US20150014056A1

US20150014056A1 - Dynamic response apparatus and methods triggered by conditions

Info

Publication number: US20150014056A1
Application number: US14/325,600
Authority: US
Inventors: Matthew White; Kevin Goodspeed
Original assignee: Ryan Directional Services Inc
Current assignee: Ryan Directional Services Inc
Priority date: 2013-07-15
Filing date: 2014-07-08
Publication date: 2015-01-15
Also published as: CA2913616A1; WO2015009573A1

Abstract

A pre-defined custom profile that specifies a potential condition, such as of a drilling rig site, is generated. One or more operational parameters at the drilling rig site are monitored to determine an actual condition of the drilling rig site. A dynamic response is made when it is detected that the actual condition of the drilling rig site matches the potential condition of the drilling rig site, as specified by the pre-defined custom profile. According to one aspect, one or more operations at the drilling rig site are automatically controlled based on the actual condition of the drilling rig site. According to another aspect, a report is automatically generated, the report including data corresponding to the actual condition at the drilling rig site.

Description

PRIORITY DATA

This application claims priority to Provisional Patent Application No. 61/846,218, filed Jul. 15, 2013, and entitled “Dynamic Response Apparatus and Methods Triggered by Conditions,” the disclosure of which is hereby incorporated by reference in its entirety.

FIELD OF THE DISCLOSURE

The present disclosure relates to an apparatus and methods to provide a dynamic response triggered by one or more conditions, such as drilling rig site conditions.

BACKGROUND OF THE DISCLOSURE

At a drilling rig site, field personnel sometimes generate reports associated with the drilling rig site and in accordance with a client's instructions. These reports may then be analyzed by the field personnel and/or the client to determine if any action needs to be taken at the drilling rig site. In some cases, however, the reports are unnecessary, and/or the reports do not include important or otherwise relevant data. Moreover, although some reports may include relevant data, such data may not be timely reported and, as a result, any necessary response action at the drilling rig site may not be timely. Therefore, what is needed is an apparatus or method that addresses the foregoing issues, among others.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is best understood from the following detailed description when read with the accompanying figures. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.

FIG. 1 is a schematic view of an apparatus according to one or more aspects of the present disclosure, the apparatus including a rig monitoring system for a drilling rig site.

FIG. 2 is a flow-chart diagram of at least a portion of a method according to one or more aspects of the present disclosure, the method including a step of generating a pre-defined custom profile associated with a potential condition of the drilling rig site of FIG. 1.

FIG. 3 is a schematic view of the pre-defined custom profile of the method of FIG. 2 according to one or more aspects of the present disclosure.

FIG. 4 is a schematic view of an apparatus according to one or more aspects of the present disclosure.

