline and the like), as well as tubular conveyances, such as coiled tubing, pipe string, and/or downhole tractor. Logging tool134can have a local power supply, such as batteries, downhole generator and the like. When employing non-conductive cable, coiled tubing, pipe string, or downhole tractor, communication can be supported using, for example, wireless protocols such as EM, acoustic and the like, and/or measurements and logging data can be stored in local memory for subsequent retrieval.

AlthoughFIGS.1A and1Bdepict specific borehole configurations, it is understood that the present disclosure is equally well suited for use in wellbores having other orientations including vertical wellbores, horizontal wellbores, slanted wellbores, multilateral wellbores and the like. WhileFIGS.1A and1Bdepict an onshore operation, it should also be understood that the present disclosure is equally well suited for use in offshore operations. Moreover, the present disclosure is not limited to the environments depicted inFIGS.1A and1Band can also be used in either logging-while-drilling (LWD) or measurement while drilling (MWD) operations.

Turning now toFIG.2, an example fracturing system200is shown. The example fracturing system200shown inFIG.2can be implemented using the systems, methods, and techniques described herein. In particular, the disclosed system, methods, and techniques may directly or indirectly affect one or more components or pieces of equipment associated with the example fracturing system200, according to one or more embodiments. Fracturing system200includes a fracturing fluid producing apparatus220, a fluid source230, a solid source240, and a pump and blender system250. All or an applicable combination of these components of the fracturing system200can reside at the surface at a well site/fracturing pad where a well260is located.

During a fracturing job, the fracturing fluid producing apparatus220can access the fluid source230for introducing/controlling flow of a fluid such as fracturing fluid in the fracturing system200. While only a single fluid source230is shown, the fluid source230can include a plurality of separate fluid sources. Further, the fracturing fluid producing apparatus220can be omitted from the fracturing system200. In turn, the fracturing fluid can be sourced directly from the fluid source230during a fracturing job instead of through the intermediary fracturing fluid producing apparatus220.

The fracturing fluid can be an applicable fluid for forming fractures during a fracture stimulation treatment of the well260. For example, the fracturing fluid can include water, a hydrocarbon fluid, a polymer gel, foam, air, wet gases, and/or other applicable fluids. In various embodiments, the fracturing fluid can include a concentrate to which additional fluid is added prior to use in a fracture stimulation of the well260. In certain embodiments, the fracturing fluid can include a gel pre-cursor ahead of a fluid (such as liquid or substantially liquid) from fluid source230. Accordingly, the gel pre-cursor with fluid can be mixed by the fracturing fluid producing apparatus220to produce a hydrated fracturing fluid for forming fractures.

Solid source240can include a volume of one or more solids for mixture with a fluid, such as fracturing fluid, to form a solid-laden fluid. The solid-laden fluid can be pumped into the well260as part of a solids-laden fluid stream that is used to form and stabilize fractures in the well260during a fracturing job. The one or more solids within the solid source240can include applicable solids that can be added to the fracturing fluid of the fluid source230. Specifically, the solid source240can contain one or more proppants for stabilizing fractures after they are formed during a fracturing job, such as after the fracturing fluid flows out of the formed fractures. For example, the solid source240can contain sand, bauxite, other mined materials, manufactured ceramic or other materials, or combinations thereof.

Fracturing system200can also include additive source270. The additive source270can contain/provide one or more applicable additives that can be mixed into fluid, such as fracturing fluid, during a fracturing job. For example, the additive source270can include solid-suspension-assistance agents, gelling agents, weighting agents, and/or other optional additives to alter the properties of the fracturing fluid. The additives can be included in the fracturing fluid to reduce pumping friction, to reduce or eliminate the fluid's reaction to the geological formation in which the well is formed, to operate as surfactants, and/or to serve other applicable functions during a fracturing job. As will be discussed in greater detail later, the additives can function to maintain solid particle suspension in a mixture of solid particles and fracturing fluid as the mixture is pumped down the well60to one or more perforations.

The pump and blender system250functions to pump fracture fluid into the well260. Specifically, pump and blender system250can pump fracture fluid from fluid source230, such as fracture fluid that is received through the fracturing fluid producing apparatus220and into the well260for forming and potentially stabilizing fractures as part of a fracture job. Pump and blender system250can include one or more pumps. Specifically, the pump and blender system250can include a plurality of pumps that operate together; for example, concurrently to form fractures in a subterranean formation as part of a fracturing job. The one or more pumps included in the pump and blender system50can be an applicable type of fluid pump. For example, the pumps in the pump and blender system250can include electric pumps and/or hydrocarbon and hydrocarbon mixture powered pumps. Specifically, the pumps in the pump and blender system250can include electric pumps, diesel powered pumps, natural gas powered pumps and diesel combined with natural gas powered pumps.

