Systems and methods for drilling operations

Abstract

A computing device performing the following operations: accessing a well plan for a drilling operation; receiving a plurality of drilling parameters for the drilling operation; generating a video including: a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated and / or video illustration of the drilling operation within a past predetermined time period; a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future time period. Also, the device may include saving the video on a server. Further, the device may include providing the video to at least one user. Similar systems and methods may be used to automatically generate and distribute videos of completion and / or production activities and planned completion and / or production activities.

Description

SYSTEMS AND METHODS FOR DRILLING OPERATIONSREFERENCE TO RELATED APPLICATION

[0001] This application claims the benefit of priority of U.S. Patent Application No. 18 / 477,323, filed on September 28, 2023, and entitled SYSTEMS AND METHODS FOR OILFIELD DRILLING OPERATIONS, the content of which is hereby incorporated by reference in its entirety.FIELD OF THE INVENTION

[0002] The present disclosure relates generally to drilling of wells for oil and gas production and, more particularly, to systems and methods useful for monitoring and managing drilling operations for one or more wells during drilling.BACKGROUND

[0003] In the fast paced, complex, and ever-changing world of drilling, completions and production in the oil and gas industry, multiple teams (technicians, superintendents (field and actual), remote operating center (ROC) employees and managers, operators, engineers, managers, vice presidents, and executives, from multiple companies (e.g., one or more vendors, the owner / operator of the well, investors in the well, etc.) all need to get timely updates and reports in order to understand the current status of the drilling operations for a well. Often, the stakeholders in a given well are also stakeholders in other wells, and so each of the stakeholders often need to get timely information for a number of wells each day, and sometimes a number of updates each day.

[0004] A modern drilling ng includes a number of systems that work with one another and generate a great deal of information during drilling. As a non-limiting example, a typical drilling rig may generate gamma ray logs, resistivity logs, mud logs, and other logs during drilling operations, as well as measurement while drilling information. Such logs may be plotted in various ways, including against measured depth, true vertical depth, and other scales.

[0005] In many situations, a stakeholder interested in drilling operations will want to obtain updated information at the beginning of a workday. The update of interest often includesinformation from the previous night’s drilling operations. Currently, gathering this information requires obtaining reports from multiple sources, and talking to multiple individuals at various companies (e.g., multiple vendors) to get a full understanding of the current status of drilling operations and what happened during the previous evening (or other time period of interest). Typically, a stakeholder will receive morning reports from multiple vendors on the drilling operations that occurred during the previous night. The stakeholder often will need to make follow up calls or otherwise communicate with others to address any questions or obtain additional information about the drilling operations that are the subject of such reports.

[0006] In addition to an update on and an understanding of the night’s (or days, weeks, or other time period) immediately preceding drilling operations and the current status of drilling operations, a stakeholder will often also want to know about the planned drilling operations. A well plan for drilling the well should exist, but drilling often does not go according to plan. Hence, a stakeholder will want to know how the current status of the well and the drilling operations compare to the well plan, and when things are not according to plan, how and in what ways the upcoming drilling operations will return the well to plan and / or what changes to the well plan are anticipated and / or are to be made, as well as when and what drilling operations will be undertaken to accomplish the return to plan and / or drilling in accordance with an update to the well plan.

[0007] Trying to collect and distill the desired information and data from various sources, some of which may be in different formats, from different sources, and which may require additional communications, may take time and effort. This time and effort delays the stakeholders from obtaining a quick update on a well and further takes time away from the stakeholder’s other activities.BRIEF SUMMARY

[0008] Embodiments covered by this patent are defined by the claims below, not this summary. This summary is a high-level overview of various embodiments and introduces some of the concepts that are further described in the Detailed Description section below. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used in isolation to determine the scope of the claimed subject matter. Thesubject matter should be understood by reference to appropriate portions of the entire specification of this patent, any or all drawings, and each claim.

[0009] Described herein is are systems and methods that will take the various pieces of pertinent information of what has happened related to a drilling operation and create a video for an end user showing, with context, what has happened during a past, predefined time period (e.g., a “look back time period”), an analysis of the drilling operation, and / or what is predicted to happen during a future, predefined time period (e.g., a “look forward time period”).

[0010] In various embodiments, the information received and / or obtained by the system may include a well plan, sensor information, information from other systems, input from a user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the system may connect via APIs to other clients applications to gather the necessary data to create the video, like the EDR, geophysical software like Starsteer, ERP’s, OCR to text applications, etc. Additionally, or alternatively, the system may obtain information from various sensors at a drilling location, such as but not limited to downhole sensors, sensors on a rig, sensors at other locations, combinations thereof, and / or as otherwise desired. As yet another non-limiting example, the system may receive input from a user, such as but not limited to an annotation or indication from a drilling engineer via a human machine interface. Other combinations and / or sub-combinations of input information may be utilized as desired.

[0011] In some embodiments, the look back time period and / or the look forward time period may be customizable and / or controlled by the system as desired. As non-limiting examples, the system may be configured to generate a video on some last amount of hours, on some last amount of days, on some future amount of hours, on some future amount of days, for the entire well, on the completion of one or more drilling operations, on well production time, combinations thereof, and / or as otherwise desired. In certain embodiments, the look back time period and / or the look forward time period may be controlled by the system based on parameters such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the system may provide a field superintendent a video showinggranular drilling activities on an hourly basis but may provide a drilling manager a video with a daily (e.g., 24 hour) look back with a high level overview of a fleet of wells and / or completions and / or drilling operations. Additionally, or alternatively, the system may produce a video based on sensor data and / or other input into the system indicating a completion of a particular drilling operation, a potential safety and / or hazardous condition, a completion of the end of well, combinations thereof, and / or as otherwise desired. The videos may include information related to a single well and / or the entire pad (e.g., multiple wells and / or completions of wells) as desired. Other combinations or sub-combinations may be utilized as desired.

[0012] Optionally, in embodiments where the input information includes a plurality of wells and / or a plurality of pads, the systems and methods described herein may generate a video analyzing the two (or more) wells and / or pads, optionally explaining similarities and / or differences between the two (or more) wells and / or pads.

[0013] In various embodiments, the systems and methods described herein may be customizable and / or otherwise configured to provide the video to the end user at various reporting intervals, which may be regular or irregular, as desired. In some embodiments, the reporting interval optionally may be based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the systems and methods may be configured to provide a video to a drilling manager or a vice president at a daily interval, a video to a drilling engineer every 6 hours, and a video to a field superintendent every hour. Other combinations or sub-combinations may be utilized as desired.

[0014] Additionally, or alternatively, the system may control the amount of information and / or the type of information and / or a duration of the video based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As a non-limiting example, the system may provide a video to a field superintendent with more information about the granular drilling activities, while a drilling manager may be provided with a high level overview, optionally omitting granular drilling activity information. As another non-limiting example, the system may generate a video for an employee of the drilling operator with a certain amount and / or type of information and may generate another video for a contractor with a filtered amount and / or type of information (e.g., such as to optionally omit operator-sensitive information). As further non-limiting examples, a drilling engineer may be provided with a video of a shorter duration (e.g., less than 30 seconds) while a drilling manager may be provided with a video of a longer duration (e.g., less than 2-3 minutes). Other combinations or sub-combinations may be utilized as desired.

[0015] Optionally, the systems and methods described herein may generate the video with a prediction of a future drilling operation, parameter, and / or event. As non-limiting examples, based on the well plan and / or other input information, the system may generate a video of predicted drilling operations, parameters, and / or events in the look forward time period (e.g., a “forward plan”), such as a predicted geological condition, potential issues based on past drilling performance and / or geological conditions, a predicted slide, a predicted rotation, combinations thereof, and / or as otherwise desired. Optionally, the predicted future drilling operation may be the forward well plan and / or the plan ahead over a certain time period. Optionally, generating the video with the predicted future drilling operations, parameters, and / or events may include identifying how many times over some last amount of wells a forward plan has hit a desired target time, and the video with the forward plan may assign a probability that the forward plan will occur in the target time period.

[0016] Optionally, the systems and methods described herein may generate a video in 3D, optionally allowing manipulation by a user. Optionally, the video generated may allow manipulation up to 360 degrees (e.g., modifying such that the video is depicting the well looking at the well from below, from above, from behind, from in front, from either side, and from any other angle). As a non-limiting example, the system may generate a 3D video showing drilling progression in the look back time period or the look forward time period. In such embodiments, the 3D video may, for example, have a first type of view of the (e.g., a sideview) of the drilling progression of the well, and a user optionally may manipulate the view to another view (e.g., a top view, a zoomed in view, a perspective view, etc.), and the system may continue the video and / or rewind the video with the modified view. In various embodiments, pertinent information may be embedded in the video.

[0017] In some embodiments, the systems and methods described herein may generate the video in various file formats and / or may provide the video to one or more end users in various formats as desired. In some embodiments, the systems and methods described herein may generate the video in a particular file format and / or may provide the video to an end user using a particular format based on various input information, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the system may send the video via formats such as but not limited to email, text, WhatsApp (or equivalent), TikTok, Instagram, Facebook, Snapchat, on a mobile application notification system , combinations thereof, and / or as otherwise desired. As a non-limiting example, the system may send the video via a secured (e.g., encrypted or otherwise) email to an outside or 3rdparty vendor, a mobile application notification to a vice president, and a text or WhatsApp (or equivalent) to a field engineer. As further non-limiting examples, videos may be sent by the system using a link to an online video hosting service and / or the system may upload the video to a mobile application to watch in the system and / or the system may generate the video at a field site location on premises for the company man / dnller to watch. Optionally, the system may generate the video which would be able to play the short clip on the notification on the persons cell phone. Other combinations or sub-combinations may be utilized as desired.

[0018] Optionally, the videos generated by the system may be utilized to improve communication between various personnel, and the videos may be interactive and / or otherwise be modified based on supplemental user input. As a non-limiting example, the system may generate a video having a look back time period, and a field superintendent may add an annotation and / or otherwise provide input modifying the video (e.g., to further explain and / or provide context to information in the video, to highlight certain information in the video, etc ).In such embodiments, the system may provide the modified video to another end user (e g., a drilling manager, vice president, another field superintendent, etc.). As another non-limiting example, the system may generate a video having a look back time period, and responsive to a user question, output segments of the video and / or modify the video itself to answer the question. As a non-limiting example, a drilling engineer may ask “how does this current H2- MB14 well intermediate section and curve compare to the last three MB 14 wells we drilled,” and the system may take the input, output a correct language response, and trigger the video to show a 3D representation of the well to be consolidated into the three separate wells showing similarities and differences. Other user input and / or interaction with the video may be utilized as desired, and the system may provide various other modifications to the video and / or interaction with the user as desired.

[0019] Additionally, or alternatively, to providing videos to various end users and / or interacting with various end users, the systems and methods described herein may utilize the videos for various other control responses. As a non-limiting example, the systems and methods described herein may utilize the video and / or the information in the video to automatically update the well plan. As another non-limiting example, the systems and methods described herein may utilize the video and / or the information in the video to control one or more pieces of drilling equipment, drilling systems, and / or drilling operations.

[0020] Compared to traditional approaches, the systems and methods described herein may deliver pertinent information through one or more videos to appropriate internal and / or external personnel as desired. Such videos may facilitate handover activities between crews, improve review of what happened during a look back time period, improve planning operations for a look forward time period, improve interaction between various personnel, improve understanding of a current operation state, and improve understanding of the future state. Various other benefits and advantages may be realized with the systems and methods described herein, and the aforementioned benefits and advantages should not be considered limiting.

[0021] In certain embodiments, a system of one or more computers may be configured to perform particular operations or actions by virtue of having software, firmware, hardware, or a combination of them installed on the system that in operation causes or cause the system toperform the actions. One or more computer programs may be configured to perform particular operations or actions by virtue of including instructions that, when executed by data processing apparatus, cause the apparatus to perform the actions.

[0022] In some embodiments, a drilling system may include a computing device that includes one or more processors. The computing device may include a memory for storing instructions that when executed by the one or more processors perform various operations. Various combinations and sub-combinations of operations may be performed. As non-limiting examples, in some embodiments, the operations may include receiving and / or accessing a well plan for drilling a well. In some embodiments, receiving and / or accessing the well plan may include receiving and / or accessing drilling operations included in the well plan. Optionally, receiving and / or accessing the well plan may include receiving a plurality of drilling data and / or drilling parameters for the drilling operations. Additionally, or alternatively, operations may include receiving and / or accessing information from one or more sensors. Additionally, or alternatively, operations may include receiving and / or accessing information from one or more sources related to one or more drilling operations.

[0023] In certain embodiments, operations may include generating a video based on the information received and / or accessed.

[0024] Optionally, generating the video may include one or more of generating the video with a graphical depiction of the drilling operations based on the plurality of drilling parameters for the drilling operations and / or the information received from the drilling rig sensors, an animated and / or video illustration of the drilling operations within a predetermined time period, a plurality of metrics associated with the drilling operations as determined by the sensors and / or as provided by the drill plan, and / or a summary of a planned activity for a drilling operation for a future predetermined time period, combinations thereof, and / or as otherwise desired. Optionally, the graphic depiction may include one or more of an animated and / or video illustration including one or more drilling logs from the time period, a profile of the wellbore as drilled and / or as planned, a profile of the wellbore, one or more geological formations, a projected path of the wellbore to be drilled, a comparison of the projected pathwith the planned path according to the well plan, a comparison of the current and / or projected path to a path of another well, combinations thereof, and / or as otherwise desired.

[0025] Optionally, the generating the video may include generating the video with an audio component, such as but not limited to a narration that describes what is being graphically depicted in the video, provides additional information to the viewer, an analysis of information in the video, a response to a user watching the video, combinations thereof, and / or as otherwise desired. Optionally, a user of the system of the present disclosure may be able to select a voice from one of several options for the narrator’s voice, as well as able to select a particular language for the narration. Additionally, or alternatively, the system itself may automatically determine such aspects of the audio component. As a non-limiting example, the system may automatically generate a narrated response responsive to a question presented by a user and based on the system’s analysis of the information in the video.

[0026] Optionally, the operations may include saving the video in a database on a sever connected to a network. Additionally, or alternatively, corresponding computer systems, apparatus, and computer programs recorded on one or more computer storage devices, may be configured to perform the actions of the methods.

[0027] In some embodiments, the operations may include providing the video to at least one user. Additionally, or alternatively, the operations may include updating a well plan. Additionally, or alternatively, the operations may include controlling one or more pieces of drilling equipment, one or more drilling systems, and / or one or more drilling operations, combinations thereof, and / or other control responses as desired.

[0028] Implementations may include one or more of the features described below.

[0029] In various embodiments, the graphical depiction of the video optionally may include a three-dimensional (3D) rendering of the drilling operation.

[0030] In some embodiments, the video includes a prediction or forward plan for the well. In various embodiments, generating the prediction or forward plan optionally may be based on a plurality of metrics, such as but not limited to a number of times that a past forward plan achieved a desired target time over N number of previous drilling wells. In variousembodiments, the operations optionally may include assigning a probability that the forward plan will achieve the desired target time during a current drilling operation. In various embodiments, the video optionally may include projected challenges for a defined time period for the drilling operation based on the plurality of drilling parameters. Additionally, or alternatively, a planned activity further may include one or more of a summary of geological changes anticipated to occur for the future predetermined time period, an identification of anticipated drilling operations, an identification of anticipated drilling parameters, combinations thereof, and / or other predicted events, parameters, and / or operations as desired.

[0031] Optionally, the video may be generated via a plurality of application programming interfaces that connect a video generating engine to one or more drilling systems that perform the drilling operations. In such an arrangement, the drilling systems may provide the data to the video generating engine during drilling operations, and the video generating operation may then access the data when generating a video.

[0032] Optionally, the video may include custom narration.

[0033] In various embodiments, providing the video to at least one user may include one or more of: emailing or texting the video or a portion thereof to a user, generating a link to the video and transmitting the link to the video to the at least one user, or simply alerting the user via text, email, phone message or otherwise that a new video is available for the user, combinations thereof, and / or as otherwise desired.

[0034] In some embodiments, generating the video includes controlling at least one aspect or characteristic of the video based on an identified and / or desired end user. Controlling one aspect of the video may include controlling a type of information in the video, an amount of information in the video, a duration of the video, a reporting interval of the video, a type of video file, a type of video file transmission to the end user, combinations thereof, and / or as otherwise desired. Optionally, for a same predetermined time period (look back or look forward), the system may generate different videos for different end users, although they need not be different in other embodiments.

[0035] Optionally, the video generating engine may send the same video to multiple stakeholders, and the video may be sent in the same form or in a different form to such stakeholders. As a non-limiting example, one stakeholder may set (and / or the system may determine based on the type of stakeholder) a preference to receive videos that exclude certain types of information (e.g., mud logs or gamma logs), while another stakeholder may prefer to include all available information in the video received.

[0036] The systems of the present disclosure allow each user to set preferences for the video content and / or the systems may automatically identify the content of the videos to various end users. Additionally, or alternatively, the systems of the present disclosure allow a user to set preferences and / or the systems may automatically identify the timing and / or manner in which the user receives the video. As a non-limiting example, some users might prefer to receive the video on a cell phone via text message, and on a computer at the office (or at home) via an emailed link. Each user may thus select multiple delivery modes for a number of devices.

[0037] In various embodiments, the operations optionally may include transmitting a copy of the video and / or a hyperlink to the video to one or more stakeholders at one or more preset times, which may be set by the stakeholders and / or determined by the system. Optionally, the operations may include transmitting a link to the video within a preset time following certain drilling operations or milestones (e.g., kick off of the transition from vertical to horizontal, a return to a planned well path, upon reaching the target formation, a kick, a cave-in, completion of drilling, combinations thereof, etc.). In various embodiments, the video optionally may include links to drilling data. In various embodiments, the video or a link to the video may transmitted via at least one of an email message, a text message, and a chat message.

[0038] In various embodiments, the operations further may include storing a link to the video on a website for viewing after user login.

[0039] In various embodiments, the video is automatically generated.

[0040] In various embodiments, the video includes one or more tags identifying information in the video.

[0041] The systems descried herein may generate videos of any duration as desired, although in certain embodiments, the videos may be of a relative short duration for easy transmission of information to the end user. In some non-limiting examples, the length of the video is less than 30 seconds in duration. In some non-limiting examples, the length of the video is between 30 and 60 seconds in duration. Yet another non-limiting example, the length of the video is greater than 60 seconds in duration. Optionally, the video may be less than 2-3 minutes, although other durations may be utilized as desired. In some embodiments, the system may receive a desired maximum video length from at least one user, and the system may automatically generate the video having a duration less than or equal to the maximum video length. Additionally, or alternatively, the system may determine a maximum video length based on the type of at least one user (e.g., position within the company, role on the drilling ng, 3rdparty vendor, etc.), and the system may automatically generate the video having a duration less than or equal to the maximum video length. In some embodiments where the system receives and / or determines the maximum video length, the system may prioritize and / or rank various input information received and / or obtained, and the system may generate the video based on the prioritization and / or ranking of the input information such that the video is less than or equal to the maximum video length.

[0042] In certain embodiments, the video is stored in a searchable database of prior reports.

[0043] In various embodiments, the operations may include receiving artificial intelligence generated inputs based on user searches.

[0044] In some embodiments, the video generating engine generates multiple formats for the video, such as, but not limited to, mp4 files, mov files, quicktime files, avi files, and / or wmv files, and the like. Optionally, the system may determine and / or a user may specify one or more file formats for receipt by that user. As a non-limiting example, the user may have a video in one format sent to a cell phone or tablet and another copy of the video sent in a different format to a computer. Implementations of the described techniques may include hardware, a method or process, and / or a computer tangible medium.

[0045] In one general aspect, a method may include accessing a well plan for drilling a well and / or for portions of the well. The method may include receiving a plurality of drillingparameters for the drilling operations. The method may include generating a video including a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, which may include an animated and / or video illustration of the drilling operation within a predetermined time period. Additionally, or alternatively, the video may include one or more of a plurality of metrics associated with the drilling operation as provided by the drill plan, and / or a summary of a planned activity for a drilling operation for a future predetermined time period.

[0046] In various embodiments, the operations may include saving the video on a sever connected to a network.

[0047] In various embodiments, the operations may include providing the video to at least one user.

[0048] Other embodiments of this aspect include corresponding computer systems, apparatus, and computer programs recorded on one or more computer storage devices, each configured to perform the actions of the methods.

[0049] In one general aspect, a non-transitory, computer readable medium may store instructions that when execute by a processor may perform various operations. The operations may include accessing a well plan for a drilling operation. The operations may include receiving a plurality of drilling parameters for the drilling operation.