FIG. 5 is a schematic view of a node for implementing one or more aspects of the present disclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Moreover, the formation of a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.
Referring to FIG. 1, illustrated is a schematic view of an apparatus 10, which is within the scope of the present disclosure and includes a monitoring system 11, which will be referred to herein in the context of a drilling rig, for monitoring a drilling rig site 12. The rig monitoring system 11 includes a computer system, which includes a computer processor 14. A computer readable medium 16 is operably coupled to, and in communication with, the computer processor 14. Instructions accessible to, and executable by, the computer processor 14 are stored on the computer readable medium 16. In several exemplary embodiments, the computer readable medium 16 includes one or more databases. In several exemplary embodiments, the computer processor 14 is part of a server, a programmable logic controller (PLC), or one or more other computing devices.
In several exemplary embodiments, the drilling rig site 12 includes one or more drilling rigs employed in oil and/or gas exploration and production operations; these one or more drilling rigs may be land-based drilling rigs, jack-up rigs, semisubmersibles, drill ships, coil tubing rigs, and casing drilling rigs, among others. In several exemplary embodiments, in addition to one or more drilling rigs, the drilling rig site 12 may include one or more other types of wellsite equipment such as, for example, one or more downhole tools, the wellbore, the wellhead, etc.
In an exemplary embodiment, the rig monitoring system 11 is located, in whole or in part, at or near the drilling rig site 12. In several exemplary embodiments, the rig monitoring system 11 may be considered to be part of the drilling rig site 12. In several exemplary embodiments, the rig monitoring system 11 is located, in whole or in part, at a location remote from the drilling rig site 12.
In operation, in an exemplary embodiment with continuing reference to FIG. 1, the rig monitoring system 11 continuously monitors parameters/inputs associated with the drilling rig site 12. The monitored parameters/inputs include one or more wellsite information transfer specification (WITS) parameters 18, one or more downhole tool parameters 20, other parameters 22, other inputs 24, or any combination thereof. In an exemplary embodiment, the WITS parameters 18 may be omitted. In an exemplary embodiment, the downhole tool parameters 20 may be omitted. In response to this monitoring, the rig monitoring system 11 automatically generates one or more actions, outputs, or both. The automatically generated actions/outputs include an automatic action 26 (such as operational control of one or more components or systems of the drilling rig site 12), an automatic output 28 (such as a report), other automatic actions 30, and other automatic outputs 32. In several exemplary embodiments, the rig monitoring system 11 continuously monitors a wide variety of parameters/inputs and acts upon such parameters/inputs in respective pre-determined manners to perform automatic actions which would otherwise be carried out by human interaction.
Referring to FIG. 2, illustrated is a flow-chart diagram of at least a portion of a method 34. In several exemplary embodiments, the method 34 is implemented in whole or in part using the apparatus 10 in whole or in part. In several exemplary embodiments, the method 34 is a method of operating the apparatus 10. The method 34 includes at step 36 generating a pre-defined custom profile 37 (shown in FIG. 3) that specifies a potential condition of the drilling rig site 12. Before, during, or after the step 36, at step 38 the actual condition of the drilling rig site 12 is determined by monitoring one or more operational parameters. The monitored operational parameters may include the WITS parameters 18, the downhole tool parameters 20, the other parameters 22, and the other inputs 24. During or after the step 38, at step 40 it is detected that the actual condition of the drilling rig site 12 determined at the step 38 matches the potential condition of the drilling rig site 12, as specified by the pre-defined custom profile generated at the step 36. This detection at the step 40 triggers a dynamic response at step 42. In an exemplary embodiment, the step 42 includes at step 44 automatically controlling one or more operations at the drilling rig site 12 based on the actual condition thereof determined at the step 40. In an exemplary embodiment, the step 42 includes at step 46 automatically generating a report that includes data corresponding to the actual condition of the drilling rig site 12. In an exemplary embodiment, the step 42 includes at step 48 automatically transmitting the report generated at the step 46 to one or more pre-determined locations.
In an exemplary embodiment, the step 42 includes the steps 44, 46 and 48. In an exemplary embodiment, the step 42 does not include the step 44. In an exemplary embodiment, the step 42 does not include the steps 46 and 48. In an exemplary embodiment, the step 42 does not include the step 48. In an exemplary embodiment, the step 42 does not include either the step 44 or the step 48.
Referring to FIG. 3, illustrated is a schematic view of the pre-defined custom profile 37, which is generated at the step 36 of the method 34. In an exemplary embodiment, the pre-defined custom profile 37 specifies one or more WITS parameters 50 at the drilling rig site 12, one or more downhole tool parameters 52 at the drilling rig site 12, a drilling depth interval parameter 54 at the drilling rig site 12, a time interval parameter 56 at the drilling rig site 12, a drilling depth target parameter 58 at the drilling rig site 12, a tripping condition parameter 60 at the drilling rig site 12, and an end-of-day summary parameter 62 at the drilling rig site 12. In an exemplary embodiment, the pre-defined custom profile 37 may not specify any of the WITS parameters 50. In an exemplary embodiment, the pre-defined custom profile 37 may not specify any of the downhole tool parameters 52. It should be understood that appropriate parameters, conditions, etc. may be selected depending on the function being monitored, such as in loading a complex weapon, raising/lowering a drawbridge, controlling a traffic network or water/sewage pipelines, or the like, and that references herein to drilling rigs and wellsites and WITS are exemplary only. In an exemplary embodiment, the pre-defined custom profile 37 specifies that one or more of the WITS parameters 50 must be met under at least one pre-defined derivative constraint (e.g., first derivative constraint, first and second derivative constraints, etc.). In an exemplary embodiment, the pre-defined custom profile 37 specifies that one or more of the downhole tool parameters 52 must be met under at least one pre-defined derivative constraint (e.g., first derivative constraint, first and second derivative constraints, etc.).