The pump and blender system250can also function to receive the fracturing fluid and combine it with other components and solids. Specifically, the pump and blender system250can combine the fracturing fluid with volumes of solid particles, such as proppant, from the solid source240and/or additional fluid and solids from the additive source270. In turn, the pump and blender system250can pump the resulting mixture down the well260at a sufficient pumping rate to create or enhance one or more fractures in a subterranean zone, for example, to stimulate production of fluids from the zone. While the pump and blender system250is described to perform both pumping and mixing of fluids and/or solid particles, in various embodiments, the pump and blender system250can function to just pump a fluid stream, such as a fracture fluid stream, down the well260to create or enhance one or more fractures in a subterranean zone.

The fracturing fluid producing apparatus220, fluid source230, and/or solid source240may be equipped with one or more monitoring devices (not shown). The monitoring devices can be used to control the flow of fluids, solids, and/or other compositions to the pumping and blender system250. Such monitoring devices can effectively allow the pumping and blender system250to source from one, some or all of the different sources at a given time. In turn, the pumping and blender system250can provide only fracturing fluid into the well at some times, just solids or solid slurries at other times, and combinations of those components at yet other times.

FIG.3illustrates a block diagram of an example system300configured to recommend whether to run a MWD tool string again or return the MWD tool string to a shop for maintenance or refurbishment. In one example, the system300includes a MWD tool310. In another aspect, the MWD tool can include a logging tool facility144, a logging tool134and/or a downhole tool126, all capable of collecting data within borehole116as discussed above. In one example, the collection of data can be conducted simultaneously during drilling operation or in between series of drilling operations. The data collected by the MWD tool310is generally in the format of binaries. In some aspects, the binary data321can encompass all data related to the wellbore operation including both relevant diagnostic data in relation to the MWD tool string and irrelevant data such as customer data, log data and non-diagnostic data.

After the MWD tool310collects data within borehole116, the system300advances to the analytical electronic device320. In one aspect, the electronic device320performs one or more data-analytic processes to assist or produce a determination as to whether or not run the MWD tool string downhole again, or send it back for maintenance, repair or refurbishment. For example, the electronic device320can determine the tool's operational capability concerning whether to be sent downhole again in a subsequent run of the tool string based on processing the binary data321. In at least one aspect, the binary data321can be downloaded or outputted from the MWD tool310to the electronic device320. The electronic device320then applies a filter322to the binary data321. In one example, the filter322sifts the binary data321and segregates it into data sets that individually constitute a diagnostic data set that can be processed to determine the operational capability of respective ones of the constituent tool of the MWD tool string. By way of example, operational capability or condition can include information about the health, fitness, and/or capability to operate properly of any one or more of the components that make-up the MWD tool string.

In some instances, data retrieved from certain components of the tool string becomes the diagnosable or diagnostic data that upon analysis, indicates the operational capability/condition of the component from which the data was retrieved/received. In other instances, the analysis may be of data from one or more components, but is predictive of an overall condition of the MWD tool string. Examples of such data represent such operational conditions as vibration, current and voltage. In another aspect, the diagnostic data can represent information that is beneficial to certain persons, depending upon the role they fulfill, examples of which can include field engineer, shop technician or system engineer. For instance, the diagnostic data can provide useful information to a field engineer at a sensitive time during which a determination must be made as to whether or not to run the tool string (or tool string component) downhole again or send it out for service/refurbishment. In another example, the diagnostic data can provide useful information to a shop technician in determining and/or to diagnose what constituent tool of a MWD tool string to repair or replace. In another example, the diagnostic data can provide useful information to a system engineer for designing and/or modifying future designs of the MWD tool string or its components in order to remedy existing deficiencies or incorporate improvements.

After filtering322the binary data321into data sets (e.g., the data sets each representing a singular tool of the MWD tool string as a whole), in one example, the data sets of each respective constituent tool of the MWD tool string can be converted to engineering units by known data processing techniques or processes known in the art. Such conversion facilitates and enables the benefits of data analysis and reporting. Upon completion of processing323the data into data sets, the data sets can be input into a post processing orchestrator324.