[0050] The operations may include generating a video. The video may include a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated and / or video illustration of the drilling operation within a predetermined time period. Additionally, or alternatively, the video may include one or more of a plurality of metrics associated with the drilling operation as provided by the drill plan, and / or a summary of a planned activity for a drilling operation for a future predetermined time period.

[0051] The operations may include saving the video on a sever connected to a network.

[0052] The operations may include providing the video to at least one user. Other embodiments of this aspect include corresponding computer systems, apparatus, and computerprograms recorded on one or more computer storage devices, each configured to perform the actions of the methods.

[0053] As explained below, the present disclosure focuses on the creation and distribution of videos for drilling operations, but the systems and methods explained and described herein may be used to generate and distribute similar reports for completion and / or production activities and operations.

[0054] With reference to the remaining portions of the specification, including the drawings and claims, the reader will realize other features and advantages of embodiments of the present disclosure. Further features and advantages, as well as the structure and operation of various embodiments of the present disclosure, are described in detail below with respect to the accompanying drawings. In the drawings, like reference numbers may indicate identical or functionally similar elements.

[0055] Various implementations described herein may include additional systems, methods, features, and advantages, which cannot necessarily be expressly disclosed herein but will be apparent to one of ordinary skill in the art upon examination of the following detailed description and accompanying drawings. It is intended that all such systems, methods, features, and advantages be included within the present disclosure and protected by the accompanying claims.BRIEF DESCRIPTION OF THE DRAWINGS

[0056] For a more complete understanding of the present invention and its features and advantages, reference is now made to the following description, taken in conjunction with the accompanying drawings, in which:

[0057] FIG. 1 is a depiction of a drilling system for drilling a borehole.

[0058] FIG. 2 is a depiction of a drilling environment including the drilling system for drilling a borehole.

[0059] FIG. 3 is a depiction of a borehole generated in the drilling environment.

[0060] FIG. 4 is a depiction of a drilling architecture including the drilling environment.

[0061] FIG. 5 is a first depiction of rig control systems included in the drilling system.

[0062] FIG. 6 is a depiction of algorithm modules used by the ng control systems.

[0063] FIG. 7 is a depiction of a steering control process used by the rig control systems.

[0064] FIG. 8 is a depiction of a graphical user interface provided by the rig control systems.

[0065] FIG. 9 is a depiction of a guidance control loop performed by the rig control systems.

[0066] FIG. 10 is a depiction of a controller usable by the rig control systems.

[0067] FIG. 11 illustrates an exemplary system for generating drilling video reports according to embodiments.

[0068] FIG. 12 illustrates a first exemplary illustration of a portion of a video from the system of FIG. 11 according to embodiments.

[0069] FIG. 13 illustrates a second exemplary illustration of a portion of a video from the system of FIG. 11 according to embodiments.

[0070] FIG. 14 illustrates a third exemplary illustration of a portion of a video from the system of FIG. 11 according to embodiments.

[0071] FIG. 15 illustrates a fourth exemplary illustration of a portion of a video from the system of FIG. 11 according to embodiments.

[0072] FIG. 16 illustrates a fifth exemplary illustration of a portion of a video from the system of FIG. 11 according to embodiments.

[0073] FIG. 17 illustrates an exemplary flowchart for a process for generating a video using the system of FIG. 11 according to embodiments.

[0074] FIG. 18 illustrates a second depiction of rig control systems included in the drilling system and including the system of FIG. 11 according to embodiments.DETAILED DESCRIPTION

[0075] In the following description, details are set forth by way of example to facilitate discussion of the disclosed subject matter. It should be apparent to a person of ordinary skill in the field, however, that the disclosed embodiments are exemplary and not exhaustive of all possible embodiments.

[0076] Throughout this disclosure, a hyphenated form of a reference numeral refers to a specific instance of an element and the un-hyphenated form of the reference numeral refers to the element generically or collectively. Thus, as an example (not shown in the drawings), device “12-1 ” refers to an instance of a device class, which may be referred to collectively as devices “12” and any one of which may be referred to generically as a device “12”. In the figures and the description, like numerals are intended to represent like elements.

[0077] Drilling a well typically involves a substantial amount of human decision-making during the drilling process. For example, geologists and drilling engineers use their knowledge, experience, and the available information to make decisions on how to plan the drilling operation, how to accomplish the drill plan, and how to handle issues that arise during drilling. However, even the best geologists and drilling engineers perform some guesswork due to the unique nature of each borehole. Furthermore, a directional human driller performing the drilling may have drilled other boreholes in the same region and so may have some similar experience. However, during drilling operations, a multitude of input information and other factors may affect a drilling decision being made by a human operator or specialist, such that the amount of information may overwhelm the cognitive ability of the human to properly consider and factor into the drilling decision. Furthermore, the quality or the error involved with the drilling decision may improve with larger amounts of input data being considered, for example, such as formation data from a large number of offset wells. For these reasons, human specialists may be unable to achieve optimal drilling decisions, particularly when such drilling decisions are made under time constraints, such as during drilling operations when continuation of drilling is dependent on the drilling decision and, thus, the entire drilling rig waits idly for the next drilling decision. Furthermore, human decision-making for drilling decisions may result in expensive mistakes because drilling errors may add significant cost todrilling operations. In some cases, drilling errors may permanently lower the output of a well, resulting in substantial long term economic losses due to the lost output of the well.

[0078] The systems and methods used to drill oil and gas wells are complex and sophisticated. Methods and systems developed for oil and gas wells may be adapted for use in planning, drilling, and creating wells for geothermal energy. The following discussion provides a description of systems and techniques for drilling wells that may be useful for drilling geothermal wells, as well as generating electricity therefrom.Drilling Systems

[0079] FIGS. 1-10 illustrate various aspects, features, and components of a drilling system according to various embodiments. The features illustrated and described with respect to FIGS. 1-10 may be used in various combinations or sub-combinations as desired, and in other embodiments, additional and / or alternative aspects, features, and / or components may be utilized as desired.

[0080] FIG. 1 illustrates a drilling system 100 according to various embodiments. The drilling system 100 is provided for illustrative purposes, and in other embodiments, drilling systems may include fewer and / or additional components as desired.

[0081] In FIG. 1, the drilling system 100 is illustrated as a top drive system and includes a derrick 132 on a surface 104 of the earth and is used to drill a borehole 106 into the earth. Typically, drilling system 100 is used at a location corresponding to a geographic formation 102 in the earth that is known.

[0082] In FIG. 1, derrick 132 includes a crown block 134 to which a traveling block 136 is coupled via a drilling line 138. In drilling system 100, a top drive 140 is coupled to traveling block 136 and may provide rotational force for drilling. A saver sub 142 may sit between the top drive 140 and a drill pipe 144 that is part of a drill string 146. Top drive 140 may rotate drill string 146 via the saver sub 142, which in turn may rotate a drill bit 148 of a bottom hole assembly (BHA) 149 in borehole 106 passing through formation 102. Also visible in drillingsystem 100 is a rotary table 162 that may be fitted with a master bushing 164 to hold drill string 146 when not rotating.

[0083] A mud pump 152 may direct a fluid mixture (e.g. , drilling mud 153) from a mud pit 154 into drill string 146. Mud pit 154 is shown schematically as a container, but it is noted that various receptacles, tanks, pits, or other containers may be used. Drilling mud 153 may flow from mud pump 152 into a discharge line 156 that is coupled to a rotary hose 158 by a standpipe 160. Rotary hose 158 may then be coupled to top drive 140, which includes a passage for drilling mud 153 to flow into borehole 106 via drill string 146 from where drilling mud 153 may emerge at drill bit 148. Drilling mud 153 may lubricate drill bit 148 during drilling and, due to the pressure supplied by mud pump 152, drilling mud 153 may return via borehole 106 to surface 104.

[0084] In drilling system 100, drilling equipment (see also FIG. 5) may be used to perform the drilling of borehole 106, such as top drive 140 (or rotary drive equipment) that couples to drill string 146 and BHA 149 and is configured to rotate drill string 146 and apply pressure to drill bit 148. Drilling system 100 may include one or more control systems such as but not limited to a WOB / differential pressure control system 522, a positional / rotary control system 524, a fluid circulation control system 526, and / or a sensor system 528, combinations thereof, and / or as otherwise desired and as further described below with respect to FIG. 5. The control systems may be used to monitor and / or change drilling rig settings, such as the WOB or differential pressure to alter the ROP or the radial orientation of the toolface, change the flow rate of drilling mud, and perform other operations.

[0085] In certain embodiments, the sensor system 528 may be configured to obtain sensor data about the drilling operation and drilling system 100, including, but not limited to, the downhole equipment. As non-limiting examples, sensor system 528 may include MWD and / or logging while drilling (LWD) tools for acquiring information, such as but not limited to toolface and formation logging information, which may be saved for later retrieval, transmitted with or without a delay using any of various communication means (e.g., wireless, wireline, or mud pulse telemetry), and / or otherwise transferred to steering control system 168. As used herein, an MWD tool is enabled to communicate downhole measurements without substantialdelay to the surface 104, such as using mud pulse telemetry, while a LWD tool is equipped with an internal memory that stores measurements when downhole and may be used to download a stored log of measurements when the LWD tool is at the surface 104. The internal memory in the LWD tool may be a removable memory, such as a universal serial bus (USB) memory device or another removable memory device. It is noted that certain downhole tools may have both MWD and LWD capabilities. Such information acquired by sensor system 528 may include information related to hole depth, bit depth, inclination angle, azimuth angle, true vertical depth, gamma count, standpipe pressure, mud flow rate, rotary rotations per minute (RPM), bit speed, ROP, WOB, among other information. It is noted that all or part of sensor system 528 may be incorporated into a control system, or in another component of the drilling equipment. As drilling system 100 may be configured in many different implementations, it is noted that different control systems and subsystems may be used.

[0086] Sensing, detection, measurement, evaluation, storage, alarm, and other functionality may be incorporated into a downhole tool 166, BHA 149, and / or elsewhere along drill string 146 to provide downhole surveys of borehole 106. Accordingly, downhole tool 166 may be an MWD tool, an LWD tool, or both, and may accordingly utilize connectivity to the surface 104, local storage, or both. In various embodiments, various types of sensors may be utilized as desired, such as but not limited to gamma radiation sensors, magnetometers, accelerometers, and / or other types of sensors suitable for the downhole surveys. Although downhole tool 166 is shown in singular in drilling system 100, it is noted that multiple instances (not shown) of downhole tool 166 may be located at one or more locations along drill string 146.

[0087] In some embodiments, formation detection and evaluation functionality may be provided via a steering control system 168 on the surface 104. Steering control system 168 may be located in proximity to derrick 132 or may be included with drilling system 100. In other embodiments, steering control system 168 may be remote from the actual location of borehole 106 (see also FIG. 4). As a non-limiting example, steering control system 168 may be a stand-alone system or may be incorporated into other systems included with drilling system 100.

[0088] In operation, steering control system 168 may be accessible via a communication network (see also FIG. 10) and may accordingly receive formation information via the communication network. In some embodiments, steering control system 168 may use the evaluation functionality to provide corrective measures, such as a convergence plan to overcome an error in the well trajectory of borehole 106 with respect to a reference, or a planned well trajectory. The convergence plans or other corrective measures may depend on a determination of the well trajectory, and therefore, may be improved in accuracy using certain methods and systems for improved drilling performance.

[0089] In particular embodiments, at least a portion of steering control system 168 may be located in downhole tool 166 (not shown). In some embodiments, steering control system 168 may communicate with a separate controller (not shown) located in downhole tool 166. In particular, steering control system 168 may receive and process measurements received from downhole surveys and may perform the calculations described herein using the downhole surveys and other information referenced herein.

[0090] In drilling system 100, to aid in the drilling process, data is collected from borehole 106, such as from sensors in BHA 149, downhole tool 166, or both. The collected data may include the geological characteristics of formation 102 in which borehole 106 was formed, the attributes of drilling system 100, including BHA 149, and drilling information such as weighton-bit (WOB), drilling speed, and other information pertinent to the formation of borehole 106. The drilling information may be associated with a particular depth or another identifiable marker to index collected data. As a non-limiting example, the collected data for borehole 106 may capture drilling information indicating that drilling of the well from 1,000 feet to 1,200 feet occurred at a first rate of penetration (ROP) through a first rock layer with a first WOB, while drilling from 1,200 feet to 1,500 feet occurred at a second ROP through a second rock layer with a second WOB (see also FIG. 2). In some applications, the collected data may be used to virtually recreate the drilling process that created borehole 106 in formation 102, such as by displaying a computer simulation of the drilling process. The accuracy with which the drilling process may be recreated depends on a level of detail and accuracy of the collected data, including collected data from a downhole survey of the well trajectory.

[0091] The collected data may be stored in a database that is accessible via a communication network and / or as otherwise desired. In some embodiments, the database storing the collected data for borehole 106 may be located locally at drilling system 100, at a drilling hub that supports a plurality of drilling systems 100 in a region, or at a database server accessible over the communication network that provides access to the database (see also FIG.4). At drilling system 100, the collected data may be stored at the surface 104 or downhole in drill string 146, such as in a memory device included with BHA 149 (see also FIG. 10). Additionally, or alternatively, at least a portion of the collected data may be stored on a removable storage medium, such as using steering control system 168 or BHA 149, which is later coupled to the database in order to transfer the collected data to the database, which may be manually performed at certain intervals, which may be regular or irregular as desired, and / or as otherwise desired.

[0092] In FIG. 1, steering control system 168 is located at or near the surface 104 where borehole 106 is being drilled. Steering control system 168 may be coupled to equipment used in drilling system 100 and may also be coupled to the database, whether the database is physically located locally, regionally, or centrally (see also FIGS. 4 and 5). Accordingly, steering control system 168 may collect and record various inputs, such as measurement data from a magnetometer and an accelerometer that may also be included with BHA 149.

[0093] Steering control system 168 may further be used as a surface steerable system, along with the database, as described above. The surface steerable system may enable an operator to plan and control drilling operations while drilling is being performed. The surface steerable system may itself also be used to perform certain drilling operations, such as controlling certain control systems that, in turn, control the actual equipment in drilling system 100 (see also FIG.5). The control of drilling equipment and drilling operations by steering control system 168 may be manual, manual-assisted, semi-automatic, or automatic, in different embodiments.

[0094] Manual control may involve direct control of the drilling rig equipment, albeit with certain safety limits to prevent unsafe or undesired actions or collisions of different equipment. To enable manual-assisted control, steering control system 168 may present various information, such as using a graphical user interface (GUI) displayed on a display device (seeFIG. 8), to a human operator, and may provide controls that enable the human operator to perform a control operation. The information presented to the user may include live measurements and feedback from the drilling rig and steering control system 168, or the drilling rig itself, and may further include limits and safety-related elements to prevent unwanted actions or equipment states, in response to a manual control command entered by the user using the GUI.

[0095] To implement semi-automatic control, steering control system 168 may itself propose or indicate to the user, such as via the GUI, that a certain control operation, or a sequence of control operations, should be performed at a given time. Then, steering control system 168 may enable the user to imitate the indicated control operation or sequence of control operations, such that once manually started, the indicated control operation or sequence of control operations is automatically completed. The limits and safety features mentioned above for manual control would still apply for semi-automatic control. It is noted that steering control system 168 may execute semi-automatic control using a secondary processor, such as an embedded controller that executes under a real-time operating system (RTOS), that is under the control and command of steering control system 168. To implement automatic control, the step of manual starting the indicated control operation or sequence of operations is eliminated, and steering control system 168 may proceed with only a passive notification to the user of the actions taken.

[0096] In order to implement various control operations, steering control system 168 may perform (or may cause to be performed) various input operations, processing operations, and output operations. The input operations performed by steering control system 168 may result in measurements or other input information being made available for use in any subsequent operations, such as processing or output operations. The input operations may accordingly provide the input information, including feedback from the drilling process itself, to steering control system 168. The processing operations performed by steering control system 168 may be any processing operation, as disclosed herein. The output operations performed by steering control system 168 may involve generating output information for use by external entities, or for output to a user, such as in the form of updated elements in the GUI, as non-limitingexamples. The output information may include at least some of the input information, enabling steering control system 168 to distribute information among various entities and processors.

[0097] In particular, the operations performed by steering control system 168 may include operations such as receiving drilling data representing a drill path, receiving other drilling parameters, calculating a drilling solution for the drill path based on the received data and other available data (e.g., rig characteristics), implementing the drilling solution at the drilling ng, monitoring the drilling process to gauge whether the drilling process is within a defined margin of error of the drill path, and calculating corrections for the drilling process if the drilling process is outside of the margin of error.

[0098] Accordingly, steering control system 168 may receive input information either before drilling, during drilling, or after drilling of borehole 106. The input information may comprise measurements from one or more sensors, as well as survey information collected while drilling borehole 106. The input information may also include a drill plan, a regional formation history, drilling engineer parameters, downhole toolface / inclination information, downhole tool gamma / resistivity information, economic parameters, and reliability parameters, among various other parameters. Some of the input information, such as the regional formation history, may be available from a drilling hub 410, which may have respective access to a regional drilling database (DB) 412 (see FIG. 4). Other input information may be accessed or uploaded from other sources to steering control system 168. As a nonlimiting example, a web interface may be used to interact directly with steering control system 168 to upload the well plan or drilling parameters.

[0099] As noted, the input information may be provided to steering control system 168. After processing by steering control system 168, steering control system 168 may generate control information that may be output to drilling rig 210 (e.g., to rig controls 520 that control drilling equipment 530, see also FIGS. 2 and 5). Drilling rig 210 may provide feedback information using rig controls 520 to steering control system 168. The feedback information may then serve as input information to steering control system 168, thereby enabling steering control system 168 to perform feedback loop control and validation. Accordingly, steering control system 168 may be configured to modify its output information to the drilling rig, inorder to achieve the desired results, which are indicated in the feedback information. The output information generated by steering control system 168 may include indications to modify one or more drilling parameters, the direction of drilling, and the drilling mode, among others. In certain operational modes, such as semi-automatic or automatic, steering control system 168 may generate output information indicative of instructions to rig controls 520 to enable automatic drilling using the latest location of BHA 149. Therefore, an improved accuracy in the determination of the location of BHA 149 may be provided using steering control system 168.

[0100] Referring now to FIG. 2, a drilling environment 200 is depicted schematically and is not drawn to scale or perspective. In particular, drilling environment 200 may illustrate additional details with respect to formation 102 below the surface 104 in drilling system 100 shown in FIG. 1. In FIG. 2, drilling ng 210 may represent various equipment discussed above with respect to drilling system 100 in FIG. 1 that is located at the surface 104.

[0101] In drilling environment 200, it may be assumed that a well plan (also referred to as a well plan) has been formulated to drill borehole 106 extending into the ground to a true vertical depth (TVD) 266 and penetrating several subterranean strata layers. Borehole 106 is shown in FIG. 2 extending through strata layers 268-1 and 270-1, while terminating in strata layer 272-1. Accordingly, as shown, borehole 106 does not extend or reach underlying strata layers 274-1 and 276-1. A target area 280 specified in the well plan may be located in strata layer 272-1 as shown in FIG. 2. Target area 280 may represent a desired endpoint of borehole 106, such as a hydrocarbon producing area indicated by strata layer 272-1. It is noted that target area 280 may be of any shape and size and may be defined using various different methods and information in different embodiments. In some instances, target area 280 may be specified in the well plan using subsurface coordinates, or references to certain markers, which indicate where borehole 106 is to be terminated. In other instances, target area may be specified in the well plan using a depth range within which borehole 106 is to remain. As a non-limiting example, the depth range may correspond to strata layer 272-1. In other examples, target area 280 may extend as far as may be realistically drilled. As a non-limiting example, when borehole 106 is specified to have a horizontal section with a goal to extend into strata layer 172 as far as possible, target area 280 may be defined as strata layer 272-1 itself and drillingmay continue until some other physical limit is reached, such as a property boundary or a physical limitation to the length of the drill string.

[0102] Also visible in FIG. 2 is a fault line 278 that has resulted in a subterranean discontinuity in the fault structure. Specifically, strata layers 268, 270, 272, 274, and 276 have portions on either side of fault line 278. On one side of fault line 278, where borehole 106 is located, strata layers 268-1, 270-1, 272-1, 274-1, and 276-1 are unshifted by fault line 278. On the other side of fault line 278, strata layers 268-2, 270-3, 272-3, 274-3, and 276-3 are shifted downwards by fault line 278.