In an exemplary embodiment, at the step 38, as noted above, the rig monitoring system 38 determines an actual condition of the drilling rig site 12 and compares the actual condition (or the parameters corresponding thereto) with the potential condition (or the parameters corresponding thereto) specified by the pre-defined custom profile 37. At the step 40, it is detected when the actual condition of the drilling rig site 12 matches the potential condition specified by the pre-defined custom profile 37, and a dynamic response is made at the step 42. In several exemplary embodiments, the foregoing conditions match if the operational parameters monitored at the step 38 are equivalent to, or are within a range of, the parameters specified by the pre-defined custom profile 37, i.e., one or more of the parameters 50, 52, 54, 56, 58, 60 and 62.
In an exemplary embodiment, a plurality of pre-defined custom profiles 37 are generated at the step 36, and the one or more operational parameters monitored at the step 38 are associated with different modes of operation of the drilling rig site 12, with each pre-defined custom profile 37 corresponding to a different operational mode; the potential conditions for which a match is detected at the step 40 is specified by one or more of the pre-defined custom profiles 37 in the plurality of pre-defined custom profiles 37.
In an exemplary embodiment, at the step 42, the dynamic response of the rig monitoring system 11 is triggered by the actual environment or condition(s) of the drilling rig site 12, as detected by the rig monitoring system 11 at the step 40. In other words, the detection of the actual environment or condition(s) at the drilling rig site 12 at the step 38 triggers the dynamic response at the step 42.
In an exemplary embodiment, the dynamic response at the step 42 is carried out at least at the step 44, which includes automatically controlling one or more operations at the drilling rig site 12. In several exemplary embodiments, at the step 42 one or more of the following operations are automatically controlled by the rig monitoring system 11: measurement-while-drilling (MWD) operations; logging-while-drilling (LWD) operations; geosteering operations; tubular handling operations; drilling operations; tubular make-up operations; and tubular break-out operations.
In an exemplary embodiment, the dynamic response at the step 42 is carried out at least at the step 46, which includes automatically generating a report that includes data corresponding to the actual condition of the drilling rig site 12. In an exemplary embodiment, the data corresponding to the actual condition of the drilling rig site 12 includes MWD data and/or LWD data.
In an exemplary embodiment, at the step 48, the report automatically generated at the step 46 is transmitted to one or more pre-determined locations. In an exemplary embodiment, at the step 48, the report is automatically e-mailed to different e-mail addresses on a pre-defined recipient list, which different e-mail addresses are the respective pre-determined locations at the step 48. In an exemplary embodiment, the pre-defined custom profile 37 specifies at least one of the one or more pre-determined locations at the step 48. In several exemplary embodiments, at least one of the one or more predetermined locations at the step 48 is at the drilling rig site 12, or is remote from the drilling rig site 12. In an exemplary embodiment, at the step 48, the report automatically generated at the step 46 is transmitted via text message to different telephone numbers, which different telephone numbers are the respective pre-determined locations at the step 48. In an exemplary embodiment, at the step 48, the report automatically generated at the step 46 is transmitted via an automated telephone call to different telephone numbers, which different telephone numbers are the respective pre-determined locations at the step 48. In an exemplary embodiment, at the step 48, the report automatically generated at the step 46 is transmitted via instant messaging.
In an exemplary embodiment, in the method 34, the pre-defined custom profile 37 generated at the step 36 specifies that the one or more WITS parameters 50 and/or the one or more downhole tool parameters 52 must be met under definable first and second derivative constraints. The one or more operational parameters monitored at the step 38 are associated with an MWD operation. The MWD operation is automatically controlled at the step 44, and/or the report automatically generated at the step 46 includes data associated with the MWD operation.
In an exemplary embodiment, in the method 34, the pre-defined custom profile 37 generated at the step 36 specifies the depth-drilled interval parameter 54 and the time-drilled interval parameter 56 so that the report is automatically generated at the step 44 when a wellbore at the drilling rig site 12 has been drilled by a certain depth amount, or the wellbore has been drilled for a certain amount of time.
The operation of the apparatus 10, and/or the execution of the method 34, provides the ability to generate custom-defined reports, as well as the ability to define that the custom-defined reports are to be generated when specific environmental conditions occur, such as when a certain WITS and/or downhole tool data profile is met under definable first and second derivative constraints).
In several exemplary embodiments, the operation of the apparatus 10, and/or the execution of the method 34, provides complete customization of report timing. The operation of the apparatus 10, and/or the execution of the method 34, provides the ability to define a large amount of rig-site situations at which reports are to be automatically generated. As a result, the operator at the drilling rig site 12, and/or office personnel at one or more locations remote from the drilling rig site 12, have the opportunity to respond to potentially critical rig-site situations in the most efficient manner possible. The operator, and/or office personnel at one or more locations remote from the drilling rig site 12, are informed of the rig-site situation, but are also provided with the data most relevant to making the correct decision in response to the rig-site situation, thereby dramatically improving drilling efficiency. Moreover, in addition to the operator at the drilling rig site 12 and/or office personnel at one or more locations remote from the drilling rig site 12, the operation of the apparatus 10, and/or the execution of the method 34, provides efficient communication of well-site data to all key decision-makers and stakeholders, enabling faster and more reliable responses to critical rig-site situations. In an exemplary embodiment, only the key decision-makers and stakeholders responsible for a particular critical alert or decision are alerted, which minimizes unnecessary interruption of those responsible for other alerts and decisions. Thus, the apparatus and methods can minimize or eliminate “alert fatigue” caused by information overload when every issue is sent to everyone every time.
In several exemplary embodiments, the operation of the apparatus 10, and/or the execution of the method 34, provides the potential for faster, more efficient, and on-target well-bore placement due to more informed and relevant decision making on the part of the operator at the drilling rig site 12, and/or office personnel at one or more locations remote from the drilling rig site 12.