The post processing orchestrator324, in at least one aspect, can accommodate and/or receive filters, algorithms, and diagnostic assessments325either directly or indirectly through a runtime plugin333. In some examples, the filters, algorithms, and diagnostic assessments325are unique and/or predetermined to apply to specific data sets based on characteristics of the data sets. For example, certain filters, algorithms and diagnostic assessments325can be applied to a data set of a particular constituent component of the tool string to derive quantifications of vibration, rotation, temperature, voltage, current and the like concerning that component tool of the MWD tool string, or the tool string in its entirety. The filters, algorithms, and diagnostic assessment325can be stored in advance prior to inputting the algorithms, filters, and/or diagnostic assessment325into the post processing orchestrator324either directly or indirectly through a runtime plugin333.

The runtime plugin333, in some examples, can be configured to permit updating of the post processing orchestrator324with revised, new, and/or updated algorithms, filters, and/or diagnostic assessment. In one instance, the filters, algorithms, and diagnostic assessment325can be updated or new algorithms, filters, and/or diagnostic assessments can be inserted. In such an example, the runtime plugin333can receive the newly updated algorithms, filters, and/or diagnostic assessments from the filters, algorithms, and diagnostic assessment325which can be outputted into the post processing orchestrator324. Updating the post processing orchestrator324via the runtime plugin333improves the speed of deployment of the new algorithms, filters, and/or diagnostic assessment without having to recompile a new software in its entirety or reprogram an original software and similarly permits instructions to be executed by a processor of the electronic device320. Additionally, the runtime plugin333can be configured to receive and utilize additional algorithms that helps drive displayable visualizations of operable conditions of constituent tool of the MWD tool string. This can eliminate the need to shut down the drilling operation or minimize potential downtime to perform an update to the post processing orchestrator324or introduce new filters, algorithms, and/or diagnostic assessments into the system300.

The post processing orchestrator324, in one example, can process (via a local and/or remote processors326) the data sets inputted from the data processing323with filters, algorithms, and/or diagnostic assessments inputted from the runtime plugin333and/or from the filters, algorithms, and diagnostic assessment325to the post processing orchestrator324. For instance, a data set can be processed using an algorithm specifically selected for that data set. In such example, the processor can output a detailed analysis327including tool-condition data yielded by the now algorithm-processed data set. The tool-condition data can correspond to a respective constituent tool. In some aspects, the tool-condition data can represent the health, characteristics, and the like of a respective constituent tool.

The processor326, in some examples, can proceed to determine whether the tool-condition data meets a predetermined operational capability threshold (requirement) to be operated in an immediately subsequent run of the tool string. The operational capability requirement, in some examples, can include a set threshold regarding the health, characteristic, quality, potential, and the like of a constituent tool of the MWD tool string to undergo redeployment and perform a subsequent run. Exemplarily, the threshold level can be predetermined/preset. The process to determine whether the tool meets a predetermined operational capability requirement can be determined by an algorithm or a human end user (e.g., field engineer, system engineer, and/or shop technician).

The processor326, in some examples, can be a local processor such as an electronic device320located at the rig site. In another example, the processor can be a remote processor such as in a virtual processing environment340and/or an electronic device320located off site. The remote processor can be one or more virtual processor340. In such example, the remote and local processor(s) can work synchronously (i.e., multi-processing and/or concurrent processing). In this regard, synchronization is defined as several processes accessing and processing data sets concurrently. That is, the several processors326(local processor on an on-site electronic device320and remote processor340) can process data simultaneously in parallel, in series, or in any combination thereof. This configuration facilitates the desired scalability that enables rapidly assessing the operatable condition of the MWD tool string, or its constituent components, by running multiple processors simultaneously. Each constituent component tool can encompass very large amounts of data distilled down into data sets comprising gigabytes of data. This tandem configuration permits multiple processors326to access and process data synchronously, thereby increasing the efficiency and speed of determining the operable condition of the members of the MWD tool string (or the string itself) in order to determine whether to re-run the tool, or even just lay one component out, but run the tool again on the next downhole trip.

Upon the processor326processing the data sets into tool-condition data of the respective constituent tools, the system300can proceed to render visualizations of the deduced tool conditions based on outputs from the processor326via a specialty visualizer328. By way of example, the specialty visualizer328can display each constituent tool of the MWD tool string. Such display or visible representation, for example, can display a recommendation329of whether a subsequent run of the tool string based on the respective tool-condition data meet a predetermined operation capability threshold or other predetermined requirement. In such example, the constituent tools of the MWD tool string can be individually displayed. In some aspects, the recommendation329can yield a Go Status Visualization330A (accompany the next downhole trip) or a No-Go Status Visualization330B (return the tool to the shop for maintenance). The visualization of the individual constituent tools, in some examples, can be color-coded to discriminate between Go and No-Go Status. The visualization of the individual constituent tool, in another example, can include a second color to indicate the respective constituent tool is not capable of a subsequent run. In other aspects, text or symbols can be used to indicate the capability of the constituent tool to be run in on the next trip downhole.