[0103] Current drilling operations frequently include directional drilling to reach a target, such as target area 280. The use of directional drilling has been found to generally increase an overall amount of production volume per well, but also may lead to significantly higher production rates per well, which are both economically desirable. As shown in FIG. 2, directional drilling may be used to drill the horizontal portion of borehole 106, which increases an exposed length of borehole 106 within strata layer 272-1, and which may accordingly be beneficial for hydrocarbon extraction from strata layer 272-1. Directional drilling may also be used alter an angle of borehole 106 to accommodate subterranean faults, such as indicated by fault line 278 in FIG. 2. Other benefits that may be achieved using directional drilling include sidetracking off of an existing well to reach a different target area or a missed target area, drilling around abandoned drilling equipment, drilling into otherwise inaccessible or difficult to reach locations (e.g., under populated areas or bodies of water), providing a relief well for an existing well, and increasing the capacity of a well by branching off and having multiple boreholes extending in different directions or at different vertical positions for the same well. Directional drilling is often not limited to a straight horizontal borehole 106 but may involve staying within a strata layer that varies in depth and thickness as illustrated by strata layer 172. As such, directional drilling may involve multiple vertical adjustments that complicate the trajectory of borehole 106.

[0104] Referring now to FIG. 3, one embodiment of a portion of borehole 106 is shown in further detail. Using directional drilling for horizontal drilling may introduce certain challenges or difficulties that may not be observed during vertical drilling of borehole 106. As a non-limiting example, a horizontal portion 318 of borehole 106 may be started from a verticalportion 310. In order to make the transition from vertical to horizontal, a curve may be defined that specifies a so-called “build up” section 316. Build up section 316 may begin at a kickoff point 312 in vertical portion 310 and may end at a begin point 314 of horizontal portion 318. The change in inclination in buildup section 316 per measured length drilled is referred to herein as a “build rate” and may be defined in degrees per one hundred feet drilled. As a nonlimiting example, the build rate may have a value of 6° / 100 ft., indicating that there is a six degree change in inclination for every one hundred feet drilled. The build rate for a particular build up section may remain relatively constant or may vary.

[0105] The build rate used for any given build up section may depend on various factors, such as properties of the formation (z.e., strata layers) through which borehole 106 is to be drilled, the trajectory of borehole 106, the particular pipe and drill collars / BHA components used (e.g., length, diameter, flexibility, strength, mud motor bend setting, and drill bit), the mud type and flow rate, the specified horizontal displacement, stabilization, and inclination, among other factors. An overly aggressive built rate may cause problems such as severe doglegs (c.g, sharp changes in direction in the borehole) that may make it difficult or impossible to run casing or perform other operations in borehole 106. Depending on the severity of any mistakes made during directional drilling, borehole 106 may be enlarged or drill bit 146 may be backed out of a portion of borehole 106 and redrilled along a different path. Such mistakes may be undesirable due to the additional time and expense involved. However, if the built rate is too cautious, additional overall time may be added to the drilling process because directional drilling generally involves a lower ROP than straight drilling. Furthermore, directional drilling for a curve is more complicated than vertical drilling and the possibility of drilling errors increases with directional drilling (e.g, overshoot and undershoot that may occur while trying to keep drill bit 148 on the planned trajectory).

[0106] Two modes of drilling, referred to herein as “rotating” and “sliding,” are commonly used to form a borehole 106. Rotating, also called “rotary drilling,” uses top drive 140 or rotary table 162 to rotate drill string 146. Rotating may be used when drilling occurs along a straight trajectory, such as for vertical portion 310 of borehole 106. Sliding, also called “steering” or “directional drilling” as noted above, typically uses a mud motor located downhole at BHA 149. The mud motor may have an adjustable bent housing and is not powered by rotation ofthe drill string. Instead, the mud motor uses hydraulic power derived from the pressurized drilling mud that circulates along borehole 106 to and from the surface 104 to directionally drill borehole 106 in buildup section 316.

[0107] Thus, sliding is used in order to control the direction of the well trajectory during directional drilling. A method to perform a slide may include the following operations. First, during vertical or straight drilling, the rotation of drill string 146 is stopped. Based on feedback from measuring equipment, such as from downhole tool 166, adjustments may be made to drill string 146, such as using top drive 140 to apply various combinations of torque, WOB, and vibration, among other adjustments. The adjustments may continue until a toolface is confirmed that indicates a direction of the bend of the mud motor is oriented to a direction of a desired deviation (z.e., build rate) of borehole 106. Once the desired orientation of the mud motor is attained, WOB to the drill bit is increased, which causes the drill bit to move in the desired direction of deviation. Once sufficient distance and angle have been built up in the curved trajectory, a transition back to rotating mode may be accomplished by rotating the drill string again. The rotation of the drill string after sliding may neutralize the directional deviation caused by the bend in the mud motor due to the continuous rotation around a centerline of borehole 106.

[0108] Referring now to FIG. 4, a drilling architecture 400 is illustrated in diagram form. As shown, drilling architecture 400 depicts a hierarchical arrangement of drilling hubs 410 and a central command 414, to support the operation of a plurality of drilling rigs 210 in different regions 402. Specifically, as described above with respect to FIGS. 1 and 2, drilling rig 210 includes steering control system 168 that is enabled to perform various drilling control operations locally to drilling ng 210. When steering control system 168 is enabled with network connectivity, certain control operations or processing may be requested or queried by steering control system 168 from a remote processing resource. As shown in FIG. 4, drilling hubs 410 represent a remote processing resource for steering control system 168 located at respective regions 402, while central command 414 may represent a remote processing resource for both drilling hub 410 and steering control system 168.

[0109] Specifically, in a region 401-1, a drilling hub 410-1 may serve as a remote processing resource for drilling rigs 210 located in region 401-1, which may vary in numberand are not limited to the exemplary schematic illustration of FIG. 4. Additionally, drilling hub 410-1 may have access to a regional drilling DB 412-1, which may be local to drilling hub 410-1 . Additionally, in a region 401-2, a drilling hub 410-2 may serve as a remote processing resource for drilling rigs 210 located in region 401-2, which may vary in number and are not limited to the exemplary schematic illustration of FIG. 4. Additionally, drilling hub 410-2 may have access to a regional drilling DB 412-2, which may be local to drilling hub 410-2.

[0110] In FIG. 4, respective regions 402 may exhibit the same or similar geological formations. Thus, reference wells, or offset wells, may exist in a vicinity of a given drilling rig 210 in region 402, or where a new well is planned in region 402. Furthermore, multiple drilling rigs 210 may be actively drilling concurrently in region 402 and may be in different stages of drilling through the depths of formation strata layers at region 402. Thus, for any given well being drilled by drilling rig 210 in a region 402, survey data from the reference wells or offset wells may be used to create the well plan and may be used for improved drilling performance. In some implementations, survey data or reference data from a plurality of reference wells may be used to improve drilling performance, such as by reducing an error in estimating TVD or a position of BHA 149 relative to one or more strata layers, as will be described in further detail herein. Additionally, survey data from recently drilled wells, or wells still currently being drilled, including the same well, may be used for reducing an error in estimating TVD or a position of BHA 149 relative to one or more strata layers.

[0111] Also shown in FIG. 4 is central command 414, which has access to central drilling DB 416, and may be located at a centralized command center that is in communication with drilling hubs 410 and drilling rigs 210 in various regions 402. The centralized command center may have the ability to monitor drilling and equipment activity at any one or more drilling rigs 210. In some embodiments, central command 414 and drilling hubs 412 may be operated by a commercial operator of drilling rigs 210 as a service to customers who have hired the commercial operator to drill wells and provide other drilling-related services.

[0112] In FIG. 4, it is particularly noted that central drilling DB 416 may be a central repository that is accessible to drilling hubs 410 and drilling rigs 210. Accordingly, central drilling DB 416 may store information for various drilling rigs 210 in different regions 402. In some embodiments, central drilling DB 416 may serve as a backup for at least one regionaldrilling DB 412 or may otherwise redundantly store information that is also stored on at least one regional drilling DB 412. In turn, regional drilling DB 412 may serve as a backup or redundant storage for at least one drilling rig 210 in region 402. As a non-limiting example, regional drilling DB 412 may store information collected by steering control system 168 from drilling ng 210.

[0113] In some embodiments, the formulation of a well plan for drilling rig 210 may include processing and analyzing the collected data in regional drilling DB 412 to create a more effective drill plan. Furthermore, once the drilling has begun, the collected data may be used in conjunction with current data from drilling rig 210 to improve drilling decisions. As noted, the functionality of steering control system 168 may be provided at drilling rig 210, or may be provided, at least in part, at a remote processing resource, such as drilling hub 410 or central command 414.

[0114] As noted, steering control system 168 may provide functionality as a surface steerable system for controlling drilling rig 210. Steering control system 168 may have access to regional drilling DB 412 and central drilling DB 416 to provide the surface steerable system functionality. As will be described in greater detail below, steering control system 168 may be used to plan and control drilling operations based on input information, including feedback from the drilling process itself. Steering control system 168 may be used to perform operations such as receiving drilling data representing a drill trajectory and other drilling parameters, calculating a drilling solution for the drill trajectory based on the received data and other available data (e.g., rig characteristics), implementing the drilling solution at drilling rig 210, monitoring the drilling process to gauge whether the drilling process is within a margin of error that is defined for the drill trajectory, or calculating corrections for the drilling process if the drilling process is outside of the margin of error.

[0115] Referring now to FIG. 5, an example of rig control systems 500 is illustrated in schematic form. It is noted that rig control systems 500 may include fewer or more elements than shown in FIG. 5 in different embodiments. As shown, rig control systems 500 includes steering control system 168 and drilling rig 210. Specifically, steering control system 168 is shown with logical functionality including an autodriller 510, a bit guidance 512, and an autoslide 514. Drilling rig 210 is hierarchically shown including rig controls 520, whichprovide secure control logic and processing capability, along with drilling equipment 530, which represents the physical equipment used for drilling at drilling rig 210. As shown, rig controls 520 include WOB / differential pressure control system 522, positional / rotary control system 524, fluid circulation control system 526, and sensor system 528, while drilling equipment 530 includes a draw works / snub 532, top drive 140, mud pumping equipment 536, and MWD / wireline equipment 538.

[0116] Steering control system 168 represent an instance of a processor having an accessible memory storing instructions executable by the processor, such as an instance of controller 1000 shown in FIG. 10. Also, WOB / differential pressure control system 522, positional / rotary control system 524, and fluid circulation control system 526 may each represent an instance of a processor having an accessible memory storing instructions executable by the processor, such as an instance of controller 1000 shown in FIG. 10, but for example, in a configuration as a programmable logic controller (PLC) that may not include a user interface but may be used as an embedded controller. Accordingly, it is noted that each of the systems included in rig controls 520 may be a separate controller, such as a PLC, and may autonomously operate, at least to a degree. Steering control system 168 may represent hardware that executes instructions to implement a surface steerable system that provides feedback and automation capability to an operator, such as a driller. As anon-limiting example, steering control system 168 may cause autodriller 510, bit guidance 512 (also referred to as a bit guidance system (BGS)), and autoslide 514 (among others, not shown) to be activated and executed at an appropriate time during drilling. In particular implementations, steering control system 168 may be enabled to provide a user interface during drilling, such as the user interface 850 depicted and described below with respect to FIG. 8. Accordingly, steering control system 168 may interface with rig controls 520 to facilitate manual, assisted manual, semi-automatic, and automatic operation of drilling equipment 530 included in drilling rig 210. It is noted that rig controls 520 may also accordingly be enabled for manual or user-controlled operation of drilling and may include certain levels of automation with respect to drilling equipment 530.

[0117] In rig control systems 500 of FIG. 5, WOB / differential pressure control system 522 may be interfaced with draw works / snubbing unit 532 to control WOB of drill string 146. Positional / rotary control system 524 may be interfaced with top drive 140 to control rotationof drill string 146. Fluid circulation control system 526 may be interfaced with mud pumping equipment 536 to control mud flow and may also receive and decode mud telemetry signals. Sensor system 528 may be interfaced with MWD / wireline equipment 538, which may represent various BHA sensors and instrumentation equipment, among other sensors that may be downhole or at the surface.

[0118] In rig control systems 500, autodriller 510 may represent an automated rotary drilling system and may be used for controlling rotary drilling. Accordingly, autodriller 510 may enable automate operation of rig controls 520 during rotary drilling, as indicated in the drill plan. Bit guidance 512 may represent an automated control system to monitor and control performance and operation drilling bit 148.

[0119] In rig control systems 500, autoslide 514 may represent an automated slide drilling system and may be used for controlling slide drilling. Accordingly, autoshde 514 may enable automate operation of rig controls 520 during a slide and may return control to steering control system 168 for rotary drilling at an appropriate time, as indicated in the drill plan. In particular implementations, autoslide 514 may be enabled to provide a user interface during slide drilling to specifically monitor and control the slide. As a non-limiting example, autoshde 514 may rely on bit guidance 512 for orienting a toolface and on autodriller 510 to set WOB or control rotation or vibration of drill string 146.

[0120] FIG. 6 illustrates one embodiment of control algorithm modules 600 used with steering control system 168. The control algorithm modules 600 of FIG. 6 include: a slide control executor 650 that is responsible for managing the execution of the slide control algorithms; a slide control configuration provider 652 that is responsible for validating, maintaining, and providing configuration parameters for the other software modules; a BHA & pipe specification provider 654 that is responsible for managing and providing details of BHA 149 and drill string 146 characteristics; a borehole geometry model 656 that is responsible for keeping track of the borehole geometry and providing a representation to other software modules; a top drive orientation impact model 658 that is responsible for modeling the impact that changes to the angular orientation of top drive 140 have had on the toolface control; a top drive oscillator impact model 660 that is responsible for modeling the impact that oscillations of top drive 140 has had on the toolface control; an ROP impact model 662that is responsible for modeling the effect on the toolface control of a change in ROP or a corresponding ROP set point; a WOB impact model 664 that is responsible for modeling the effect on the toolface control of a change in WOB or a corresponding WOB set point; a differential pressure impact model 666 that is responsible for modeling the effect on the toolface control of a change in differential pressure (DP) or a corresponding DP set point; a torque model 668 that is responsible for modeling the comprehensive representation of torque for surface, downhole, break over, and reactive torque, modeling impact of those torque values on toolface control, and determining torque operational thresholds; a toolface control evaluator 672 that is responsible for evaluating all factors impacting toolface control and whether adjustments need to be projected, determining whether re-alignment off-bottom is indicated, and determining off-bottom toolface operational threshold windows; a toolface projection 670 that is responsible for projecting toolface behavior for top drive 140, the top drive oscillator, and auto driller adjustments; a top drive adjustment calculator 674 that is responsible for calculating top drive adjustments resultant to toolface projections; an oscillator adjustment calculator 676 that is responsible for calculating oscillator adjustments resultant to toolface projections; and an autodriller adjustment calculator 678 that is responsible for calculating adjustments to autodriller 510 resultant to toolface projections.

[0121] FIG. 7 illustrates one embodiment of a steering control process 700 for determining an optimal corrective action for drilling. Steering control process 700 may be used for rotary drilling or slide drilling in different embodiments.

[0122] Steering control process 700 in FIG. 7 illustrates a variety of inputs that may be used to determine an optimum corrective action. As shown in FIG. 7, the inputs include formation hardness / unconfined compressive strength (UCS) 710, formation structure 712, inclination / azimuth 714, current zone 716, measured depth 718, desired toolface 730, vertical section 720, bit factor 722, mud motor torque 724, reference trajectory 730, and angular velocity 726. In FIG. 7, reference trajectory 730 of borehole 106 is determined to calculate a trajectory misfit in a step 732. Step 732 may output the trajectory misfit to determine an optimal corrective action to minimize the misfit at step 734, which may be performed using the other inputs described above. Then, at step 736, the drilling rig is caused to perform the optimal corrective action.

[0123] It is noted that in some implementations, at least certain portions of steering control process 700 may be automated or performed without user intervention, such as using rig control systems 700 (see FIG. 7). In other implementations, the optimal corrective action in step 736 may be provided or communicated (by display, SMS message, email, or otherwise) to one or more human operators, who may then take appropriate action. The human operators may be members of a rig crew, which may be located at or near drilling rig 210 or may be located remotely from drilling rig 210.

[0124] Referring to FIG. 8, one embodiment of a user interface 850 that may be generated by steering control system 168 for monitoring and operation by a human operator is illustrated. User interface 850 may provide many different types of information in an easily accessible format. As a non-limiting example, user interface 850 may be shown on a computer monitor, a television, a viewing screen (e.g., a display device) associated with steering control system 168. In some embodiments, at least certain portions of user interface 850 may be displayed to and operated by a user of steering control system 168 on a mobile device, such as a tablet or a smartphone (see also FIG. 10). As a non-limiting example, steering control system 168 may support mobile applications that enable user interface 850, or other user interfaces, to be used on the mobile device, for example, within a vicinity of drilling rig 210.

[0125] As shown in FIG. 8, a user interface 850 provides visual indicators such as a hole depth indicator 852, a bit depth indicator 854, a GAMMA indicator 856, an inclination indicator 858, an azimuth indicator 860, and a TVD indicator 862. Other indicators may also be provided, including a ROP indicator 864, a mechanical specific energy (MSE) indicator 866, a differential pressure indicator 868, a standpipe pressure indicator 870, a flow rate indicator 872, a rotary RPM (angular velocity) indicator 874, a bit speed indicator 876, and a WOB indicator 878.

[0126] In FIG. 8, at least some of indicators 864, 866, 868, 870, 872, 874, 876, and 878 may include a marker representing a target value. As a non-limiting example, markers may be set as certain given values, but it is noted that any desired target value may be used. Although not shown, in some embodiments, multiple markers may be present on a single indicator. The markers may vary in color or size. As a non-limiting example, ROP indicator 864 may include a marker 865 indicating that the target value is 50 feet / hour (or 15 meters per hour). MSEindicator 866 may include a marker 867 indicating that the target value is 37 kilo pounds per square inch (ksi) (or 255 MegaPascals (MPa)). Differential pressure indicator 868 may include a marker 869 indicating that the target value is 200 psi (or 1,380 kPa). ROP indicator 864 may include a marker 865 indicating that the target value is 50 feet / hour (or 15 m / h). Standpipe pressure indicator 870 may have no marker in the present example. Flow rate indicator 872 may include a marker 873 indicating that the target value is 500 gallons per minute (gpm) (or 31.5 liters per second). Rotary RPM indicator 874 may include a marker 875 indicating that the target value is 0 RPM (e.g., due to sliding). Bit speed indicator 876 may include a marker 877 indicating that the target value is 150 RPM. WOB indicator 878 may include a marker 879 indicating that the target value is 10 klbs (or 4,500 kg). Each indicator may also include a colored band, or another marking, to indicate, for example, whether the respective gauge value is within a safe range (e.g., indicated by a green color), within a caution range (e.g., indicated by a yellow color), or within a danger range (e.g., indicated by a red color).

[0127] In FIG. 8, a log chart 880 may visually indicate depth versus one or more measurements (e.g., may represent log inputs relative to a progressing depth chart). As a nonlimiting example, log chart 880 may have a Y-axis representing depth and an X-axis representing a measurement such as GAMMA count 881 (as shown), ROP 883 (e.g., empirical ROP and normalized ROP), or resistivity. An autopilot button 882 and an oscillate button 884 may be used to control activity. As a non-limiting example, autopilot button 882 may be used to engage or disengage autodriller 510, while oscillate button 884 may be used to directly control oscillation of drill string 146 or to engage / di sengage an external hardware device or controller.

[0128] In FIG. 8, a circular chart 886 may provide current and historical toolface orientation information (e.g, which way the bend is pointed). For purposes of illustration, circular chart 886 represents three hundred and sixty degrees. A series of circles within circular chart 886 may represent a timeline of toolface orientations, with the sizes of the circles indicating the temporal position of each circle. As a non-limiting example, larger circles may be more recent than smaller circles, so a largest circle 888 may be the newest reading and a smallest circle 889 may be the oldest reading. In other embodiments, circles 889, 888 may represent the energy or progress made via size, color, shape, a number within a circle, etc. Asa non-limiting example, a size of a particular circle may represent an accumulation of orientation and progress for the period of time represented by the circle. In other embodiments, concentric circles representing time (e.g., with the outside of circular chart 886 being the most recent time and the center point being the oldest time) may be used to indicate the energy or progress (e.g, via color or patterning such as dashes or dots rather than a solid line).