In several exemplary embodiments, the operation of the apparatus 10, and/or the execution of the method 34, reduces the amount of repetitive tasks conducted by field staff (e.g., manual well-site report generation), allowing the field staff to concentrate on job-specific functions such as, for example, data analysis and interpretation. Moreover, the amount of personnel at the drilling rig site 12 may be reduced, thereby increasing margins through reduced per-job costs, and improving rig-site safety.
In several exemplary embodiments, the operation of the apparatus 10, and/or the execution of the method 34, provides for thorough auditing of data and consistent data reporting and formatting throughout the life of a job at the drilling rig site 12. As a result, the risk of incorrect or improper data presentation is reduced.
In several exemplary embodiments, the operation of the apparatus 10, and/or the execution of the method 34, offers the potential to predict potential well-site disasters well before any occurrences thereof by providing constant monitoring of well-site variable trends, both downhole and at the surface of the drilling rig site 12.
Referring to FIG. 4, illustrated is a schematic view of apparatus 100. The apparatus 100 demonstrates an exemplary environment in which an apparatus within the scope of the present disclosure may be implemented. In several exemplary embodiments, the apparatus 100 is positioned at, and forms part of, the drilling rig site 12.
As shown in FIG. 4, the apparatus 100 is or includes a land-based drilling rig for drilling a wellbore within a subterranean formation. However, one or more aspects of the present disclosure are applicable or readily adaptable to any type of wellsite equipment, such as a drilling rig. The drilling rig may include without limitation one or more jack-up rigs, semisubmersibles, drill ships, coil tubing rigs, and casing drilling rigs, among others. Apparatus 100 includes a mast 105 supporting lifting gear above a rig floor 110. The lifting gear includes a crown block 115 and a traveling block 120. The crown block 115 is coupled at or near the top of the mast 105, and the traveling block 120 hangs from the crown block 115 by a drilling line 125. The drilling line 125 extends from the lifting gear to draw-works 130, which is configured to reel the drilling line 125 out and in to cause the traveling block 120 to be lowered and raised relative to the rig floor 110. A hook 135 may be attached to the bottom of the traveling block 120. A top drive 140 may be suspended from the hook 135. A quill 145 extending from the top drive 140 may be attached to a saver sub 150, which may be attached to a tubular lifting device 152. The tubular lifting device 152 can be engaged with a drill string 155 suspended within and/or above a wellbore 160. The drill string 155 may include one or more interconnected sections of drill pipe 165, among other components. It should be understood that the use of the term “pipe” herein is merely an exemplary type of tubular and that various other types of tubulars (e.g., casing) can often be substituted depending on the desired operation. One or more pumps 180 may deliver drilling fluid to the drill string 155 through a hose or other conduit 185, which may be connected to the top drive 140 and also through other components for managed pressure drilling operations. The drilling fluid may pass through a central passage of the tubular lifting device 152. In an alternative embodiment, the top drive 140, quill 145 and sub 150 may not be utilized between the hook 125 and the tubular lifting device 152, such as where the tubular lifting device 152 is coupled directly to the hook 125, or where the tubular lifting device 152 is coupled to the hook 125 via other components.
In several exemplary embodiments, one or more of the operational parameters of the apparatus 100 may be monitored at the step 38, and one or more of the foregoing operations of the apparatus 100 may be automatically controlled at the step 44 of the method 34. In several exemplary embodiments, the report automatically generated at the step 46, as well as automatically transmitted at the step 48, may include data corresponding to actual conditions of the apparatus 100 and its various operational states, or at least a portion of the apparatus 100 and its operational state.
Referring to FIG. 5, an exemplary node 200 for implementing one or more embodiments of one or more of the above-described apparatus, elements, methods and/or steps, and/or any combination thereof, is depicted. The node 200 includes a microprocessor 200 a, an input device 200 b, a storage device 200 c, a video controller 200 d, a system memory 200 e, a display 200 f, and a communication device 200 g, all of which are interconnected by one or more buses 200 h. In several exemplary embodiments, the storage device 200 c may include a floppy drive, hard drive, CD-ROM, optical drive, any other form of storage device and/or any combination thereof. In several exemplary embodiments, the storage device 200 c may include, and/or be capable of receiving, a floppy disk, CD-ROM, DVD-ROM, or any other form of computer-readable medium that may contain executable instructions. In several exemplary embodiments, the communication device 200 g may include a modem, network card, or any other device to enable the node to communicate with other nodes. In several exemplary embodiments, any node represents a plurality of interconnected (whether by intranet or Internet) computer systems, including without limitation, personal computers, mainframes, PDAs, smartphones and cell phones.
In several exemplary embodiments, one or more of the components of the apparatus 10, the rig monitoring system 11, the drilling rig site 12, the apparatus 100, or any combination thereof, include at least the node 200 and/or components thereof, and/or one or more nodes that are substantially similar to the node 200 and/or components thereof. In several exemplary embodiments, one or more of the above-described components of the node 200 and/or the apparatus 10, the rig monitoring system 11, the drilling rig site 12, or the apparatus 100 include respective pluralities of same components.
In several exemplary embodiments, a computer system typically includes at least hardware capable of executing machine readable instructions, as well as the software for executing acts (typically machine-readable instructions) that produce a desired result. In several exemplary embodiments, a computer system may include hybrids of hardware and software, as well as computer sub-systems.
In several exemplary embodiments, hardware generally includes at least processor-capable platforms, such as client-machines (also known as personal computers or servers), and hand-held processing devices (such as smart phones, tablet computers, personal digital assistants (PDAs), or personal computing devices (PCDs), for example). In several exemplary embodiments, hardware may include any physical device that is capable of storing machine-readable instructions, such as memory or other data storage devices. In several exemplary embodiments, other forms of hardware include hardware sub-systems, including transfer devices such as modems, modem cards, ports, and port cards, for example.