The specialty visualizer328, in at least one example, can provide a further visualization based on a detailed description of the MWD tool string. The visualization based on the detailed description can include a drill-down or drop-down menu. For example, the visualization based on a detailed description can display an entire MWD tool string that is broken down into its respective constituent parts and depict such characteristics as vibration, voltage, current and the like. In another example, the characteristic(s) of the respective constituent tool can be displayed in waveforms.

The disclosure now turns toFIGS.4A-4Cand provides examples of specialization visualizations328that can be employed to practice the concepts, methods, and techniques disclosed herein. Referring toFIG.4A, the specialized visualization illustrates the detailed analysis327in an overview configuration400A (e.g., an abstracted/macro detailed analysis of the MWD tool string). In one example, the overview configuration400A can display some or all the individual constituent tools402A of the tool string401A in an exploded manner403A. The individual constituent tools402A can be displayed in a first color indicating the respective tool being capable to make a subsequent run. In another aspect, the individual constituent tools402A can be displayed in a second color indicating the respective tool being incapable of taking a subsequent run and/or recommending the return of that tool to the shop for maintenance330B. Other characteristics of the tool string401A that can be represented and displayed are: (i) data gaps404A, (ii) vibration405A, (iii) voltage406A, (iv) current407A, (v) temperature408A, (vi) rotation per minute (RPM)409A, (vii) sub bus communication efficiency410A, and (viii) burst communication efficiency411A. Such display, by way of example can be in the form of symbols (e.g., check marks and x marks) to illustrate Go330A or No-Go330B recommendations, gauges (e.g., temperature408A and RPM409A), and bar charts (sub bus communication efficiency410A, burst communication efficiency411A).

The overview configuration400A, in some instances, can be interactive wherein a user may select an individual constituent tool402A of the tool string401A for a second level analysis400B or a further detailed analysis on the respective subcomponents401B (seeFIG.4B). The second level analysis400B, by way of example, can display the overall subcomponents401B of the individual constituent tool402A. The subcomponents401B, in some examples, can be displayed in a manner to illustrate the health of the subcomponents. For example, the subcomponents401B can be displayed in a first color indicating the respective subcomponent's capability to make the next downhole run. In another aspect, the subcomponents401B can be displayed in a second color indicating the respective subcomponent is incapable of a subsequent run and must be returned to the shop for maintenance/repair330B.

Specific characteristics of the different constituent tools402A can be displayed in a similar manner as the characteristics of the overview configuration400A are displayed as described above. The individual characteristics can further include, by way of example, the present and maximum current402B, voltage403B, RPM404B, and temperature405B of the subcomponents401B.

FIG.4Cillustrates a third type or level of analysis display representing various characteristics-of-interest of one or more tool string subcomponents401B wherein the several representative waveforms can be vertically aligned with respect to time. The display ofFIG.4Ccan be initiated by user interaction with the display ofFIG.4B, or otherwise selected such as via a keyboard and/or mouse. In this regard, the displays ofFIGS.4A and4Bcan be touch-sensitive thereby permitting a user to touch-select a particular sub-component or specific tool characteristic (e.g., current402B, voltage403B, RPM404B and temperature405B) for display in greater detail. By way of example,FIG.4Cillustrates vibration as the selected characteristic for display in greater detail. In the example, vibration is displayed in the waveforms401C. Exemplarily, the waves401C can each be displayed in a variety of colors. A first color404C (red, for example) can be used as a flag that signals to a user (shop tech, system engineer, operator) display of an operational aspect of concern. A second color405C (green, for example) can be used to indicate an operational aspect that is operating within acceptable levels (tool vibration, for instance). At the top ofFIG.4C, the continuum of time applicable to the several waveforms is denoted by time-bar402C. Binary characteristics such as ON/OFF activity, as in the instance of pump operation, is illustrated by the vertical bars403C. Another waveform401C inFIG.4Cillustrates a concerning characteristic related to tool vibration; that is, tool-stick and/or tool-slip which cause deleterious, uneven tool/string rotation. As shown and described,FIGS.4A-Cuniquely illustrate operational aspects and conditions of a MWD tool string and/or its constituent components that are instantaneously recognizable and useful to users, both seasoned and inexperienced. These information-rich displays are to be compared to previously available data in binary format which was decipherable only by the most experienced, after detailed study, and taking time, which is often unavailable.