[0129] In user interface 850, circular chart 886 may also be color coded, with the color coding existing in a band 890 around circular chart 886 or positioned or represented in other ways. The color coding may use colors to indicate activity in a certain direction. As a nonlimiting example, the color red may indicate the highest level of activity, while the color blue may indicate the lowest level of activity. Furthermore, the arc range in degrees of a color may indicate the amount of deviation. Accordingly, a relatively narrow (e.g, thirty degrees) arc of red with a relatively broad (e.g., three hundred degrees) arc of blue may indicate that most activity is occurring in a particular toolface orientation with little deviation. As shown in user interface 850, the color blue may extend from approximately 22-337 degrees, the color green may extend from approximately 15-22 degrees and 337-345 degrees, the color yellow may extend a few degrees around the 13 and 345 degree marks, while the color red may extend from approximately 347-10 degrees. Transition colors or shades may be used with, for example, the color orange marking the transition between red and yellow or a light blue marking the transition between blue and green. This color coding may enable user interface 850 to provide an intuitive summary of how narrow the standard deviation is and how much of the energy intensity is being expended in the proper direction. Furthermore, the center of energy may be viewed relative to the target. As a non-limiting example, user interface 850 may clearly show that the target is at 90 degrees, but the center of energy is at 45 degrees.

[0130] In user interface 850, other indicators, such as a slide indicator 892, may indicate how much time remains until a slide occurs or how much time remains for a current slide. As a non-limiting example, slide indicator 892 may represent a time, a percentage (e.g, as shown, a current slide may be 56% complete), a distance completed, or a distance remaining. Slide indicator 892 may graphically display information using, as a non-limiting example, a colored bar 893 that increases or decreases with slide progress. In some embodiments, slide indicator 892 may be built into circular chart 886 (e.g., around the outer edge with anincreasing / decreasing band), while in other embodiments slide indicator 892 may be a separate indicator such as a meter, a bar, a gauge, or another indicator type. In various implementations, slide indicator 892 may be refreshed by autoslide 514.

[0131] In user interface 850, an error indicator 894 may indicate a magnitude and a direction of error. As a non-limiting example, error indicator 894 may indicate that an estimated drill bit position is a certain distance from the planned trajectory, with a location of error indicator 894 around the circular chart 886 representing the heading. As a non-limiting example, FIG. 8 illustrates an error magnitude of 15 feet and an error direction of 15 degrees. Error indicator 894 may be any color but may be red for purposes of example. It is noted that error indicator 894 may present a zero if there is no error. Error indicator may represent that drill bit 148 is on the planned trajectory using other means, such as being a green color. Transition colors, such as yellow, may be used to indicate varying amounts of error. In some embodiments, error indicator 894 may not appear unless there is an error in magnitude or direction. A marker 896 may indicate an ideal slide direction. Although not shown, other indicators may be present, such as a bit life indicator to indicate an estimated lifetime for the current bit based on a value such as time or distance.

[0132] It is noted that user interface 850 may be arranged in many different ways. As a non-limiting example, colors may be used to indicate normal operation, warnings, and problems. In such cases, the numerical indicators may display numbers in one color (e.g., green) for normal operation, may use another color (e.g., yellow) for warnings, and may use yet another color (e.g., red) when a serious problem occurs. The indicators may also flash or otherwise indicate an alert. The gauge indicators may include colors (e.g., green, yellow, and red) to indicate operational conditions and may also indicate the target value (e.g., an ROP of 100 feet / hour). As a non-limiting example, ROP indicator 864 may have a green bar to indicate a normal level of operation (e.g., from 10-300 feet / hour), a yellow bar to indicate a warning level of operation (e.g., from 300-360 feet / hour), and a red bar to indicate a dangerous or otherwise out of parameter level of operation (e.g., from 360-390 feet / hour). ROP indicator 864 may also display a marker at 100 feet / hour to indicate the desired target ROP.

[0133] Furthermore, the use of numeric indicators, gauges, and similar visual display indicators may be varied based on factors such as the information to be conveyed and thepersonal preference of the viewer. Accordingly, user interface 850 may provide a customizable view of various drilling processes and information for a particular individual involved in the drilling process. As a non-limiting example, steering control system 168 may enable a user to customize the user interface 850 as desired, although certain features (e.g., standpipe pressure) may be locked to prevent a user from intentionally or accidentally removing important drilling information from user interface 850. Other features and attributes of user interface 850 may be set by user preference. Accordingly, the level of customization and the information shown by the user interface 850 may be controlled based on who is viewing user interface 850 and their role in the drilling process.

[0134] Referring to FIG. 9, one embodiment of a guidance control loop (GCL) 900 is shown in further detail GCL 900 may represent one example of a control loop or control algorithm executed under the control of steering control system 168. GCL 900 may include various functional modules, including a build rate predictor 902, a geo modified well planner 904, a borehole estimator 906, a slide estimator 908, an error vector calculator 910, a geological drift estimator 912, a slide planner 914, a convergence planner 916, and a tactical solution planner 918. In the following description of GCL 900, the term “external input” refers to input received from outside GCL 900 , while “internal input” refers to input exchanged between functional modules of GCL 900.

[0135] In FIG. 9, build rate predictor 902 receives external input representing BHA information and geological information, receives internal input from the borehole estimator 906, and provides output to geo modified well planner 904, slide estimator 908, slide planner 914, and convergence planner 916. Build rate predictor 902 is configured to use the BHA information and geological information to predict drilling build rates of current and future sections of borehole 106. As a non-limiting example, build rate predictor 902 may determine how aggressively a curve will be built for a given formation with BHA 149 and other equipment parameters.

[0136] In FIG. 9, build rate predictor 902 may use the orientation of BHA 149 to the formation to determine an angle of attack for formation transitions and build rates within a single layer of a formation. As a non-limiting example, if a strata layer of rock is below a strata layer of sand, a formation transition exists between the strata layer of sand and the strata layerof rock. Approaching the strata layer of rock at a 90 degree angle may provide a good toolface and a clean drill entry, while approaching the rock layer at a 45 degree angle may build a curve relatively quickly. An angle of approach that is near parallel may cause drill bit 148 to skip off the upper surface of the strata layer of rock. Accordingly, build rate predictor 902 may calculate BHA orientation to account for formation transitions. Within a single strata layer, build rate predictor 902 may use the BHA orientation to account for internal layer characteristics (e.g., grain) to determine build rates for different parts of a strata layer. The BHA information may include bit characteristics, mud motor bend setting, stabilization, and mud motor bit to bend distance. The geological information may include formation data such as compressive strength, thicknesses, and depths for formations encountered in the specific drilling location. Such information may enable a calculation-based prediction of the build rates and ROP that may be compared to both results obtained while drilling borehole 106 and regional historical results (e.g., from the regional drilling DB 412) to improve the accuracy of predictions as drilling progresses. Build rate predictor 902 may also be used to plan convergence adjustments and confirm in advance of drilling that targets may be achieved with current parameters.

[0137] In FIG. 9, geo modified well planner 904 receives external input representing a drill plan, internal input from build rate predictor 902 and geo drift estimator 912 and provides output to slide planner 914 and error vector calculator 910. Geo modified well planner 904 uses the input to determine whether there is a more optimal trajectory than that provided by the drill plan, while staying within specified error limits. More specifically, geo modified well planner 904 takes geological information (e.g., drift) and calculates whether another trajectory solution to the target may be more efficient in terms of cost or reliability. The outputs of geo modified well planner 904 to slide planner 914 and error vector calculator 910 may be used to calculate an error vector based on the current vector to the newly calculated trajectory and to modify slide predictions. In some embodiments, geo modified well planner 904 (or another module) may provide functionality needed to track a formation trend. As a non-limiting example, in horizontal wells, a geologist may provide steering control system 168 with a target inclination as a set point for steering control system 168 to control. As a non-limiting example, the geologist may enter a target to steering control system 168 of 90.5 - 91.0 degrees ofinclination for a section of borehole 106. Geo modified well planner 904 may then treat the target as a vector target, while remaining within the error limits of the original drill plan. In some embodiments, geo modified well planner 904 may be an optional module that is not used unless the well plan is to be modified. As a non-limiting example, if the well plan is marked in steering control system 168 as non-modifiable, geo modified well planner 904 may be bypassed altogether or geo modified well planner 904 may be configured to pass the well plan through without any changes.

[0138] In FIG. 9, borehole estimator 906 may receive external inputs representing BHA information, measured depth information, survey information (e.g, azimuth and inclination), and may provide outputs to build rate predictor 902, error vector calculator 910, and convergence planner 916. Borehole estimator 906 may be configured to provide an estimate of the actual borehole and drill bit position and trajectory angle without delay, based on either straight line projections or projections that incorporate sliding. Borehole estimator 906 may be used to compensate for a sensor being physically located some distance behind drill bit 148 (e.g., 50 feet) in drill string 146, which makes sensor readings lag the actual bit location by 50 feet. Borehole estimator 906 may also be used to compensate for sensor measurements that may not be continuous (e.g., a sensor measurement may occur every 100 feet). Borehole estimator 906 may provide the most accurate estimate from the surface to the last survey location based on the collection of survey measurements. Also, borehole estimator 906 may take the slide estimate from slide estimator 908 (described below) and extend the slide estimate from the last survey point to a current location of drill bit 148. Using the combination of these two estimates, borehole estimator 906 may provide steering control system 168 with an estimate of the drill bit's location and trajectory angle from which guidance and steering solutions may be derived. An additional metric that may be derived from the borehole estimate is the effective build rate that is achieved throughout the drilling process.

[0139] In FIG. 9, slide estimator 908 receives external inputs representing measured depth and differential pressure information, receives internal input from build rate predictor 902, and provides output to borehole estimator 906 and geo modified well planner 904. Slide estimator 908 may be configured to sample toolface orientation, differential pressure, measured depth(MD) incremental movement, MSB, and other sensor feedback to quantify / estimate a deviation vector and progress while sliding.

[0140] Traditionally, deviation from the slide would be predicted by a human operator based on experience. The operator would, for example, use a long slide cycle to assess what likely was accomplished during the last slide. However, the results are generally not confirmed until the downhole survey sensor point passes the slide portion of the borehole, often resulting in a response lag defined by a distance of the sensor point from the drill bit tip (e.g., approximately 50 feet). Such a response lag may introduce inefficiencies in the slide cycles due to over / under correction of the actual trajectory relative to the planned trajectory.

[0141] In GCL 900, using slide estimator 908, each toolface update may be algorithmically merged with the average differential pressure of the period between the previous and current toolface readings, as well as the MD change during this period to predict the direction, angular deviation, and MD progress during the period. As an example, the periodic rate may be between 10 and 60 seconds per cycle depending on the toolface update rate of downhole tool 166. With a more accurate estimation of the slide effectiveness, the sliding efficiency may be improved. The output of slide estimator 908 may accordingly be periodically provided to borehole estimator 906 for accumulation of well deviation information, as well to geo modified well planner 904. Some or all of the output of the slide estimator 908 may be output to an operator, such as shown in the user interface 850 of FIG. 8.

[0142] In FIG. 9, error vector calculator 910 may receive internal input from geo modified well planner 904 and borehole estimator 906. Error vector calculator 910 may be configured to compare the planned well trajectory to an actual borehole trajectory and drill bit position estimate. Error vector calculator 910 may provide the metrics used to determine the error (e.g., how far off) the current drill bit position and trajectory are from the drill plan. As a non-limiting example, error vector calculator 910 may calculate the error between the current bit position and trajectory to the planned trajectory and the desired bit position. Error vector calculator 910 may also calculate a projected bit position / projected trajectory representing the future result of a current error.

[0143] In FIG. 9, geological drift estimator 912 receives external input representing geological information and provides outputs to geo modified well planner 904, slide planner914, and tactical solution planner 918. During drilling, drift may occur as the particular characteristics of the formation affect the drilling direction. More specifically, there may be a trajectory bias that is contributed by the formation as a function of ROP and BHA 149. Geological drift estimator 912 is configured to provide a drift estimate as a vector that may then be used to calculate drift compensation parameters that may be used to offset the drift in a control solution.

[0144] In FIG. 9, slide planner 914 receives internal input from build rate predictor 902, geo modified well planner 904, error vector calculator 910, and geological drift estimator 912, and provides output to convergence planner 916 as well as an estimated time to the next slide. Slide planner 914 may be configured to evaluate a slide / dnll ahead cost equation and plan for sliding activity, which may include factoring in BHA wear, expected build rates of current and expected formations, and the well plan trajectory. During drill ahead, slide planner 914 may attempt to forecast an estimated time of the next slide to aid with planning. As a non-limiting example, if additional lubricants (e.g., fluorinated beads) are indicated for the next slide, and pumping the lubricants into drill string 146 has a lead time of 30 minutes before the slide, the estimated time of the next slide may be calculated and then used to schedule when to start pumping the lubricants. Functionality for a loss circulation material (LCM) planner may be provided as part of slide planner 914 or elsewhere (e.g, as a stand-alone module or as part of another module described herein). The LCM planner functionality may be configured to determine whether additives should be pumped into the borehole based on indications such as flow-in versus flow-back measurements. As a non-limiting example, if drilling through a porous rock formation, fluid being pumped into the borehole may get lost in the rock formation. To address this issue, the LCM planner may control pumping LCM into the borehole to clog up the holes in the porous rock surrounding the borehole to establish a more closed-loop control system for the fluid.

[0145] In FIG. 9, slide planner 914 may also look at the current position relative to the next connection. A passageway may happen every 90 to 100 feet (or some other distance or distance range based on the particulars of the drilling operation) and slide planner 914 may avoid planning a slide when close to a passageway or when the slide would carry through the connection. As a non-limiting example, if the slide planner 914 is planning a 50 foot slide butonly 20 feet remain until the next connection, slide planner 914 may calculate the slide starting after the next passageway and make any changes to the slide parameters to accommodate waiting to slide until after the next connection. Such flexible implementation avoids inefficiencies that may be caused by starting the slide, stopping for the connection, and then having to reorient the toolface before finishing the slide. During slides, slide planner 914 may provide some feedback as to the progress of achieving the desired goal of the current slide. In some embodiments, slide planner 914 may account for reactive torque in the drill string. More specifically, when rotating is occurring, there is a reactional torque wind up in drill string 146. When the rotating is stopped, drill string 146 unwinds, which changes toolface orientation and other parameters. When rotating is started again, drill string 146 starts to wind back up. Slide planner 914 may account for the reactional torque so that toolface references are maintained, rather than stopping rotation and then trying to adjust to an optimal toolface orientation. While not all downhole tools may provide toolface orientation when rotating, using one that does supply such information for GCL 900 may significantly reduce the transition time from rotating to sliding.

[0146] In FIG. 9, convergence planner 916 receives internal inputs from build rate predictor 902, borehole estimator 906, and slide planner 914, and provides output to tactical solution planner 918. Convergence planner 916 is configured to provide a convergence plan when the current drill bit position is not within a defined margin of error of the planned well trajectory. The convergence plan represents a path from the current drill bit position to an achievable and optimal convergence target point along the planned trajectory. The convergence plan may take account the amount of sliding / drill ing ahead that has been planned to take place by slide planner 914. Convergence planner 916 may also use BHA orientation information for angle of attack calculations when determining convergence plans as described above with respect to build rate predictor 902. The solution provided by convergence planner 916 defines a new trajectory solution for the current position of drill bit 148. The solution may be immediate without delay, or planned for implementation at a future time that is specified in advance.

[0147] In FIG. 9, tactical solution planner 918 receives internal inputs from geological drift estimator 912 and convergence planner 916 and provides external outputs representinginformation such as toolface orientation, differential pressure, and mud flow rate. Tactical solution planner 918 is configured to take the trajectory solution provided by convergence planner 916 and translate the solution into control parameters that may be used to control drilling ng 210. As a non-limiting example, tactical solution planner 918 may convert the solution into settings for control systems 522, 524, and 526 to accomplish the actual drilling based on the solution. Tactical solution planner 918 may also perform performance optimization to optimizing the overall drilling operation as well as optimizing the drilling itself (e.g., how to drill faster).

[0148] Other functionality may be provided by GCL 900 in additional modules or added to an existing module. As a non-limiting example, there is a relationship between the rotational position of the drill pipe on the surface and the orientation of the downhole toolface. Accordingly, GCL 900 may receive information corresponding to the rotational position of the drill pipe on the surface. GCL 900 may use this surface positional information to calculate current and desired toolface orientations. These calculations may then be used to define control parameters for adjusting the top drive 140 to accomplish adjustments to the downhole toolface in order to steer the trajectory of borehole 106.

[0149] For purposes of example, an object-oriented software approach may be utilized to provide a class-based structure that may be used with GCL 900, or other functionality provided by steering control system 168. In GCL 900, a drilling model class may be defined to capture and define the drilling state throughout the drilling process. The drilling model class may include information obtained without delay. The drilling model class may be based on the following components and sub-models: a drill bit model, a borehole model, a rig surface gear model, a mud pump model, a / differential pressure model, a positional / rotary model, an MSE model, an active drill plan, and control limits. The drilling model class may produce a control output solution and may be executed via a main processing loop that rotates through the various modules of GCL 900. The drill bit model may represent the current position and state of drill bit 148. The drill bit model may include athree dimensional (3D) position, a drill bit trajectory, BHA information, bit speed, and toolface (e.g., orientation information). The 3D position may be specified in north-south (NS), east-west (EW), and true vertical depth (TVD). The drill bit trajectory may be specified as an inclination angle and an azimuth angle. The BHA informationmay be a set of dimensions defining the active BHA. The borehole model may represent the current path and size of the active borehole. The borehole model may include hole depth information, an array of survey points collected along the borehole path, a gamma log, and borehole diameters. The hole depth information is for current drilling of borehole 106. The borehole diameters may represent the diameters of borehole 106 as drilled over current drilling. The rig surface gear model may represent pipe length, block height, and other models, such as the mud pump model, WOB / differential pressure model, positional / rotary model, and MSB model. The mud pump model represents mud pump equipment and includes flow rate, standpipe pressure, and differential pressure. The WOB / differential pressure model represents draw works or other WOB / differential pressure controls and parameters, including WOB. The positional / rotary model represents top drive or other positional / rotary controls and parameters including rotary RPM and spindle position. The active well plan represents the target borehole path and may include an external well plan and a modified drill plan. The control limits represent defined parameters that may be set as maximums and / or minimums. As a nonlimiting example, control limits may be set for the rotary RPM in the top drive model to limit the maximum rotations per minute (RPMs) to the defined level. The control output solution may represent the control parameters for drilling rig 210.

[0150] Each functional module of GCL 900 may have behavior encapsulated within a respective class definition. During a processing window, the individual functional modules may have an exclusive portion in time to execute and update the drilling model. For purposes of example, the processing order for the functional modules may be in the sequence of geo modified well planner 904, build rate predictor 902, slide estimator 908, borehole estimator 906, error vector calculator 910, slide planner 914, convergence planner 916, geological drift estimator 912, and tactical solution planner 918. It is noted that other sequences may be used in different implementations.

[0151] In FIG. 9, GCL 900 may rely on a programmable timer module that provides a timing mechanism to provide timer event signals to drive the mam processing loop. While steering control system 168 may rely on timer and date calls driven by the programming environment, timing may be obtained from other sources than system time. In situations where it may be advantageous to manipulate the clock (e.g., for evaluation and testing), aprogrammable timer module may be used to alter the system time. As a non-limiting example, the programmable timer module may enable a default time set to the system time and a time scale of 1.0, may enable the system time of steering control system 168 to be manually set, may enable the time scale relative to the system time to be modified, or may enable periodic event time requests scaled to a requested time scale.

[0152] Referring now to FIG. 10, a block diagram illustrating selected elements of an embodiment of a controller 1000 for performing steering methods and systems for improved drilling performance according to the present disclosure. In various embodiments, controller 1000 may represent an implementation of steering control system 168. In other embodiments, at least certain portions of controller 1000 may be used for control systems 510, 512, 514, 522, 524, and 526 (see FIG. 5).

[0153] In the embodiment depicted in FIG. 10, controller 1000 includes processor 1001 coupled via shared bus 1002 to storage media collectively identified as memory media 1010.

[0154] Controller 1000, as depicted in FIG. 10, further includes network adapter 1020 that interfaces controller 1000 to a network (not shown in FIG. 10). In embodiments suitable for use with user interfaces, controller 1000, as depicted in FIG. 10, may include peripheral adapter 1006, which provides connectivity for the use of input device 1008 and output device 1009. Input device 1008 may represent a device for user input, such as a keyboard or a mouse, or even a video camera. Output device 1009 may represent a device for providing signals or indications to a user, such as loudspeakers for generating audio signals.