In several exemplary embodiments, software includes any machine code stored in any memory medium, such as RAM or ROM, and machine code stored on other devices (such as floppy disks, flash memory, or a CD ROM, for example). In several exemplary embodiments, software may include source or object code. In several exemplary embodiments, software encompasses any set of instructions capable of being executed on a node such as, for example, on a client machine or server.
In several exemplary embodiments, combinations of software and hardware could also be used for providing enhanced functionality and performance for certain embodiments of the present disclosure. In an exemplary embodiment, software functions may be directly manufactured into a silicon chip. Accordingly, it should be understood that combinations of hardware and software are also included within the definition of a computer system and are thus envisioned by the present disclosure as possible equivalent structures and equivalent methods.
In several exemplary embodiments, computer readable mediums include, for example, passive data storage, such as a random access memory (RAM) as well as semi-permanent data storage such as a compact disk read only memory (CD-ROM). One or more exemplary embodiments of the present disclosure may be embodied in the RAM of a computer to transform a standard computer into a new specific computing machine. In several exemplary embodiments, data structures are defined organizations of data that may enable an embodiment of the present disclosure. In an exemplary embodiment, a data structure may provide an organization of data, or an organization of executable code.
In several exemplary embodiments, any networks and/or one or more portions thereof may be designed to work on any specific architecture. In an exemplary embodiment, one or more portions of any networks may be executed on a single computer, local area networks, client-server networks, wide area networks, internets, hand-held and other portable and wireless devices and networks.
In several exemplary embodiments, a database may be any standard or proprietary database software, such as Oracle, Microsoft Access, SyBase, or DBase II, for example. In several exemplary embodiments, the database may have fields, records, data, and other database elements that may be associated through database specific software. In several exemplary embodiments, data may be mapped. In several exemplary embodiments, mapping is the process of associating one data entry with another data entry. In an exemplary embodiment, the data contained in the location of a character file can be mapped to a field in a second table. In several exemplary embodiments, the physical location of the database is not limiting, and the database may be distributed. In an exemplary embodiment, the database may exist remotely from the server, and run on a separate platform. In an exemplary embodiment, the database may be accessible across the Internet. In several exemplary embodiments, more than one database may be implemented.
In several exemplary embodiments, a plurality of instructions stored on a computer readable medium may be executed by one or more processors to cause the one or more processors to carry out or implement in whole or in part the above-described operation of each of the above-described exemplary embodiments of the apparatus 10, the rig monitoring system 11, the drilling rig site 12, the apparatus 100, the method 34, and/or any combination thereof. In several exemplary embodiments, such a processor may include one or more of the microprocessor 200 a, the computer processor 14, any processor(s) that are part of the components of the apparatus 10 or 100, and/or any combination thereof, and such a computer readable medium may be distributed among one or more components of the apparatus 10, the rig monitoring system 11, the drilling rig site 12, the apparatus 100, and/or any combination thereof. In several exemplary embodiments, such a processor may execute the plurality of instructions in connection with a virtual computer system. In several exemplary embodiments, such a plurality of instructions may communicate directly with the one or more processors, and/or may interact with one or more operating systems, middleware, firmware, other applications, and/or any combination thereof, to cause the one or more processors to execute the instructions.
In view of all of the above and the figures, one of ordinary skill in the art will readily recognize that the present disclosure introduces a method that includes generating, using a computer system, a pre-defined custom profile that specifies a potential condition of a drilling rig site; monitoring, using the computer system, one or more operational parameters at the drilling rig site to determine an actual condition of the drilling rig site; detecting, using the computer system, that the actual condition of the drilling rig site matches the potential condition of the drilling rig site specified by the pre-defined custom profile; and dynamically responding to the detection of the matching conditions, wherein the dynamic response includes one or more of the following: automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site; and automatically generating, using the computer system, a report that includes data corresponding to the actual condition at the drilling rig site. According to one aspect, the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters. According to another aspect, the pre-defined custom profile specifies that the one or more downhole tool parameters must be met under at least one pre-defined derivative constraint. According to yet another aspect, the pre-defined custom profile specifies that the one or more WITS parameters must be met under at least one pre-defined derivative constraint. According to still yet another aspect, the dynamic response includes the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, wherein the dynamic response further includes automatically transmitting, using the computer system, the report to one or more pre-determined locations. According to still yet another aspect, the pre-defined custom profile specifies at least one of the one or more pre-determined locations. According to still yet another aspect, the dynamic response includes the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the data corresponding to the actual condition at the drilling rig site include at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data. According to still yet another aspect, the dynamic response includes the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the pre-defined custom profile specifies at least a depth-drilled interval parameter and a time-drilled interval parameter so that the report is automatically generated when a wellbore at the drilling rig site has been drilled by a depth amount, or has been drilled for an amount of time, or both. According to still yet another aspect, the pre-defined custom profile specifies at least one of the following: a depth target parameter; a tripping condition parameter; and an end-of-day summary parameter. According to still yet another aspect, the dynamic response includes the step of automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site, and wherein the one or more operations controlled at the drilling rig site include one or more of the following: MWD operations; LWD operations; geosteering operations; tubular handling operations; drilling operations; tubular make-up operations; and tubular break-out operations.