FIG.5is a flowchart illustrating an exemplary process5000for assessing the operable condition of each of the constituent tools of a MWD tool string. At block5002, the process5000includes utilizing a computer processor, filtering binary data downloaded from a recently pulled MWD tool string for data sets that represent conditions indicative of the operational condition of a respective one of a plurality of tools of the tool string.

At block5004, the process5000includes selecting, for each of the data sets, a processing algorithm from a store of predetermined algorithms, based on characteristics of the respective data set. In some aspects, the store of predetermined algorithms can include a plugin configured to receive one or more new algorithms or visualizations.

At block5006, the illustrated process5000includes processing, substantially simultaneously, each data set with the algorithm selected for that data set. The computer processor can process the data sets synchronously. In some embodiments, the computer processor includes one or more virtual processors/servers housed in a cloud-based environment.

At block5008, the process5000includes determining, based on respective tool-condition data output by each algorithm-processed data set, whether the tool that corresponds to the respective data set meets a predetermined operational capability requirement (threshold) to be operated (included) in the next downhole run of the drill string. GO/NO GO recommendations can be visually displayed for instantaneous operator appreciation. Other operational aspects can also be visually represented and configured to be user interactive for easy navigation and aspect drill-down, often via engageable drop-down menus.

In some examples, the process can include recommending at least a go or no-go decision based on the determination of whether the tool that corresponds to the respective data set meets a predetermined operational capability requirement to be operated in the subsequent run of the MWD tool string.

FIG.6illustrates an example apparatus (e.g., a processor-based system) with which some aspects of the subject technology can be implemented. For example, processor-based system600can be any computing device making up electronic device320and/or the virtual processing environment340, as discussed above with respect toFIG.3.

Example system600includes at least one processing unit (CPU or processor)610and connection605that couples various system components including system memory615, such as read-only memory (ROM)620and random-access memory (RAM)625to processor610. Computing system600can include a cache of high-speed memory612connected directly with, in close proximity to, or integrated as part of processor610.

Processor610can include any general-purpose processor and a hardware service or software service, such as services632,634, and636stored in storage device630, configured to control processor610as well as a special-purpose processor where software instructions are incorporated into the actual processor design. Processor610may essentially be a completely self-contained computing system, containing multiple cores or processors, a bus, memory controller, cache, etc. A multi-core processor may be symmetric or asymmetric.

To enable user interaction, computing system600includes an input device645, which can represent any number of input mechanisms, such as a microphone for speech, a touch-sensitive screen for gesture or graphical input, keyboard, mouse, motion input, speech, etc. Computing system600can also include output device635, which can be one or more of a number of output mechanisms known to those of skill in the art. In some instances, multimodal systems can enable a user to provide multiple types of input/output to communicate with computing system600.

Computing system600can include communications interface640, which can generally govern and manage the user input and system output. The communication interface may perform or facilitate receipt and/or transmission wired or wireless communications via wired and/or wireless transceivers, including those making use of an audio jack/plug, a microphone jack/plug, a universal serial bus (USB) port/plug, an Apple® Lightning® port/plug, an Ethernet port/plug, a fiber optic port/plug, a proprietary wired port/plug, a BLUETOOTH® wireless signal transfer, a BLUETOOTH® low energy (BLE) wireless signal transfer, an IBEACON® wireless signal transfer, a radio-frequency identification (RFID) wireless signal transfer, near-field communications (NFC) wireless signal transfer, dedicated short range communication (DSRC) wireless signal transfer, 802.11 Wi-Fi wireless signal transfer, wireless local area network (WLAN) signal transfer, Visible Light Communication (VLC), Worldwide Interoperability for Microwave Access (WiMAX), Infrared (IR) communication wireless signal transfer, Public Switched Telephone Network (PSTN) signal transfer, Integrated Services Digital Network (ISDN) signal transfer, 3G/4G/5G/LTE cellular data network wireless signal transfer, ad-hoc network signal transfer, radio wave signal transfer, microwave signal transfer, infrared signal transfer, visible light signal transfer, ultraviolet light signal transfer, wireless signal transfer along the electromagnetic spectrum, or some combination thereof.

Storage device630can include software services, servers, services, etc., that when the code that defines such software is executed by the processor610, it causes the system to perform a function. In some embodiments, a hardware service that performs a particular function can include the software component stored in a computer-readable medium in connection with the necessary hardware components, such as processor610, connection605, output device635, etc., to carry out the function.

The various examples described above are provided by way of illustration only and should not be construed to limit the scope of the disclosure. For example, the principles herein apply equally to optimization as well as general improvements. Various modifications and changes may be made to the principles described herein without following the example aspects and applications illustrated and described herein, and without departing from the spirit and scope of the disclosure.