[0155] Controller 1000 is shown in FIG. 10 including display adapter 1004 and further includes a display device 1005. Display adapter 1004 may interface shared bus 1002, or another bus, with an output port for one or more display devices, such as display device 1005. Display device 1005 may be implemented as a liquid crystal display screen, a computer monitor, a television, or the like. Display device 1005 may comply with a display standard for the corresponding type of display. Standards for computer monitors include analog standards such as video graphics array (VGA), extended graphics array (XGA), etc., or digital standards such as digital visual interface (DVI), definition multimedia interface (HDMI), among others. A television display may comply with standards such as NTSC (National Television SystemCommittee), PAL (Phase Alternating Line), or another suitable standard. Display device 1005 may include an output device 1009, such as one or more integrated speakers to play audio content, or may include an input device 1008, such as a microphone or video camera.

[0156] In FIG. 10, memory media 1010 encompasses persistent and volatile media, fixed and removable media, and magnetic and semiconductor media. Memory media 1010 is operable to store instructions, data, or both. Memory media 1010 as shown includes sets or sequences of instructions 1024-2, namely, an operating system 1012 and steering control 1014. Operating system 1012 may be a UNIX or UNIX-like operating system, a Windows® family operating system, or another suitable operating system. Instructions 1024 may also reside, completely or at least partially, within processor 1001 during execution thereof. It is further noted that processor 1001 may be configured to receive instructions 1024-1 from instructions 1024-2 via shared bus 1002. In some embodiments, memory media 1010 is configured to store and provide executable instructions for executing GCL 900, as mentioned previously, among other methods and operations disclosed herein.

[0157] As noted previously, steering control system 168 may support the display and operation of various user interfaces, such as in a client / server architecture. As a non-limiting example, steering control 1014 may be enabled to support a web server for providing the user interface to a web browser client, such as on a mobile device or on a personal computer device. In another example, steering control 1014 may be enabled to support an app server for providing the user interface to a client app, such as on a mobile device or on a personal computer device. It is noted that in the web server or the app server architecture, surface steering control 1014 may handle various communications to rig controls 520 while simultaneously supporting the web browser client or the client app with the user interface.Videos

[0158] FIGS. 11-18 illustrate a video reporting system and a drilling system incorporating such video reporting systems according to various embodiments. In certain embodiments, the video reporting system may be utilized with the drilling system of FIGS. 1-10, sub-components thereof, and / or as otherwise desired.

[0159] During drilling a well, a great deal of information is generated and collected. Stakeholders interested in the drilling operations usually want updates reporting on drilling progress, often daily or sometimes more frequently. Daily videos (DDR) are typically generated by drilling operators and teams during the drilling process of oil and gas wells. These reports may serve as a critical record of all activities, events, and data associated with the drilling operation on a day-to-day basis and serve as progress reports to persons interested in the drilling of a well and its progress. Such reports may provide valuable insights, as well as a chronological overview of the drilling progress, technical details, safety measures, unexpected conditions, corrections, how progress compares to the well plan, and other relevant information. Videos may provide well information, date and time of drilling activities, weather conditions, crew and personnel, drilling progress, days versus depth curves to show if the operation is ahead or behind schedule and or cost Authorization For Expenditures, and by how much, drilling parameters, mud and drilling fluid information (mud weight, viscosity, plastic viscosity, yield point, temperature), safety measures and times since last incident, equipment used (drill pipe, downhole tools including BHA, MWD, LWD, bit make and type, records of samples and cores, drilling cuttings, geological conditions and formations, comments and driller observations, areas where hole has had issues or complications, mud loss zones, areas where influx was encountered, proximity to lease lines, boundaries, or trouble zones, and future plans for the drilling of the well.

[0160] Daily videos are important not only for real-time decision-making but also for creating a historical record that may be used for analysis, regulatory compliance, audits, and future reference in case of any issues that may arise with the well.

[0161] In the fast paced, complex, and ever-changing world of drilling, completions, & production in the oil and gas industry, the teams (techs, superintendents (field and actual), remote operations center (ROC) employees and managers, operators, engineers, managers, VP’s, SVP’s, CEO’s, other executives, and any other stakeholders, all need to get updates and reports to understand what is happening in the drilling operations for a well.

[0162] Currently, gathering this information often requires obtaining and reading reports from multiple sources, and talking to multiple vendors / groups to get full context on the currentstate of the well and drilling operations and what has happened over some preceding time interval. This often happens multiple times a day (for at least some stakeholders), typically starting with a video first thing in the morning about drilling operations during the preceding 8-12 hours (e.g., during the prior evening and night shift and into the early morning hours).

[0163] Multiple vendors providing various services for drilling the well may send in their reports to be read first thing in the morning (and other specified times during the day and night) by the different leaderships of the companies involved in drilling the wells with data or information related to various drilling parameters. However, in order to understand the context of the reports, those involved generally need to call vendors or onsite drilling representatives (company men, drilling site managers, etc) or others to get contextual data on why things have happened the way they did. Often, the drilling site representatives or other staff in the office consolidate the information to create a single report from the multiple reports, but still require conversations about context to create the picture of the events that have unfolded. Additionally, stakeholders often ask what the plan is going forward for drilling operations for the rest of the day, including any significant upcoming events and how they will be handled, if logistical calls have been made to ensure equipment is at the site, teams are on standby, material is on the way or delivered, regulatory authorities have been alerted, landowners have been notified, etc.

[0164] This requires a great deal of time, conversations, and each stakeholder involved typically has to seek out information to gather the data necessary to complete understand the current state of the well and drilling operations, and what the future drilling operations and events will be.

[0165] In various embodiments, the planned activity may include a summary of geological changes for the future predetermined time period. During a drilling operation, geological changes refer to the alterations and variations encountered in the subsurface geological formations as the drill bit penetrates deeper into the Earth. These changes may have significant implications for drilling operations, wellbore stability, drilling efficiency, and the overall success of the drilling project.

[0166] Some common geological changes that may occur during a drilling operation may include formation changes, stratigraphic changes, faults and fractures, changes in pressure andfluids, geothermal gradients, unconsolidated or depleted formations, drilling through fault zones, Karst features, pressure and stress changes, and mineralization and gas zones.

[0167] At a high level, the system 1100 may receive various pieces of information regarding drilling operations and / or events during a given time interval, combine and synthesize it, and provide the information to a computer system that includes a video generating engine. As such, the system 1100 may take the various pieces of pertinent information of what has happened related to a drilling operation and create a video for an end user showing, with context, what has happened during a predefined time period (e.g., a look back time period, a look forward time period, etc. Optionally, the system 1100 may provide a video with an analysis of the drilling operation during the predefined time period. In some embodiments, and as discussed in detail below, at least one aspect of the video may be controlled based on the desired and / or identified end user. Such aspects may include, but are not limited to, a duration of the video, a file type of the video, a type of transmission sending the video to the end user, an amount of information included in the video, a type of information included in the video, a reporting interval in which the video is provided to the end user, the look back time period, the look forward time period, combinations thereof, and / or as otherwise desired.

[0168] In various embodiments, the information received and / or obtained by the system 1100 may include a well plan, sensor information, information from other systems, input from a user, combinations thereof, and / or as otherwise desired. As non-limiting examples, he system 1100 may connect via application programming interface (API) to other client applications to gather the necessary data to create the video, like an electronic drilling recorder (EDR), geosteering software (e.g., Starsteer), customer well data recording (e.g. WellView), well planning software (e.g. Compass), enterprise resource planning (ERP), optical character recognition (OCR) to text applications, etc. Additionally, or alternatively, the system 1100 may obtain information from various sensors at a drilling location, such as but not limited to downhole sensors, sensors on a rig, sensors at other locations, combinations thereof, and / or as otherwise desired. As yet another non-limiting example, the system 1 100 may receive input from a user, such as but not limited to an annotation or indication from a drilling engineer viaa human machine interface. Additionally, or alternatively, the information received and / or obtained may be information the drilling operations, the well plan, one or more offset wells, one or more synthetic wells, combinations thereof, and / or otherwise desired. Other combinations and / or sub-combinations of input information may be utilized as desired.

[0169] Based on the information obtained and / or received by the system 1100, the system 1100 generates a video of the drilling operations during a predefined time period, which may be a look back time period and / or a look forward time period. The look back time period and / or the look forward time period may be customizable and / or controlled by the system 1 100 as desired. As non-limiting examples, the system 1100 may be generate a video on some last amount of hours, on some last amount of days, on some future amount of hours, on some future amount of days, for the entire well, on the completion of one or more drilling operations, on well production time, combinations thereof, and / or as otherwise desired.

[0170] In certain embodiments, the look back time period and / or the look forward time period may be controlled by the system 1100 based on parameters such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the system 1100 may provide a field superintendent a video showing granular drilling activities on an hourly basis but may provide a drilling manager a video with a daily (e.g., 24 hour) look back with a high level overview of a fleet of wells and / or completions and / or drilling operations. Additionally, or alternatively, the system 1100 may produce a video based on sensor data and / or other input into the system indicating a completion of a particular drilling operation, a potential safety and / or hazardous condition, a completion of the end of well, combinations thereof, and / or as otherwise desired. The videos may include information related to a single well and / or the entire pad (e.g., multiple wells and / or completions of wells) as desired. Other combinations or sub-combinations may be utilized as desired.

[0171] Optionally, in embodiments where the input information includes a plurality of wells and / or a plurality of pads, the system 1100 may generate a video analyzing the two (or more) wells and / or pads, optionally explaining similarities and / or differences between the two(or more) wells and / or pads. Additionally, or alternatively, the system 1100 may generate the video with various analysis such as but not limited to a comparison of the drilling operations with the well plan and / or relevant portions of the well plan offset wells, or synthetic wells, or relevant portions of these offset or synthetic wells. Optionally, the system 1100 may be configurable to compare two separate wells, more than two wells, two or more pads and produce the video output to explain how the two or more wells, two pads, etc. were similar and where there were differences.

[0172] The system 1 100 may then deliver the video to each intended recipient by one or more communication channels. Communication channels may include, but are not limited to, email, text, WhatsApp (or equivalent), TikTok, Instagram, Facebook, Snapchat, or on a mobile application with a notification system to deliver that video at the specified time each day (or multiple times per day), combinations thereof, and / or as otherwise desired. In some embodiments, the system 1100 may generate the video in various file formats and / or may provide the video to one or more end users in various formats as desired.

[0173] In some embodiments, the system 1100 may generate the video in a particular file format and / or may provide the video to an end user using a particular format based on various input information, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As non-limiting examples, the system 1100 may send the video via formats such as but not limited to email, text, WhatsApp (or equivalent), TikTok, Instagram, Facebook, Snapchat, on a mobile application notification system, combinations thereof, and / or as otherwise desired. As a non-limiting example, the system 1100 may send the video via a secured (e.g., encrypted or otherwise) email to an outside vendor, a mobile application notification to a vice president, and a text or WhatsApp (or equivalent) to a field engineer. As further non-limiting examples, videos may be sent by the system 1100 using a link to an online video hosting service and / or the system 1100 may upload the video to a mobile application to watch in the system and / or the system may generate the video at a field site location on premises for the company man / driller to watch. Optionally, the system 1100 may generate thevideo which would be able to play the short clip on the notification on the persons cell phone. Other combinations or sub-combinations may be utilized as desired. Optionally, the system 1100 may generate multiple versions of the video, such as by generating copies in different video formats. Additionally, or alternatively, the system 1100 may generate links and may deliver links to the recipients in addition to or in lieu of copies of the videos.

[0174] Optionally, the system 1100 may send the video directly and / or may deliver the video by sending a link to the video file. As a non-limiting example, the system 1100 may deliver a link to the file as available on an online video hosting service (e.g., YouTube, TikTok, Instagram, FaceBook, Twitter, or other mobile application and the like). In addition, or alternatively, the video may be uploaded to a server which is accessible by a user via an application running on a cell phone, tablet, smart watch, laptop, and / or other device.

[0175] In some embodiments, the system may receive a first file size (e.g., 2 MB) for the video from the at least one user, and the system may send the video to the at least one user with the video having less than or equal to the first file size. In such embodiments, the system may automatically store the video having a second file size (e.g., 10 MB) larger than first file size in a storage system, and the system may automatically send a selectable link to access the video having the second file size to the at least one user. As a non-limiting example, the system may automatically send a low definition video (having a smaller file size) to an end user via text message, and the system may store a high definition video (having a larger file size) to a storage system, and the system may send a link to the high definition video to the end user via email (or otherwise).

[0176] In various embodiments, the system may receive a first file type (e.g., MP4) for the video from the at least one user and the system may send the video to the at least one user with the video the first file type. In such embodiments, the system may automatically store the video having a second file type (e.g., WMV) different from the first file type in a storage system, and the system may send a selectable link to access the video having the second file type to the at least one user.

[0177] It should be appreciated that the videos may be available in multiple file formats that may be viewed by multiple stakeholders in multiple locations via viewing on multiple devices and platforms.

[0178] Components of the system 1100, such as but not limited to the video generating software, the 3D rendering software, and the software used for delivering the video files or links thereto, may be provided as dedicated systems. In other embodiments, the system 1100 and / or sub-components thereof may be incorporated into another system of the drilling system, such as but not limited to a surface steerable system like that described above, one or more drilling rig control systems like those described above, or may be a stand-alone system and connected to any one or more of the foregoing.

[0179] The videos system disclosed herein may use Large Language Models (such as but not limited to ChatGPT) or other artificial intelligence and / or machine learning systems. As a non-limiting example, the videos system may include one or more Al systems designed to receive the drilling operations information, the well plan, and existing information from systems and reports, and consolidate that information and use it to generate a new report. The Al system may be used to accept additional requests or feedback from stakeholders and use that information to generate future videos that include information like that requested for that stakeholder.

[0180] In some embodiments, an Al system (and / or the system 1100) may be used to refine the content and display of information in videos for a particular well or group of wells or owner / operator by receiving requests from the stakeholders regarding such reports over time. As a non-limiting example, the Al system may decide to add certain information (e.g., gamma ray logs) and delete other information (e.g., mud logs) from the videos based on the feedback received from the relevant stakeholders. Similarly, feedback from stakeholders regarding the types of displays that are preferred or less desired (e.g., MD versus TVD, or the length of the segments of the log displays provided) may be used by the Al system to modify and adapt the displays and / or information included in the videos provided to one or more stakeholders. The system may use the Al component to provide particularized videos for each stakeholder based on that stakeholder’s feedback, save their preferences and deliver those on a go forward basisor it may be that the system provides a standard video for all users associated with a particular well or particular company but modifies the content of the videos based on feedback received from one or more users associated with that well or company.

[0181] In various embodiments, the system 1100 may utilize large language models (such as but not limited to ChatGPT) or other AI / ML tools to be interactive. As a non-limiting example, the system 1100 may receive an input question from a user and then output a short video clip and / or modification of the video with answers to the questions, such as by providing additional information, showing backup information, or providing a more detailed explanation. A non-limiting example example would be the drilling engineer could ask “how does this current H2-MB14 well intermediate section and curve compared to the last three MB 14 wells we drilled, include trajectories, bit and BHA’s, hours on each of those during that time, geological formations and faults, mud type and mud additives added at this stage, mud properties?” The large language models may take that input, output the correct language response, and then the reporting tool would generate a video including the audio narration of the answer, together with the 3D representation of the well, with the display of the current well provided with displays of the earlier three reference wells so that the video visually shows the similarities and differences of the current well and the three earlier reference wells that were the subject of the question. The engineer could then refine the request after reviewing the generated video and say “now take wells MB 14 and X well and also compare the dip angles on each well as well as direction the wells were drilled”. The large language model would then provide a response, which the video engine may use to provide an updated video with updated text and / or audio narration including the response to the second input query. Various other interactions may be realized as desired.

[0182] In various embodiments, the system 1100 may be customizable and / or otherwise configured to provide the video to the end user at various reporting intervals, which may be regular or irregular, as desired. In some embodiments, the video interval optionally may be based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / oras otherwise desired. As non-limiting examples, the system 1100 may be configured to provide a video to a drilling manager or a vice president at a daily interval, a video to a drilling engineer every 6 hours, and a video to a field superintendent every hour. Optionally, the system 1100 may be customized to report on the last predetermined number of hours, predetermined number of days, or for the entire well, completion operation, or well production over a period time. Other combinations or sub-combinations may be utilized as desired.

[0183] Additionally, or alternatively, the system 1100 may produce a video that would also be able to report out the end of well (reviewing the entire well) and / or a video of the entire pad (multiple wells or completions). Optionally, the videos may be a short duration, although in other embodiments a video with more information may be longer than a video that provides less information (e.g., a video on the entire well drilled in ten days will likely be longer than a video on a time interval from 6 p.m. to 6 a.m.).

[0184] Additionally, or alternatively, the system 1100 may control the amount of information and / or the type of information and / or a duration of the video based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired. As a non-limiting example, the system 1100 may provide a video to a field superintendent with more information about the granular drilling activities, while a drilling manager may be provided with a high level overview, optionally omitting granular drilling activity information. As another non-limiting example, the system 1100 may generate a video for an employee of the drilling operator with a certain amount and / or type of information and may generate another video for a contractor with a filtered amount and / or type of information (e.g., such as to optionally omit operator-sensitive information). As further non-limiting examples, a drilling engineer may be provided with a video of a shorter duration (e.g., less than 30 seconds) while a drilling manager may be provided with a video of a longer duration (e.g., less than 2-3 minutes). Other combinations or sub-combinations may be utilized as desired.

[0185] Optionally, the system 1100 may generate the video with a prediction of a future drilling operation, parameter, and / or event. As non-limiting examples, based on the well planand / or other input information, the system 1100 may generate a video of predicted drilling operations, parameters, and / or events in the look forward time period (e.g., a “forward plan”), such as a predicted geological condition, potential issues based on past drilling performance and / or geological conditions, a predicted slide, a predicted rotation, combinations thereof, and / or as otherwise desired. In certain embodiments, the prediction of the future drilling operation is the forward plan for the well over a certain look forward time period. Optionally, generating the video with the predicted future drilling operations, parameters, and / or events may include identifying how many times over some last amount of wells a forward plan has hit a desired target time, and the video with the forward plan may assign a probability that the forward plan will occur in the target time period.

[0186] Optionally, the system 1100 may generate a video in 3D, optionally allowing manipulation by a user. Optionally, the video generated may allow manipulation up to 360 degrees (e.g., modifying such that the video is depicting the well looking at the well from below, from above, from behind, from in front, from either side, and from any other angle). As a non-limiting example, the system 1100 may generate a 3D video showing drilling progression in the look back time period or the look forward time period. In such embodiments, the 3D video may, for example, have a first type of view of the (e.g., a side view) of the drilling progression of the well, and a user optionally may manipulate the view to another view (e.g., a top view, a zoomed in view, a perspective view, etc.), and the system 1100 may continue the video and / or rewind the video with the modified view. In various embodiments, pertinent information may be embedded in the video.

[0187] As a non-limiting example, the system 1100 may include a 3D rendering and visualization program (e.g., 3DViz) to provide to the end user a video showing the work done in 3D, optionally with a summary of the pertinent information embedded in the video. 3D rendering and visualization displays may be a powerful tool for depicting drilling data in a visually informative and engaging way. In some embodiments, the system 1100 may include a 3D rendering and visualization engine, which may receive the relevant data from the well plan, offsetting wells, and / or synthetic wells and the preceding drilling operations to be covered by the video, then generate a 3D video display. As a non-limiting example, the 3Dvideo may show the progress of the wellbore and / or its trajectory during the drilling operations during the covered time interval. Optionally, the 3D video may also show the wellbore trajectory’s progress as compared to that of the well plan, offsetting wells, and / or synthetic wells for that time period. Optionally, the 3D video may display one or more geological formations and / or conditions relative to the wellbore’s trajectory. Optionally, the well plan does not include geological information, the 3D rendering and visualization engine may be provided with such information and then use it to generate the 3D display for the video.

[0188] The 3D rendering and visualization routine may receive and gather relevant drilling data. As non-limiting examples, drilling data may include parameters such as but not limited to drill bit position, depth, speed, torque, pressure, weight on bit, rate of penetrations, geological formations, bit type and characteristics, BHA type and characteristics, location of drill pipe and heavyweight drill pipe and collars, depth of cut planned versus actual on the bits run, and more. Additionally, or alternatively, the 3D engine may receive logging information, such as but not limited to, gamma ray logs, resistivity logs, mud logs, and other logs, which may be included in the 3D. Additionally, or alternatively, one or more of the logs displayed may be modified, such as by converting a log from a measured depth format to a true vertical depth format. Moreover, portions of one or more of the logs may be displayed against portions of one or more logs from one or more reference wells previously drilled that are included in the well plan. Additionally, or alternatively, portions of one or more logs may be displayed and may be manipulated to show the correlation of a well log obtained during drilling with a corresponding portion of one or more reference or offset well logs or a synthetic well log. Optionally, 3D rendering and visualization routine may ensure the data is accurate, complete, and properly formatted for visualization to be able to visualize all the different pieces at once.