The present disclosure also introduces an apparatus that includes a non-transitory computer readable medium; and a plurality of instructions stored on the computer readable medium and executable by one or more processors, the plurality of instructions including instructions that cause the one or more processors to generate a pre-defined custom profile that specifies a potential condition of a drilling rig site; instructions that cause the one or more processors to monitor one or more operational parameters at the drilling rig site to determine an actual condition of the drilling rig site; instructions that cause the one or more processors to detect that the actual condition of the drilling rig site matches the potential condition of the drilling rig site specified by the pre-defined custom profile; and instructions that cause the one or more processors to dynamically respond to the detection of the matching conditions, wherein the dynamic response instructions include one or more of the following: instructions that cause the one or more processors to automatically control one or more operations at the drilling rig site based on the actual condition of the drilling rig site; and instructions that cause the one or more processors to automatically generate a report that includes data corresponding to the actual condition at the drilling rig site. According to one aspect, the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters. According to another aspect, the pre-defined custom profile specifies that the one or more downhole tool parameters must be met under at least one pre-defined derivative constraint. According to yet another aspect, the pre-defined custom profile specifies that the one or more WITS parameters must be met under at least one pre-defined derivative constraint. According to still yet another aspect, the dynamic response instructions include the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the dynamic response instructions further include instructions that cause the one or more processors to automatically transmit the report to one or more pre-determined locations. According to still yet another aspect, the pre-defined custom profile specifies at least one of the one or more pre-determined locations. According to still yet another aspect, the dynamic response instructions include the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the data corresponding to the actual condition at the drilling rig site include at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data. According to still yet another aspect, wherein the dynamic response instructions include the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the pre-defined custom profile specifies at least a depth-drilled interval parameter and a time-drilled interval parameter so that the report is automatically generated when a wellbore at the drilling rig site has been drilled by a depth amount, or has been drilled for an amount of time, or both. According to still yet another aspect, the pre-defined custom profile specifies at least one of the following: a depth target parameter; a tripping condition parameter; and an end-of-day summary parameter. According to still yet another aspect, the dynamic response instructions include the instructions that cause the one or more processors to automatically control the one or more operations at the drilling rig site based on the actual condition of the drilling rig site, and wherein the one or more operations controlled at the drilling rig site include one or more of the following: MWD operations; LWD operations; geosteering operations; tubular handling operations; drilling operations; tubular make-up operations; and tubular break-out operations.
The present disclosure also introduces a method that includes generating, using a computer system, a pre-defined custom profile that specifies a potential condition of a drilling rig site, wherein the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters; monitoring, using the computer system, one or more operational parameters at the drilling rig site to determine an actual condition of the drilling rig site; detecting, using the computer system, that the actual condition of the drilling rig site matches the potential condition of the drilling rig site specified by the pre-defined custom profile; and dynamically responding to the detection of the matching conditions, wherein the dynamic response includes automatically generating, using the computer system, a report that includes data corresponding to the actual condition at the drilling rig site, wherein the data corresponding to the actual condition at the drilling rig site include at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data; and automatically transmitting, using the computer system, the report to one or more pre-determined locations. According to one aspect, the dynamic response further includes automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site, the one or more operations including at least one of MWD operations and LWD operations.
The present disclosure also introduces an apparatus according to one or more aspects of the present disclosure.
The present disclosure also introduces a method including at least one step according to one or more aspects of the present disclosure.
The present disclosure also introduces a system including at least one component having at least one character according to one or more aspects of the present disclosure.
The present disclosure also introduces a kit including at least one component having at least one character according to one or more aspects of the present disclosure.
In several exemplary embodiments, in addition to the oil and gas industry, the exemplary embodiments described above, and/or one or more aspects of the present disclosure, may be readily applied to any industry in which critical, important, or relevant data must be communicated to pertinent individuals who require such information to make informed decisions in the most efficient, timely manner possible; such industries include, for example, the medical industry in which health care professionals could be informed of drastic changes in a patient's health in real time or near real time, rather than risking delays by being informed through traditional communication channels.
The foregoing outlines features of several embodiments so that a person of ordinary skill in the art may better understand the aspects of the present disclosure. Such features may be replaced by any one of numerous equivalent alternatives, only some of which are disclosed herein. One of ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. One of ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.
The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. §1.72(b) to allow the reader to quickly ascertain the nature of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.
Moreover, it is the express intention of the applicant not to invoke 35 U.S.C. §112(f) for any limitations of any of the claims herein, except for those in which the claim expressly uses the word “means” together with an associated function.

Claims

What is claimed is:

1. A method, comprising:

generating, using a computer system, a pre-defined custom profile that specifies a potential condition of a drilling rig site;

monitoring, using the computer system, one or more operational parameters at the drilling rig site to determine an actual condition of the drilling rig site;

detecting, using the computer system, that the actual condition of the drilling rig site matches the potential condition of the drilling rig site specified by the pre-defined custom profile; and

dynamically responding to the detection of the matching conditions, wherein the dynamic response comprises one or more of the following:

automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site; and

automatically generating, using the computer system, a report that includes data corresponding to the actual condition at the drilling rig site.

2. The method of claim 1, wherein the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters.

3. The method of claim 2, wherein the pre-defined custom profile specifies that the one or more downhole tool parameters must be met under at least one pre-defined derivative constraint.

4. The method of claim 2, wherein the pre-defined custom profile specifies that the one or more WITS parameters must be met under at least one pre-defined derivative constraint.

5. The method of claim 1, wherein the dynamic response comprises the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the dynamic response further comprises automatically transmitting, using the computer system, the report to one or more pre-determined locations.

6. The method of claim 5, wherein the pre-defined custom profile specifies at least one of the one or more pre-determined locations.

7. The method of claim 1, wherein the dynamic response comprises the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the data corresponding to the actual condition at the drilling rig site comprise at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data.