[0189] Optionally, the 3D rendering and visualization routine may import the drilling data into the video generator 1102. The video generator 1102 may be a computing device that includes one or more processors, a memory, one or more displays, and various network interfaces. This may involve importing data from spreadsheets, databases, or other sources.

[0190] The 3D rendering and visualization routine may set up the 3D environment where the drilling data will be visualized. As non-limiting examples, the 3D environment may includea virtual representation of the drilling site, a cross-section of the geological formations, combinations thereof, and / or as otherwise desired.

[0191] In some embodiments, the 3D rendering and visualization computer system may use the drilling data to generate and display a virtual representation of the drill string, the bottom hole assembly and / or drill bit in the 3D environment. The 3D rendering and visualization software may depict the drilling path based on the recorded positions of the bottom hole assembly during drilling of the wellbore (e.g., by using the MWD data) and / or as otherwise desired.

[0192] In some embodiments, the 3D rendering and visualization routine may animate the display of the drilling process to show the progression of the drill string, BHA, and / or drill bit through various depths and formations as the wellbore is being drilled, and / or as otherwise desired. Optionally, the 3D rendering and visualization software may generate visual displays of drilling parameters. As non-limiting examples, drilling parameters may include but are not limited to depth (measured and / or TVD), speed, torque, WOB, depth of cut, ROP, and differential pressure, combinations thereof, and / or as otherwise desired, using animations, graphs, color-coded indicators, and / or as otherwise desired.

[0193] In certain embodiments, the 3D rendering and visualization software may incorporate 3D models or representations of geological formations to give context to the drilling process. The 3D rendering and visualization software optionally may highlight different layers and formations as the drilling progresses.

[0194] The 3D rendering and visualization software optionally may provide various interactive elements that allow users to pause, rewind, or fast-forward the drilling animation.

[0195] Optionally, the 3D rendering and visualization routine may provide tooltips or pop- ups with additional information about specific points in the drilling process.

[0196] In some embodiments, the 3D rendering and visualization routine may allow a user to manipulate the 3D video and / or control one or more characteristics of the 3D video. As nonlimiting examples, the user may interact with the 3D video by changing a view angle, changing a zoom setting of the view, playing the 3D video forward or reverse, add or removeannotations, labels, callouts, etc. to highlight important events, changes in parameters, and / or challenges faced during drilling, combinations thereof, and / or interactions or controls of other characteristics of the 3D view as desired. In some non-limiting examples, the 3D video may be manipulated by the end user, optionally while the 3D video is playing, paused, and / or as otherwise desired. User manipulation and / or interaction with the 3D video may achieved via various techniques as desired. As non-limiting examples, the video may include a set of prepopulated challenges / events (such as may be provided in a drop-down menu or pop-up window or otherwise desired), and the user may interact (e.g., touch, click, etc.) with the associated icon or item to annotate that part or section of the well to document the event. In other nonlimiting examples, the video may change or manipulate some characteristic responsive to a voice command from a user and / or other user input, optionally received via a human machine interface. Optionally, the 3D rendering and visualization routine may call on these annotations and / or other changes in 3D video characteristics, optionally alerting the users of upcoming potential issues either while tripping in our out, or on the next well geographically close enough that the new well is deemed to potentially have similar issues or events, and / or as otherwise desired.

[0197] In certain embodiments, the 3D rendering and visualization software may use data visualization techniques such as but not limited to color mapping, heatmaps, and / or graphs to represent quantitative data such as but not limited to pressure, temperature, and / or depth and / or other data as desired.

[0198] Optionally, the 3D rendering and visualization software may set up a live visualization that updates as new data is received.

[0199] In some embodiments, after the 3D visualization for the video has been generated, the software optionally may export it in one or more suitable file formats for delivery and sharing with colleagues, clients, or other stakeholders.

[0200] Optionally, the 3D video generated by the system 1100 may be further manipulated by a user, such as but not limited to an end user. Optionally, the video generated may allow manipulation up to 360 degrees (e.g., modifying such that the video is depicting the well looking at the well from below, from above, from behind, from in front, from either side, andfrom any other angle). As a non-limiting example, the 3D video may, for example, have a first type of view of the (e.g., a side view) of the drilling progression of the well, and a user optionally may manipulate the view to another view (e.g., a top view, a zoomed in view, a perspective view, etc.), and the system 1100 may continue the video and / or rewind the video with the modified view.

[0201] Optionally, the videos generated by the system 1100 may be utilized to improve communication between various personnel, and the videos may be interactive and / or otherwise be modified based on supplemental user input. As a non-limiting example, the system 1 100 may generate a video having a look back time period, and a field superintendent may add an annotation and / or otherwise provide input modifying the video (e.g., to further explain and / or provide context to information in the video, to highlight certain information in the video, etc ). In such embodiments, the system may provide the modified video to another end user (e.g., a drilling manager, vice president, another field superintendent, etc.). As another non-limiting example, the system 1100 may generate a video having a look back time period, and responsive to a user question, output segments of the video and / or modify the video itself to answer the question. As a non-limiting example, a drilling engineer may ask “how does this current H2- MB14 well intermediate section and curve compare to the last three MB 14 wells we drilled,” and the system 1100 may take the input, output a correct language response, and trigger the video to show a 3D representation of the well to be consolidated into the three separate wells showing similarities and differences. Other user input and / or interaction with the video may be utilized as desired, and the system 1100 may provide various other modifications to the video and / or interaction with the user as desired.

[0202] Additionally, or alternatively, to providing videos to various end users and / or interacting with various end users, the system 1100 may utilize the videos for various other control responses. As a non-limiting example, the system 1100 may utilize the video and / or the information in the video to automatically update the well plan. As another non-limiting example, the system 1100 may utilize the video and / or the information in the video to control one or more pieces of drilling equipment, drilling systems, and / or drilling operations.

[0203] In another non-limiting example, the system 1 100 may be coupled to another control system of the drilling rig (such as but not limited to the steering control system). The system 1100 may detect or identify an event or condition, and based on the identification or detection that the event or condition has occurred, may generate an alert. In smoe embodiments, the system 1100 may both generate videos and automatically detect that an event and / or condition has occurred. Optionally, the system 1100 may further provide a response to such detected event and / or condition, such as by identifying a corrective action and / or alerting the user by modifying the video to include visual and / or audio cues, sending an audio alert, providing other alerts to the user, controlling equipment, updating the well plan, combinations thereof, and / or as otherwise desired.

[0204] As a non-limiting example, the system 1100 may detect the well is off course based on the obtained information and relative to the well plan. In such embodiments, the system 1100, based on the sensor information, may identify that the well is off course, may automatically generate the video showing the well is off course, may determine a corrective trajectory, and / or may automatically show the corrective trajectory as a future activity in the video.

[0205] As a further non-limiting example, the system 1100, based on the received and / or obtained information, may identify that something in the drilling operation is wrong and / or some operation needs to be performed, the system 1100 may automatically adjust one or more drilling parameters for a future operation (e.g., by updating the well plan), and / or the system 1100 may automatically generate the video with the adjusted drilling parameter, optionally with the identification of what caused the parameter to be updated.

[0206] Other control responses may be implemented by the system 1100 as desired.

[0207] The videos generated by the system 1100 may include various content and / or information as desired based on the obtained and / or received information.

[0208] As a non-limiting example, the video may include well identification information, such as but not limited to a well name and / or number, a location (e.g., latitude and longitude) of the well, a name of a well operator of the well, drilling rig information, other uniqueidentifiers for the well and / or the rig and / or equipment, as well as any other information of interest, combinations thereof, and / or as otherwise desired.

[0209] Optionally, the videos generated by the system 1100 may be dated and / or otherwise provided with an identification. Optionally, each video is dated, indicating the activities and / or developments for a particular predetermined time period (e.g., a day, a week, an hour, several hours, etc.). As a non-limiting example, a video may be provided with a time stamp, such as the time created or the time through which it covers. Videos generated by the system 1100 may be provided at any interval as desired, such as but not limited to daily, more than once a day, and / or may be less than once a day (e.g., every other day).

[0210] Optionally, the video generated by the system 1100 may include information related to environmental information, such as but not limited to weather conditions at the wellsite, including temperature, wind speed, atmospheric pressure, and any adverse weather events that might impact drilling operations, such as rainstorms, snowstorms, blizzards, ice storms, sandstorms, excessive heat, tornadoes, and the like, combinations thereof, and / or other environmental information as desired.

[0211] Optionally, the video generated by the system 1100 may include safety information. As non-limiting examples, safety information may include but is not limited to information about safety measures taken during the predetermined time period, safety meetings conducted during the predetermined time period, incidents (if any) during the predetermined time period, any near-miss situations during the predetermined time period, compliance with safety regulations and protocols, combinations thereof, and / or as otherwise desired.

[0212] Optionally, the video generated by the system may include a roll up of work completed, oil / water produced, wells completed, proppant, water, and chemicals pumped, combinations thereof, and / or as otherwise desired

[0213] Optionally, the video generated by the system 1100 may include personnel information. Such personnel information in the video may include, but is not limited to, a list of personnel involved in the drilling operations for a predefined time period, a role of one or more persons, a responsibility of one or more persons, a location of one or more persons, astatus of one or more persons, combinations thereof, and / or as otherwise desired. As nonlimiting examples, personnel information may include role information such as but not limited to drilling engineers, on site oil and gas company representatives, rig hands, safety personnel, and / or third-party contractors, combinations thereof, and / or as otherwise desired.

[0214] In certain embodiments, the video generated by the system 1100 may include detailed drilling information of the drilling progress, drilling operations, drilling parameters, etc. made during a look back time period and / or a prediction of future drilling progress, drilling operations, drilling parameters, etc. in a look forward time period. Drilling information in the video may include, but is not limited to, data about the drilled depth, a wellbore diameter, a drilling rate (rate of penetration), details about the formations encountered, challenges faced during drilling, such as equipment issues, geological anomalies, or drilling fluid problems, combinations thereof, and / or other drilling information as desired.

[0215] In some embodiments, the drilling information may include information about one or more drilling parameters used or predicted to be used during the predetermined time period. Drilling parameters may include, but are not limited to, details about the bit that was used, the BHA used, weight on bit (WOB), rotary speed, depth of cut on the drill bit cutters (actual versus planned), drilling fluid properties (mud weight, viscosity), differential pressure, rate of penetration, mechanical specific energy, slide drilling operations, rotary drilling operations, curvature, and / or any adjustments made to optimize drilling efficiency and wellbore stability, combinations thereof, and / or as otherwise desired.

[0216] In some embodiments, the drilling information in the video may include information about the type of drilling fluid (mud) used, its properties, volume circulated, additives added, and any changes made to the mud system.

[0217] In certain embodiments, the drilling information in the video may include a summary of equipment used and / or any maintenance and / or repairs carried out during the predetermined time period. Such equipment included in this drilling information may include the drilling ng, bottom hole assembly, drill bits, drill string components, sub-components thereof, and / or auxiliary equipment as desired.

[0218] Optionally, the drilling information in the video may include special drilling operations. As a non-limiting example, if any special drilling operations were conducted during the predetermined time period, such as running casing, cementing, coring, and / or well logging, this information may be included in the video.

[0219] Optionally, the drilling information in the video may include geological information. As non-limiting examples, if rock samples or cores were extracted from the wellbore for geological analysis, information about their depths and descriptions may be provided in the video.

[0220] Optionally, the video generated by the system 1100 may include input from one or more users. As non-limiting examples, the video may include observations and / or comments from one or more users (provided, for example, via a human machine interface) about the drilling progress over the predetermined time period, challenges, successes, and / or any noteworthy occurrences may be included. In some embodiments, such information may provide helpful context to the raw data presented in the video.

[0221] Optionally, the video generated by the system 1100 may include predicted future events, operations, and / or parameters, and / or plans for drilling activities in a look forward time period. As non-limiting examples, such information may include anticipated drilling objectives, goals, and / or potential challenges.

[0222] In certain embodiments, the video generated by the system 1100 may include information from the well plan. Optionally, the video generated by the system 1100 may include, the well plan, a comparison of actual drilling information to the corresponding information in the well plan, information from other offset wells that have similar characteristics, information from synthetic wells created as an amalgam of as drilled information from other wells to create a best composite well or technical limit well, combinations thereof, and / or as otherwise desired. As a non-limiting example, the prior day’s rate of penetration might be compared against the rate of penetration of the well plan, the rate of penetration of offset wells, and / or the rate of penetration synthetic wells, combinations thereof, and / or as otherwise desired. As another example, the curvature to be added to the wellaccording to the well plan, offset wells, or synthetic wells, may be compared against the curvature actually drilled.

[0223] The system 1100 may be customizable to be able to deliver the pertinent information through the video to the appropriate internal and external customer levels and personas. Non-limiting examples are provided below for illustrative purposes, but other videos and / or controls may be realized with the system 1100 as desired: a. Example 1 : The system 1100 may obtain well plan and / or drilling information, and generate a video for a drilling engineer. The drilling engineer may want to get four videos day, two at 6 am, with one showing the last twelve hours of drilling operations and the second covering the planned next 12 hours of drilling operations, and two at 5 pm, with one showing the last 12 hours and the second showing the projected 12 hours of drilling. b. Example 2: The system 1100 may obtain well plan and / or drilling information, and generate a video for a drilling manager or a VP. The drilling manager and or VP may receive one video each day from the system 1100 with a high level overview of their entire fleet of wells and completions operations. This video may provide a highlight of all the rigs / fracking spreads and progress for each well. They may also get a video each Monday showing the last week’s total amount of work completed (footage, costs, incidents, etc.) They could also specify to only get one aspect of the operation one time or cadence, while receiving other reports on other aspects at multiple times per day or week. They could specify to only see drilling in one area at a certain cadence per day / week / month, completions in another area at a certain cadence per day / week / month, and production volumes, temperatures, and the like for another area at still different intervals. c. Example 3: The system 1100 may obtain well plan and / or drilling information, and generate a video for a field superintendent or remote operating center (ROC) employee. The field superintendent or ROC employee may receive a short video from the system 1100 with more granular activities on a predetermined hourlybasis to gain insights into multiple rigs / frac spreads work as they oversee the operations. They would leverage this for handover activities to be able to synthesize a video with context to explain what has transpired over a period of time 14, 21, 28, 30+ days per hitch) as well. This may help keep everyone informed about different events even if people are on days off.

[0224] In certain embodiments, personnel optionally may leverage these videos generated by the system 1100 to help with their handover activities each tour to give quick context to their counterpart relieving them and taking on their duties for the next x period of time. This may facilitate better understanding of the operations that have happened to give more continuity and information for a more complete handover to the next driller

[0225] The system 1100 optionally may allow the videos to be customizable to be able to deliver varying information through the varying videos to the appropriate internal and external customer personas. It will be appreciated that some stakeholders may want much more detailed information in a video than that of other stakeholders.

[0226] Optionally, the system may utilize the forward plan for the well, leveraging the well plan itself as well as the planner function, and output in a short video clip the plan ahead over the next predetermined number of hours, days or until the completion of the well, frac job, etc. Optionally, the system may report out how many times over the last predetermined number of wells the forward plan achieved the desired target time and assign a probability that will happen again in the upcoming drilling period. This will help inform the probability of the estimated time to target time being correct.

[0227] Optionally, the system 1100 may be used in the pre-tour meetings in the rigs / frac spreads to review what happened the night before as well as the operations that are going to happen that day. As non-limiting examples, the system 1100 may describe the geological changes, potential loss zones, comparisons of the same depth range from previous wells, and lessons learned from them, any pertinent Standard Operating Procedures that are coming up in the forward plan and potential issues to prompt the operations to look out for in the day ahead. There may be links to the safety related information about the upcoming jobs to facilitate a more interactive pre-tour meeting

[0228] FIG. 11 illustrates the system 1100 for generating videos or videos according to embodiments.

[0229] The system 1100 may include a control system (e.g., controller) 1111 with video generator 1102 including one or more processors and / or one or more memory devices. In some embodiments, the control system 1111 (and / or sub-components thereof) may be a dedicated computing device, while in other embodiments, the control system 1111 (and / or subcomponents thereof) may be provided as components of other systems of the drilling system. As a non-limiting example, the control system 1 1 1 1 may be implemented with the steering control system 168 as described above.

[0230] The video generator 1102 and / or the control system 1111 may be provided at various locations as desired. In various embodiments, the video generator 1102 may be located at the site of the drilling ng 1104. Additionally, or alternatively, the video generator 1102 may be located remote from the drilling rig 1104. As mentioned, the control system may include one or more processing devices and / or one or more memory devices. The memory devices may store instructions that, when executed by the one or more processors, perform operations. The operations may include, but are not limited to, receiving and / or accessing a well plan for drilling a well, receiving and / or accessing disparate databases with offsetting well data or synthetic well data (best composite well, tech limit well, etc.), receiving and / or obtaining sensor data, receiving and / or obtaining user input, generating one or more videos 1114, transmitting the one or more videos 1114, displaying and / or otherwise providing one or more videos to at least one end user, saving the one or more videos 1114, updating a well plan, controlling a drilling operation, controlling one or more drilling systems, controlling one or more pieces of drilling equipment, combinations thereof, and / or as otherwise desired.

[0231] In certain embodiments, the control system 1 111 and / or the video generator 1102 is communicatively coupled (directly or indirectly) to various other components, such as but not limited to one or more sensors 1106, 1108, one or more components or systems of a drilling rig 1104, data storage 1110, a user device 1112, and / or a well plan 1116. Various wired or wired communication techniques may be implemented such that the control system 1111 and / or the video generator 1102 may send and / or receive data to such other components.

[0232] In some embodiments, the video generator 1102 of the control system t i l l may be communicatively coupled with various systems, equipment, and / or components of the drilling rig 1104. As non-limiting examples, the control system 1111 and / or the video generator 1102 may be communicatively coupled with one or more of the drilling rig control systems described above, such as but not limited to the mud pump 152, WOB / differential pressure control system 522, the positional / rotary control system 524, the fluid circulation control system 526, the sensor system 528, the steering control system 168, autodriller 510, bit guidance 512, autoslide 514, drilling equipment 530, draw works / snub 532, top drive 140, mud pumping equipment 536, mud pump 152, and / or MWD / wireline equipment 538, combinations thereof, and / or as otherwise desired.

[0233] The sensors 1106, 1108 may be various sensors as desired configured to obtain various information related to a drilling operation. While the sensors 1106, 1108 are illustrated as downhole sensors 1106 and surface sensors 1108 in FIG. 11, such identifications are for illustrative purposes only, and the sensors 1106, 1108 may be other types and / or combinations of sensors as desired. Thus, while the below description may reference “downhole sensors 1106” and “surface sensors 1108,” the description should not be considered limiting.

[0234] In certain embodiments, the information from the downhole sensors 1106 and / or the surface sensors 1108 may be collected using either the control system 1111 and / or video generator 1102 remotely / indirectly or directly as desired. As a non-limiting example, a system of the drilling rig 1104, such as but not limited to the steering control system 168, may collect and provide sensor data to the control system 1111 and / or video generator 1102, and / or the video generator 1102 and / or the control system 1111 may be provided on or with the drilling rig 1 104. As mentioned, the data from the sensors may be transmitted via wired or wireless means to the video generator 1102. As non-limiting examples, data from surface sensors 1108 may be transmitted via wired or wireless communication, and the data from the downhole sensors may be telemetered to the surface and provided to the control system 1111 and / or video generator 1102. In various embodiments, the data from the sensors optionally may be stored in the data storage 1110.

[0235] Non-limiting examples of sensors 1106, 1108 are described in detail below. While the examples are discussed separately, the system 1100 may include any combination of sensors as desired.

[0236] In some embodiments, one or more downhole sensors 1106 may measure various information regarding the drilling operation. The downhole sensors 1106 may be provided at various locations as desired such as but not limited to in the BHA, and may include MWD sensors, LWD sensors, combinations thereof, and / or other sensors as desired. In various embodiments, downhole sensors 1 106 at a drilling rig may provide various types of real-time data and information about the drilling process, the formation being drilled, and the condition of the wellbore. These downhole sensors 1106 may help drilling operators make informed decisions to optimize drilling performance, ensure safety, and maximize well productivity.