8. The method of claim 1, wherein the dynamic response comprises the step of automatically generating, using the computer system, the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the pre-defined custom profile specifies at least a depth-drilled interval parameter and a time-drilled interval parameter so that the report is automatically generated when a wellbore at the drilling rig site has been drilled by a depth amount, or has been drilled for an amount of time, or both.

9. The method of claim 1, wherein the pre-defined custom profile specifies at least one of the following: a depth target parameter; a tripping condition parameter; and an end-of-day summary parameter.

10. The method of claim 1, wherein the dynamic response comprises the step of automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site, and wherein the one or more operations controlled at the drilling rig site comprise one or more of the following: MWD operations; LWD operations; geosteering operations; tubular handling operations; drilling operations; tubular make-up operations; and tubular break-out operations.

11. An apparatus, comprising:

a non-transitory computer readable medium; and

a plurality of instructions stored on the computer readable medium and executable by one or more processors, the plurality of instructions comprising:

instructions that cause the one or more processors to generate a pre-defined custom profile that specifies a potential condition of a drilling rig site;

instructions that cause the one or more processors to monitor one or more operational parameters at the drilling rig site to determine an actual condition of the drilling rig site;

instructions that cause the one or more processors to detect that the actual condition of the drilling rig site matches the potential condition of the drilling rig site specified by the pre-defined custom profile; and

instructions that cause the one or more processors to dynamically respond to the detection of the matching conditions, wherein the dynamic response instructions comprise one or more of the following:

instructions that cause the one or more processors to automatically control one or more operations at the drilling rig site based on the actual condition of the drilling rig site; and

instructions that cause the one or more processors to automatically generate a report that includes data corresponding to the actual condition at the drilling rig site.

12. The apparatus of claim 11, wherein the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters.

13. The apparatus of claim 12, wherein the pre-defined custom profile specifies that the one or more downhole tool parameters must be met under at least one pre-defined derivative constraint.

14. The apparatus of claim 12, wherein the pre-defined custom profile specifies that the one or more WITS parameters must be met under at least one pre-defined derivative constraint.

15. The apparatus of claim 11, wherein the dynamic response instructions comprise the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the dynamic response instructions further comprise instructions that cause the one or more processors to automatically transmit the report to one or more pre-determined locations.

16. The apparatus of claim 15, wherein the pre-defined custom profile specifies at least one of the one or more pre-determined locations.

17. The apparatus of claim 11, wherein the dynamic response instructions comprise the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the data corresponding to the actual condition at the drilling rig site comprise at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data.

18. The apparatus of claim 11, wherein the dynamic response instructions comprise the instructions that cause the one or more processors to automatically generate the report that includes the data corresponding to the actual condition at the drilling rig site, and wherein the pre-defined custom profile specifies at least a depth-drilled interval parameter and a time-drilled interval parameter so that the report is automatically generated when a wellbore at the drilling rig site has been drilled by a depth amount, or has been drilled for an amount of time, or both.

19. The apparatus of claim 11, wherein the pre-defined custom profile specifies at least one of the following: a depth target parameter; a tripping condition parameter; and an end-of-day summary parameter.

20. The apparatus of claim 11, wherein the dynamic response instructions comprise the instructions that cause the one or more processors to automatically control the one or more operations at the drilling rig site based on the actual condition of the drilling rig site, and wherein the one or more operations controlled at the drilling rig site comprise one or more of the following: MWD operations; LWD operations; geosteering operations; tubular handling operations; drilling operations; tubular make-up operations; and tubular break-out operations.

21. A method, comprising:

generating, using a computer system, a pre-defined custom profile that specifies a potential condition of a drilling rig site, wherein the pre-defined custom profile specifies at least one of the following: one or more downhole tool parameters; and one or more wellsite information transfer specification (WITS) parameters;

dynamically responding to the detection of the matching conditions, wherein the dynamic response comprises:

automatically generating, using the computer system, a report that includes data corresponding to the actual condition at the drilling rig site, wherein the data corresponding to the actual condition at the drilling rig site comprise at least one of measurement-while-drilling (MWD) data and logging-while-drilling (LWD) data; and

automatically transmitting, using the computer system, the report to one or more pre-determined locations.

22. The method of claim 21, wherein the dynamic response further comprises:

automatically controlling, using the computer system, one or more operations at the drilling rig site based on the actual condition of the drilling rig site, the one or more operations comprising at least one of MWD operations and LWD operations.