[0237] In certain embodiments, downhole sensors 1106 may monitor and transmit information about various drilling parameters as desired. As non-limiting examples, drilling parameters monitored by the sensors 1106 may include, but are not limited to, toolface, weight on bit (WOB), rate of penetration (ROP), rotary speed, torque, mud flow rate, vibration, accelerations, other drilling dysfunctions, differential pressure, combinations thereof, and / or as otherwise desired. This data related to drilling parameters may facilitate optimization of drilling efficiency and prevent issues like bit wear or hole instability.

[0238] In some embodiments, downhole sensors 1106 may provide information about the properties of the geological formation being drilled. Non-limiting examples of geological properties may include, but are not limited to resistivity, porosity, permeability, fluid saturation, combinations thereof, and / or as otherwise desired. Geological data may aid in understanding the potential for hydrocarbon reservoirs and in determining the best drilling strategy.

[0239] In certain embodiments, downhole sensors 1 106 may be equipped with inclinometers and magnetometers. In such embodiments, the data from these sensors may provide data about the wellbore’s inclination, azimuth, and overall trajectory, among other components. This information may be used for directional drilling and well placement.

[0240] In various embodiments, downhole sensors 1106 may capture images or video of the wellbore as the drilling progresses and / or during other time intervals as desired. This visual data may help operators visualize the condition of the well and identify any issues such as borehole collapse or stuck pipe.

[0241] In various embodiments, downhole sensors 1106 may monitor temperature and pressure conditions in the wellbore. Temperature and pressure data may be used for assessing well integrity, evaluating fluid properties, and / or detecting any anomalies that might indicate wellbore stability problems, among other uses.

[0242] In some embodiments, downhole sensors 1106 may detect vibrations and acoustic signals produced during drilling. Vibration and / or acoustic signals may be utilized to help identify issues like bit bouncing, poor drilling mechanics, and / or potential formation instability, among other issues.

[0243] In various embodiments, downhole sensors 1106 may provide data on the quality of casing placement and / or cementing operations. Such sensor data may be analyzed for wellbore integrity, and / or preventing fluid migration between different formations.

[0244] In certain embodiments, downhole sensors 1106 may measure formation pressure while drilling. Such sensor data may help operators understand reservoir characteristics and evaluate drilling fluid properties.

[0245] In some embodiments, downhole sensors 1106 may detect the presence of gases, including hydrocarbons, and / or other elements or materials as desired while drilling. Such sensor data may be utilized to detect potential well kicks or gas influxes that could lead to well control issues.

[0246] Some downhole sensors 1106 include monitoring sensors. Non-limiting examples of monitoring sensors may provide information about wellbore stability and / or identify signs of borehole collapse or other stability issues.

[0247] In various embodiments, downhole sensors 1106 may assess the condition of the drilling bit in real-time, helping operators make decisions about when to change the bit to optimize drilling efficiency.

[0248] In certain embodiments, downhole sensors 1106 may provide data about drilling mud properties such as density, viscosity, and / or rheology. This information may be used for maintaining proper wellbore conditions and / or preventing fluid-related issues.

[0249] In some embodiments, the drilling rig 1104 may include surface sensors 1108. Surface sensors 1108 in drilling operations may measure various parameters and / or conditions at the drilling rig itself. In certain embodiments, the surface sensors 1108 may provide real- time data to drilling operators, engineers, and / or other personnel on the surface, allowing them to monitor and control the drilling process, optimize performance, and ensure safety.

[0250] In certain embodiments, surface sensors 1108 may measure the hookload and / or the weight applied to the drill bit, often referred to as weight on bit (WOB). As non-limiting examples, such sensors may monitor tension in the drilling rig’s hoisting system. This helps operators control the drilling process and avoid excessive weight that could lead to bit wear or hole instability.

[0251] In various embodiments, surface sensors 1108 may monitor the rotational speed of the drill string and / or the drill bit. Controlling the rotational speed may help optimize drilling efficiency and bit performance.

[0252] In certain embodiments, surface sensors may be torque sensors, which may measure the amount of rotational force applied to the drill bit. Monitoring torque may help prevent bit damage and assess the drilling efficiency.

[0253] In some embodiments, surface sensors 1108 may measure the flow rate and / or pressure of drilling mud being pumped downhole. This information may be used for maintaining proper wellbore conditions, carrying cuttings to the surface, and preventing well control issues.

[0254] In various embodiments, surface sensors 1108 may monitor the pressure of the drilling mud as it is pumped into the wellbore. Abnormal pressure changes could indicate wellbore instability or other issues.

[0255] In certain embodiments, surface sensors 1108 may measure various properties of the drilling mud, such as but not limited to, density, viscosity, and / or rheology, combinationsthereof, and / or as otherwise desired. Maintaining appropriate mud properties may be used for effective drilling and wellbore stability.

[0256] In certain embodiments, surface sensors 1108 may include standpipe pressure sensors that measure the pressure in the pipe that carries drilling mud from the pumps to the wellhead. Changes in standpipe pressure may indicate changes in downhole conditions.

[0257] In various embodiments, surface sensors 1108 may monitor the flow rates of drilling mud and / or solids entering and exiting the wellbore. Discrepancies between the two rates may help detect potential well control problems, hole cleaning efficiency (or lack thereof), loss of drilling mud, and the like.

[0258] In some embodiments, surface sensors 1108 may monitor the rate at which drilling mud is circulated down the drill string and back up the annulus. Proper circulation may be used to removing cuttings and maintaining wellbore integrity.

[0259] In certain embodiments, surface sensors 1108 may detect the presence of gases, including hydrocarbons, and / or other components in the drilling mud. Gas detection may provide early warning of potential well kicks or gas influxes.

[0260] In certain embodiments, surface sensors 1108 may include vibration sensors, which may detect vibrations in the drill string and may help identify issues such as bit bouncing or poor drilling mechanics.

[0261] In some embodiments, surface sensors 1108 may measure the temperature of various components in the drilling system, including but not limited to the drilling mud. Temperature changes may indicate downhole conditions and / or equipment problems.

[0262] In various embodiments, surface sensors 1108 may track the position, trajectory, and / or depth of the drill bit in the wellbore. This information may be important for well placement and trajectory control.

[0263] In certain embodiments, surface sensors 1108 may monitor the movement and / or tilt of the drilling rig itself, helping ensure rig stability and safety.

[0264] Some surface sensors 1108 may measure the power consumption of different rig components. Such data may provide insights into equipment performance and efficiency.

[0265] Surface sensors 1108 may play a pivotal role in providing real-time data to drilling personnel, helping them make informed decisions to optimize drilling operations, ensure safety, and respond to changing downhole conditions.

[0266] As mentioned, various combinations of sensors and / or other sensors may be utilized as desired.

[0267] The data storage 1110 may be a cloud storage system, although other suitable data storage systems and / or devices may be utilized as desired, in place of and / or in addition to the cloud storage system. A cloud storage system as the data storage 1110 is a technology infrastructure that enables users and organizations to store, manage, and access data over the internet. Instead of relying on local storage devices like hard drives or physical servers, cloud storage leverages remote servers hosted by third-party providers. Cloud storage providers operate data centers with powerful servers that are designed to store vast amounts of data. These servers are geographically distributed to ensure redundancy and minimize the risk of data loss due to hardware failures or disasters. Cloud storage systems divide user data into smaller segments and distribute these segments across multiple servers or data centers. This distribution ensures better load balancing, improves access speeds, and enhances data availability. Cloud storage providers implement redundancy mechanisms to protect against data loss. This often involves creating multiple copies of data and storing them across different physical locations. Redundancy helps ensure data availability even in the event of hardware failures or disasters.

[0268] The electronic device 1112 may be various suitable devices for playing a video generated by the system 1100 (discussed in detail below). Optionally, the electronic device 1 1 12 may be utilized to provide user input to the system 1 100 and may include various types of human machine interfaces as desired.

[0269] Well plans 1116 may include a substantial amount of information for a well to be drilled and / or a well being drilled, including, but not limited to, logs for reference wells,geological information, the planned trajectory of the well, drilling parameters, drilling operations, operational parameters, and / or equipment information for drilling the well, combinations thereof, and / or as otherwise desired. In some embodiments, the operations performed by the control system 1111 may include receiving and / or obtaining one or more drilling parameters for the drilling operation from the well plan 1116.

[0270] In certain embodiments, the well plan 1116 may be a comprehensive document that outlines the detailed strategy, procedures, and / or steps required to drill a given well. It serves as a roadmap for the drilling operation, providing guidance to drilling personnel, engineers, and other stakeholders involved in the process. The content of a drilling plan may vary depending on factors such as the type of well-being drilled (oil, gas, geothermal, etc.), the geological conditions, regulatory requirements, and the specific goals of the drilling project.

[0271] In some embodiments, the well plan 1116 may outline the overall objectives of the drilling project. This includes, but is not limited to, defining the purpose of the well (exploration, production, injection, geothermal, etc.) and the expected outcomes.

[0272] In various embodiments, the well plan 1116 may include geological and / or geophysical data, including but not limited to information about the subsurface geology, formation depths, formation types, and / or expected characteristics, combinations thereof, and / or other information as desired. This data helps determine the drilling strategy and equipment needed.

[0273] In some embodiments, the well plan 1116 may describe the well design, including, but not limited to, wellbore trajectory (vertical, directional, horizontal), casing sizes, cementing program, and / or any deviation plans, combinations thereof, and / or other information as desired. The design ensures that the well is drilled safely and efficiently while meeting the intended objectives.

[0274] In certain embodiments, the well plan 1116 may specify components of the drilling ng 104, such as but not limited to the drilling rig type, capacity, and / or required equipment such as drill bits, drilling mud, drill collars, bottom hole assembly (BHA), and other tools necessary for the drilling process, combinations thereof, and / or other information as desired.

[0275] In various embodiments, the well plan 1116 may provide details on the drilling procedure. Such information optionally may include step-by-step procedures for drilling the well. Optionally, such information may cover the process of setting up the drilling rig, spudding the well (starting drilling operations), drilling the wellbore, tripping operations (removing and adding drill pipe), mud circulation, drilling fluid management, and / or well control procedures, among others.

[0276] In some embodiments, the well plan 1116 may outline the casing program, including, but not limited to, the number of casing strings, casing sizes, and / or depths at which casing will be set. It also may include details about the cementing operations to ensure proper casing integrity and zonal isolation.

[0277] In some embodiments, the well plan 1116 may include safety measures and / or emergency response procedures. Safety protocols, best practices, and / or emergency response procedures may address potential hazards, risk assessments, blowout prevention measures, well control procedures, and / or evacuation plans.

[0278] In various embodiments, the well plan 1116 may address environmental protection measures, waste management practices, and / or ways to minimize the impact of drilling operations on the surrounding ecosystem.

[0279] Depending on the location and jurisdiction, drilling plans 1116 may need to comply with local, state, and / or national regulations. In such embodiments, the well plan 1116 may outline the permits, licenses, and / or approvals required for the drilling project.

[0280] In certain embodiments, the well plan 1116 may describe the types of downhole sensors, surface sensors, and / or other sensors as desired that will be used to monitor drilling parameters, formation characteristics, and / or wellbore conditions, optionally in real-time.

[0281] In some embodiments, the well plan 1116 may include a timeline for different stages of the drilling process, optionally outlining the estimated duration for one or more operations.

[0282] In certain embodiments, the well plan 1116 may include contingency plans. Such plans may detail information such as but not limited to how the team will handle unexpectedchallenges, equipment failures, adverse weather conditions, and / or other potential issues that might arise during drilling.

[0283] In some embodiments, the well plan 1116 may include estimates of the monetary, resource, and / or labor costs associated with one or more aspects of the drilling operation.

[0284] In some embodiments, the well plan 1116 may outline communication protocols for various stakeholders, including but not limited drilling personnel, wellsite supervisors, management, regulatory agencies, and / or nearby communities, among others.

[0285] In use, the control system 1111 and / or the video generator 1102 may may receive and / or obtain the inputs from the drilling rig 1104, one or more sensors 1106, 1108, and / or the well plan 1116, and generates one or more videos 1114 (see, e.g., FIGS. 12-16).

[0286] The video 1114 may include various information related to the drilling operation based on the received and / or obtained information. In various embodiments, the video 1114 is automatically generated. As discussed in detail below, various aspects of the video 1114 may be controlled based on the received and / or obtained information and / or based on a determined and / or identified end user.

[0287] In some embodiments, the video generator 1102 generates the video 1114 with a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation. The graphic depiction may include an animated and / or video illustration of the drilling operation within a predetermined time period, such as within a look back time period and / or a look forward time period.

[0288] In various embodiments, the video generator 1102 generates the video 1114 with one or more metrics associated with the drilling operation as provided by the well plan and / or based on the sensor data.

[0289] In some embodiments, the video generator 1102 generates the video 1114 with a summary of a planned activity and / or a prediction for a future drilling operation, parameter, and / or event for a future predetermined time period. In various embodiments, the summary of the planned activity and / or predicted future drilling operation, parameter, and / or event in a future time period may include an animation, an audio narration, and / or text explaining theplanned activity and / or the predicted future. In some embodiments, video generator 1102 optionally may be configured to allocate a certain portion of the video 1114 to a preceding time period and a second portion of the video 1114 to the planned activities. As a non-limiting example, the video generator 1102 may generate the video 1114 such that no more than ten seconds of a thirty second video 1114 is spent on the planned drilling activities. The video generator 1102 optionally may allow a user to specify how much of the video 1114 should be allocated to the preceding drilling activity versus the amount of the video 1 114 allocated to the planned drilling activity. In various embodiments, the planned activity and / or predicted future drilling operation, parameter, and / or event of the video 1114 optionally may include a summary of geological changes for the future predetermined time period. Other information related to the drilling operation may be provided in the planned and / or predicted future drilling operation, parameter, and / or event of the video 1114 as desired.

[0290] In various embodiments, the video generator 1102 generates the video 1114 with one or more metrics, such as but not limited to, toolface, weight on bit (WOB), rate of penetration (ROP), rotary speed, torque, mud flow rate, depth of cut, mechanical specific energy, slide drilling operations, rotary drilling operations, curvature, vibration, accelerations, other drilling dysfunctions, differential pressure, performance metrics, a number of times that a forward plan achieved a desired target time over N number of previous drilling wells, combinations thereof, and / or as otherwise desired. As non-limiting examples, the well plan may specify performance metrics (e.g., stay above ROP, drill X fee overnight, toolface within x degrees of target, etc.), and, in the video, if there are performance metrics for the well, the video can include how drilling during the specified time period matches up with metrics. In some non-limiting examples, the system may automatically take information provided, and correlate to see whether it matches the performance metrics (staying on target, staying ROP, etc.).

[0291] In some embodiments, the video generator 1102 generates the video 1114 with an assigned probability that the forward plan will achieve the desired target time during a current drilling operation as determined by the control system 1111 and / or video generator 1102.

[0292] In certain embodiments, the video generator 1102 generates the video 1114 with projected challenges for a defined time period for the drilling operation based on the plurality of drilling parameters.

[0293] In various embodiments, the video generator 1102 generates the video 1114 which may include a 3D rendering of the drilling operation. Other graphical depictions may be utilized as desired, including 2D renderings, actual video footage (e.g., obtained from a sensor), combinations thereof, and / or as otherwise desired.

[0294] In some embodiments, the video generator 1102 generates the video 1114 via a plurality of application programming interfaces that connect to one or more drilling systems that perform the drilling operation (e.g., systems of the drilling rig 104 and / or a plurality of drilling rigs 104).

[0295] In some embodiments, the video generator 1102 generates the video 1114 with auditory and / or text narration.

[0296] In some embodiments, the video generator 1102 generates the video 1114 with links to drilling data. In certain embodiments, an end user may directly interface with the video 1114 (e.g., by clicking the link) to directly access the drilling data.

[0297] In some embodiments, the video generator 1102 generates the video 1114 with one or more tags, markings, annotations, and / or other features identifying information in the video.

[0298] The video generator 1102 may generate the 1114 with various durations. In various embodiments, the video generator 1102 generates the video 1114 with a video length less than 30 seconds in duration. In some embodiments, the video generator 1102 generates the video 1114 with a video length of the video is between 30 and 60 seconds in duration. In certain embodiments, the length of the video is greater than 60 seconds in duration. In some embodiments, the length of the video is in a range from 30 seconds to 3 minutes. In some embodiments, the system may receive a desired maximum video length from at least one user, and the system may automatically generate the video having a duration less than or equal to the maximum video length. Additionally, or alternatively, the system may determine a maximum video length based on the type of at least one user (e.g., position within the company,role on the drilling ng, 3rdparty vendor, etc.), and the system may automatically generate the video having a duration less than or equal to the maximum video length. In some embodiments where the system receives and / or determines the maximum video length, the system may prioritize and / or rank various input information received and / or obtained, and the system may generate the video based on the prioritization and / or ranking of the input information such that the video is less than or equal to the maximum video length.

[0299] In some embodiments, the video generator 1102 generates the video 1114 and stores the video 1 1 14 in a searchable database of prior videos.

[0300] In various embodiments, the video generator 1102 generates the video 1114 with on artificial intelligence generated inputs based on user searches and / or user inputs.

[0301] The video generator 1102 may provide one or more videos 1114 to one or more end users. In some embodiments, the video generator 1102 may generate a link to the video and transmitting the link to the video to the electronic device 1112 to the at least one user, and / or the video generator 1102 may send the video 1114 itself. In various embodiments, video generator 1102 may provide the video 1114 and / or a link to the video 1114 to the end user at a preset time. In various embodiments, the video generator 1102 may provide the video 1114 and / or a link to the video 114 within a preset time following the end of operations and / or at other trigger events or time intervals as desired. In various embodiments, the video and / or a link to the video may transmitted via at least one of an email message, a text message, and / or a chat message, among other communication techniques. In various embodiments, the video generator 1102 may store the video and / or a link to the video on a website for viewing after user login.

[0302] In various embodiments, the video generator 1102 may control one or more aspects of the video 1114 and / or the transmission and / or providing of the video 1114 to an end user based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired.

[0303] In one non-limiting example, the video generator 1102 may control a duration of the video 1114 based on the type of end user and / or input from the end user. As a non-limiting example, the video generator 1102 may generate a shorter video for a field engineer and a longer video for a VP. Optionally, the system 1100 may prioritize and / or rank information included in the video such that the video is less than or equal to a maximum video length determined for the end user and / or received by the end user.

[0304] In another non-limiting example, the video generator 1102 may control an amount of information and / or a type of information in the video 1 1 14 based on the type of end user. As a non-limiting example, the video generator 1102 may generate video with more granular information to field engineer and a video with a high level overview for a drilling manager. As another non-limiting example, the video generator 1102 may omit sensitive company information from a video for a contractor and may include such company information in a video to the drilling manager.

[0305] In another non-limiting example, the video generator 1102 may control a reporting interval at which the video 1114 is provided to the end user 1114 based on the type of end user. As a non-limiting example, the video generator 1102 may transmit the video 1114 to a drilling manager every four hours / multiple times a day and may transmit the video 1114 a first type of video on a daily basis and a second type of video on a weekly basis.

[0306] In yet another non-limiting example, the video generator 1102 may control a file format and / or a type of transmission for the video 1114 based on the end user. As a nonlimiting example, the video generator 1102 may send the video 1114 via a secured (e.g., encrypted or otherwise) email to an outside vendor, a mobile application notification to a vice president, and a text or WhatsApp (or equivalent) to a field engineer. As further non-limiting examples, the video generator 1102 may send the video 1114 by the system using a link to an online video hosting service and / or the system may upload the video to a mobile application to watch in the system and / or the system may generate the video at a field site location on premises for the company man / dnller to watch.

[0307] In addition to providing the video 1114 to one or more end users, the video generator 1102 may utilize the video 1114 to improve communication between various personnel, andthe videos 1114 may be interactive and / or otherwise be modified based on supplemental user input. As a non-limiting example, the video generator 1102 may generate a video 1114 having a look back time period, and a field superintendent may add an annotation and / or otherwise provide input modifying the video (e.g., to further explain and / or provide context to information in the video, to highlight certain information in the video, etc.). In such embodiments, the video generator 1102 may provide the modified video 1114 to another end user (e.g., a drilling manager, vice president, another field superintendent, etc.). As another non-limiting example, the video generator 1102 may generate a video 1114 having a look back time period, and responsive to a user question, output segments of the video 1114 and / or modify the video itself to answer the question. As a non-limiting example, a drilling engineer may ask “how does this current H2-MB14 well intermediate section and curve compare to the last three MB 14 wells we drilled,” and the system may take the input, output a correct language response, and trigger the video to show a 3D representation of the well to be consolidated into the three separate wells showing similarities and differences. In some embodiments, the system, in response to a user search or user request, generates a second video with modified information. In various embodiments, the system, in response to a user search or user request, generates a response to the user search or user request, which may or may not be a video. As non-limiting examples, the response to the user search or request may include one or more of a second video, a text response, and / or an audio response. Other user input and / or interaction with the video may be utilized as desired, and the video generator 1102 may provide various other modifications to the video and / or interaction with the user as desired.

[0308] Additionally, or alternatively, to providing videos to various end users and / or interacting with various end users, the video generator 1 102 may utilize the videos 1 1 14 for various other control responses. As a non-limiting example, the video generator 1102 may utilize the video 1114 and / or the information in the video 1114 to automatically update the well plan. As another non-limiting example, the video generator 1102 may utilize the video 1114 and / or the information in the video 1114 to control one or more pieces of drilling equipment, drilling systems, and / or drilling operations. Various other controls may be implemented as desired.

[0309] FIGS. 12-16 illustrate non-limiting examples of portions of a video 1114 generated by the video generator 1102. The features illustrated in FIGS. 12-16 are for illustrative purposes, and as mentioned, videos 1114 generated by the video generator 1114 may include various information as desired.

[0310] FIG. 12 illustrates a first exemplary screen capture 1200 of a video 1114. The video 1114 may illustrate or depict at least a portion of a drilling path 1216 for a borehole. In some embodiments, the depiction of the drilling path 1216 may be 2D as illustrated in FIG. 12. In other embodiments, the depiction may be a 3D depiction, and the video generator 1 102 may automatically change a view of the 3D depiction (e.g., to highlight an event, data, etc ), and / or an end user may change the view of the 3D depiction. As a non-limiting example, the video 1114 may initially present the depiction as a side view of the wellbore as illustrated in FIG. 12, and responsive to a user input (e.g., speech command and / or other interfacing and / or input as desired), the view of the video 1114 is changed to the perspective 3D view illustrated in FIG. 13. Other depictions may be generated by the video generator 1102 as desired.

[0311] As illustrated in FIG. 12, the screen capture 1200 illustrates how the video 1114 may depict a wellbore or drilling path 1216 for at least a portion of a borehole. The drilling path 1216 may include information such as but not limited to a current position of the bottom hole assembly, details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 and a north south coordinate 1212), a starting point 1214, the drilling path 1216 for the borehole, and / or an end of the borehole 1218, combinations thereof, and / or as otherwise desired.

[0312] Optionally, the video 1114 generated by the video generator 1102 may include an audio narration narrating various aspects of the video 1114. As non-limiting examples, the audio narration may identify the drill rig number and describe the drilling progress over the last number of preselected hours. Optionally, the narration may provide, among other things, the duration of the bottom hole assembly off bottom of the borehole, slide distance as a percentage of drill depth, average slide, and / or rate of penetration, as well provide other information of interest to the recipients of the video, combinations thereof, and / or other information as desired.

[0313] As shown in FIG. 12, in some embodiments, the video 1114 includes space available both above and below the depiction of the wellbore in the horizontal section to include additional information. Such additional information may be provided by the video generator 1102, provided by a user, and / or provided by an end user. Although not shown in FIG. 12, additional text could be displayed, additional animations could be displayed, a text display of the audio narration could be displayed, logs and log correlations could be displayed, additional geological formations could be displayed, cost information (e.g., costs of drilling to date, estimated costs to completion, cost curves, etc.) could be displayed, combinations thereof, and / or other information as desired could be generated and displayed in the video 1114 by the video generator 1102.

[0314] In some embodiments, because the video 1114 provides a video presentation, the additional information could be added and removed, then replaced with other information, changed, and / or modified (such as by showing a correlation of the well log from drilling the wellbore with a reference well log from the well plan), and so forth as desired.

[0315] Optionally, characteristics of the video 1114 may be modified by the end user and / or automatically. As non-limiting examples, the video 1114 may be modified by zooming in on the well and / or associated information regarding drilling operations, such as to show key events, potential problems or issues, conditions, or the like, changing a view of the video (e.g., from a side view of the depiction of the wellbore as shown in FIG. 12 to a perspective view such as illustrated in FIGS. 13-16). As noted below, the display shown in FIG. 12 could also include a video clip within the display, especially if the rig is equipped with one or more computer vision systems as described below.

[0316] FIG. 13 illustrates a second exemplary screen capture 1300 of the video 1114. FIG. 13 illustrates a different perspective of the drilling path 1216 from the first exemplary screen capture of the video shown in FIG. 12. The screen capture 1300 of the video 1114 illustrates that the depiction of the drilling path 1216 optionally may include the current position of the bottom hole assembly. The screen capture 1300 of the video 1114 illustrates that the video 1114 may provide details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 anda north south coordinate 1212. Optionally, screen capture 1300 of the video 1114 illustrates that the video 1114 may provide information regarding the author of the video and / or the drill site number. The screen capture 1300 of the video 1114 illustrates that the video 1114 may provide slide information and / or time off bottom, among other information.

[0317] The screen capture 1300 of the video 1114 illustrates that the video 1114 optionally may provide distances for various slides and / or characteristics of one or more slides, including but not limited to a slide quality of the slide.

[0318] In the context of a drilling operation, “slide quality” may refer to the effectiveness and efficiency of the process by which a drilling tool or bit is guided and controlled as it advances through the material being drilled. This is particularly relevant in directional drilling, where the goal is to deviate the wellbore from the vertical axis and navigate through specific underground formations or targets. A high slide quality means that the drilling tool smoothly transitions from one direction to another without sudden jerks or instability. This is crucial to avoid excessive wear on the drill bit, as well as to avoid sharp curves. Maintaining a smooth borehole by having high quality slide drilling operations helps minimize tortuosity of the wellbore, which in turn helps avoid other problems during the drilling process.

[0319] In directional drilling, maintaining control over the angle of inclination (how much the wellbore deviates from vertical) may be important. A good slide quality helps ensure that the desired angle is achieved and maintained without deviations that could lead to issues like wellbore collapse or drilling off-target.

[0320] Slide quality also refers to the ability to accurately predict and control the path of the wellbore. This involves using advanced software and measurement-while-drilling (MWD) tools to ensure that the wellbore follows the planned trajectory and reaches the intended target.

[0321] A “dogleg” refers to a sudden change in wellbore trajectory. High-quality slides help minimize the occurrence of doglegs, which may lead to equipment wear, reduced drilling efficiency, and even equipment failure.

[0322] Slide quality may also affect the rate at which the drilling tool penetrates the formation. Efficient slides contribute to a consistent ROP and overall faster drilling progress.

[0323] Poor slide quality may result in vibrations and shock loads being transmitted to the drilling equipment. These vibrations may be damaging and reduce the lifespan of drilling tools and equipment.

[0324] Improving slide quality often involves a combination of advanced drilling techniques, accurate data analysis, and the use of high-quality drilling equipment. Directional drilling engineers and operators work to optimize drilling parameters and techniques to achieve the best possible slide quality, ensuring efficient and accurate drilling operations while minimizing risks and costs.

[0325] Optionally, the video 1114 generated by the video generator 1102 may have a static and / or unchanging depiction of the drilling path 1216. In other embodiments, the video 1114 generated by the video generator 1102 may have a moving and / or changing depiction of the drilling path 1216. As non-limiting examples, the video 1114 may include a depiction which travels along the length of the borehole and drilling operations covered by the relevant time period for that report.

[0326] As mentioned, in some embodiments, the video 1114 may be automatically adjusted by the video generator 1102 and / or responsive to user input such that the view of the depiction changes. As a non-limiting examples, the video 1114 may be modified and transition from the view shown in FIG. 12 to that shown in FIGS. 13-16. Various techniques may be utilized to modify the video 1114. As non-limiting examples, the user may provide input rotating and zooming in to a particular portion of the wellbore depicted in the video 1114.

[0327] Optionally, the video generator 1102 may generate multiple views as may be desired within a single video 1114, and / or may generate a video 1114 which smoothly transitions between such multiple views.

[0328] Optionally, the video 1114 and / or the video generator 1102 may add additional information (e g., text, audio, etc.) to one or more of the views included in the video, such as shown by the combination of FIGS. 12-16, automatically (e.g., based on updated input information and / or a user input) and / or responsive to an end user input.

[0329] FIG. 14 illustrates a third exemplary screen capture 1400 of the video 1114. The screen capture 1400 of the video 1114 may provide details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 and a north south coordinate 1212. FIG. 14 illustrates a position of the bottom hole assembly 1402 in the video 1114. The video 1114 may provide distances for various slides including but not limited to the slide quality.

[0330] FIG. 15 illustrates another exemplary screen capture 1500 of the video 1114. FIG. 15 illustrates the presence of nearby wells (e.g., well one 1502, well two 1504, and well three 1506) and distance from the nearest drilling path 1216 in the video 1114. The audio narration of the video 1114 may provide various information, such as but not limited to the nearest distance from the nearby wells (e.g., well one 1502, well two 1504, and well three 1506) and any change in that minimum separation factor as the drilling progresses in the time period covered by that report. The screen capture 1500 of the video 1114 may provide details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 and a north south coordinate 1212).

[0331] FIG. 16 illustrates yet another exemplary screen capture 1600 of the video 1114. The screen capture 1600 of the video 1114 may provide details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 and a north south coordinate 1212. The narration may provide the nearest distance from the nearby wells (e.g., well one 1502, well two 1504, and well three 1506) and any change in that minimum separation factor. The screen capture 1600 of the video 1114 may provide details regarding the drilling operation (e.g., a measured depth 1202, a total vertical depth 1204, an inclination 1206, an azimuth 1208, and east / west coordinate 1210 and a north south coordinate 1212).

[0332] FIG. 17 is a flow chart of a process 1700 for generating one or more videos 1114, according to an example of the present disclosure. According to an example, one or more process blocks of FIG. 17 may be performed by video generator 1102 and / or control system 1111.

[0333] At block 1705, process 1700 may include accessing and / or receiving information from a well plan for a drilling operation. As a non-limiting example, video generator 1102 may access a well plan for a drilling operation, as described above. In various embodiments, the well plan optionally may be stored in a memory of the video generator 1102. In some embodiments, the video generator 1102 may receive the well plan via wired or wireless communications from another device and / or system. In certain embodiments, the well plan may include a great deal of information about the planned drilling of the well, including but not limited to, a planned trajectory, planned drilling parameters, expected geological formations, well logs, and expected progress, equipment to be used, such as a bottom hole assembly and drill bit, combinations thereof, and / or other information as desired. In some embodiments, the well plan may contain the drilling parameters to be used, among other information.

[0334] At block 1710, process 1700 optionally may include receiving information from one or more reference wells. The information may include information much like that in a well plan, including but not limited to the well trajectory, well log information, drilling parameters (such as but not limited to rate of penetration, weight on bit, differential pressure, torque, revolutions per minute, tool face, spindle position, and so forth), geological information, and / or equipment used, such as bottom hole assembly, mud motor, drill bit, combinations thereof, and / or as otherwise desired.

[0335] At block 1715, the process 1700 may include receiving and / or obtaining information from one or more sensors and / or one or more drilling parameters for the drilling operation. As a non-limiting example, video generator 1102 may receive information from a plurality of downhole and / or surface sensors 1106, 1108, including but not limited to MWD and LWD information, rate of penetration, weight on bit, differential pressure, torque, spindle position, and other parameters as described above, well log information, geological information, and / or a plurality of drilling parameters for the drilling operation, as described above, and / or other information as desired. In various embodiments, the video generator 1102 may receive the sensor data and / or drilling parameters via wired or wireless communications from a database, from a steering control system 168, or the like. In various embodiments, theplurality of drilling parameters may be accessed from storage 1110 (e.g., cloud storage). The video generator 1102 may receive and / or obtain the data from the sensors and / or other control systems of the drilling rig and its equipment directly or indirectly as desired. As non-limiting examples, the video generator 1102 may receive and / or obtain the data via application programming interfaces that cooperate and transfer data from the WITS format and / or other drilling rig control systems.

[0336] At block 1720, process 1700 may include generating a video 1114 with various information as desired and as previously described. As mentioned previously, the video 1 1 14 may include a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation. The graphic depiction may include an animated and / or video illustration of the drilling operation within a past predetermined time period. In some embodiments, generating the video 1114 may include generating the video 1114 with a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future predetermined time period. As a non-limiting example, video generator 1102 may generate a video 1114 using the processor, the drilling metrics and well plan stored in memory. In various embodiments, the video generator 1102 may store the video in the memory. Optionally, the video generator 1102 may use various software programs and / or subroutines to obtain the relevant information from the reference well(s), the drilling operation of the well being drilled, the well plan, and the like. Optionally, the video generator 1102 may automatically generate the video, audio and text portions of the video and then put them together into a video file, which may then be converted to one or more different video formats, as described below in more detail.

[0337] In various embodiments, generating the video 1114 may include generating the video 1114 with custom narration. As a non-limiting example, the video may be narrated using a different native language, a local accent or dialect. There are several programs and tools available that may change the language or dialect of a narration. These tools typically use text- to-speech (TTS) technology to convert written text into spoken words in the desired language or dialect. Example tools include but are not limited to: Google Text -to-Speech, Amazon Polly: Amazon Polly, Microsoft Azure Cognitive Services, IBM Watson Text to Speech,ResponsiveVoice, i Speech, Balabolka, Natural Reader, Loquendo, and Acapela Group. These tools generally require generating a textual input for converting into speech and then select the desired language or dialect for the output.

[0338] In various embodiments, generating the video 1114 may include generating the video 1114 without any actions taken by an operator or user. In such embodiments, the drilling information may be collected and then a video 1114 like that described herein may be automatically generated and delivered.

[0339] In various embodiments, generating the video 1114 may include generating the video 1114 and prompting a user to preview the automatically generated report prior to publication and / or distribution.

[0340] In various embodiments, generating the video 1114 may include generating the video 1114 via a plurality of application programming interfaces that connect to one or more drilling systems that perform the drilling operation. An Application Programming Interface (API) is a set of rules, protocols, and tools that allows different software applications to communicate and interact with each other. It defines the methods and data structures that developers may use to integrate their software applications with external services, libraries, or platforms. APIs enable developers to access the functionalities of another application or service without needing to understand the internal details of how that functionality is implemented.

[0341] In various embodiments, generating the video 1114 may include generating the video 1114 with projected challenges for a defined time period for the drilling operation based on the plurality of drilling parameters.

[0342] In some embodiments, generating the video 1114 may include generating the video 1114 with links to drilling data. In various embodiments, a link to the video is transmitted via at least one of an email message, a text message, and a chat message.

[0343] In certain embodiments, generating the video 1114 may include generating the video 1114 with one or more tags identifying information in the video.

[0344] In various embodiments, generating the video 1114 may include generating the video 1114 with a length of the video less than 30 seconds in duration, 30-60 seconds in duration, and / or any duration as desired.

[0345] In various embodiments, generating the video 1114 may include generating the video 1114 with a plurality of metrics. As a non-limiting example, the video 1114 may include toolface, weight on bit (WOB), rate of penetration (ROP), rotary speed, torque, mud flow rate, depth of cut, mechanical specific energy, slide drilling operations, rotary drilling operations, curvature, vibration, accelerations, other drilling dysfunctions, differential pressure, performance metrics, a number times that a previous planned activity achieved a desired target time over N number of previous drilling wells, combinations thereof, and / or as otherwise desired.

[0346] In various embodiments, process 1700 may include assigning a probability that the planned activity will achieve the desired target time during a current drilling operation and generating the video 1114 with the assigned probability.

[0347] Other information may be included in the video as desired. In some embodiments, block 1720 includes controlling one or more aspects of the video 1114 and / or the transmission and / or providing of the video 1114 to an end user based on various parameters, such as but not limited to an amount of information provided in the video, a type of information provided in the video, a source of information used in the video, a type of end user, an input or selection from an end user, combinations thereof, and / or as otherwise desired.

[0348] At block 1720, process 1700 optionally may include saving the video on a sever connected to a network and / or in other storage 1110 as desired. As a non-limiting example, video generator 1102 may save the video on a sever connected to a network, as described above, the video may include one or more of video content, audio content and text / data content. In various embodiments, the video may be stored in a memory of the computing device. In various embodiments, the video may be stored in a storage 1110.

[0349] At block 1725, process 1700 may include providing the video to at least one user. As a non-limiting example, video generator 1102 may provide the video to at least one user,as described above. In various embodiments, providing the video to at least one user may include: generating a link to the video; and transmitting the link to the video to the at least one user.

[0350] In various embodiments, the operations further may include transmitting a link to the video at a preset time and / or desired reporting interval. In various embodiments, the operations further may include transmitting a link to the video within a preset time following the end of operations. In various embodiments, the operations further may include transmitting a link to the video at a preset time and / or reporting interval. In various embodiments, the operations further may include storing a link to the video on a website for viewing after user login.

[0351] In some embodiments, the system and methods provided may allow for one or more recipients of a video to comment on the video and / or otherwise interact and / or modify the video 1114. In some embodiments, the comments, interaction, and / or modification may be provided by the video generator 1102 to one or more other recipients of the video, optionally by updating the video 1114. As a non-limiting example, depending on the video file format, the application used to view it by a user, and / or on the rights granted to a user with respect to that report (among other possible parameters), the video generator 1102 may allow the video 1114 to be annotated, manipulated, and / or modified, such as by adding text or other symbols, diagrams, highlighting, changing views, zooming in or out, combinations thereof, and / or as otherwise desired. The video generator 1102 may send the modified video to one or more other recipients of the video, either automatically and / or by a user input prompt (e.g., by the user clicking on a “send” or “reply” button or link or the like).

[0352] Optionally, the video generator 1102 may limit the number of recipients who may provide such comments, manipulations, and / or modifications, such as by granting only some system users such rights (e.g., based on a type of end user). Once a recipient makes such annotations and / or modifications, and hits a “send” or “reply” button or link (and / or the modified video is resent by the video generator 1102), the annotated video may be provided back to the storage 1110 where the annotated version may be stored. Once stored, the annotated version may be delivered to the same or a different set of recipients by the same or differentdelivery means as the initial video file. Alternatively, or additionally, the video generator 1102 may send a message (e.g., email, text, phone message, etc.) to the intended recipients of the annotated version that an annotated version is available, at which point the recipients notified of the available update may either request delivery by responding to the message or may access the annotated version, such as by accessing a website from which the annotated version is accessible and / or as otherwise desired.

[0353] In one embodiment, the video generator 1102 may allow a recipient who annotates the video to also restrict the other stakeholders to whom the annotated report is to be sent. As a non-limiting example, the video generator 1102 may provide and / or receive inputs, such as but not limited to receiving a selection of appropriate commands to restrict access and provide a list of recipients to whom access is to be granted. The annotated version might be in video form and / or a snapshot of a specific view of the video that then includes the annotated and “markup.” As non-limiting examples, the annotated version may be annotated by adding context, by asking a question, and / or clarifying (or requesting clarification of) some aspect of a question, combinations thereof, and / or as otherwise desired.

[0354] In some embodiments, for security and confidentiality reasons, the system may require the intended recipients to authenticate themselves before they are provided access to one or more videos.

[0355] Alternatively, or additionally, the system may generate different videos that are available to different users or user categories. As a non-limiting example, an owner / operator of a well may choose to allow any and all employees and officers interested in a given well to have full access to any and all information provided in a video for that well. Nonetheless, the owner / operator may not necessarily want to allow one or more vendors’ personnel to have access to all of that information and may want to restrict the information provided to vendor personnel. Moreover, there may be situations where one vendor refuses to allow a video with that vendor’s confidential information from being sent to a different vendor which is also involved with that well. In such cases, contractual restrictions may prevent the second vendor from receiving the same video as the other stakeholders, and the video generator may need to generate a second report for the second vendor by removing some or all information flaggedas proprietary to the first vendor. Various other types of different videos with different information may be generated by the system as desired.

[0356] Returning to the issue of security, there are a wide variety of techniques for authenticating users of and providing access to apps, websites, and networks. Among other things, biometrics may be used, such as facial recognition, voice recognition, ins patterns, fingerprints, and possibly DNA, by the system. Other techniques may be used by the system, such as requiring a user to first provide a username and a password before being provided with access to a resource (such as one or more videos). Two-factor authentication may also be used by the system to restrict access to one or more videos and provide security. The system connected to the internet and containing the video files may allow users to remain logged in or may require new logins each time or after a given time interval in order for a user to access the video(s). In some embodiments, when a user first creates an account and provides a username and password (or other login information, such as biometric information like a fingerprint, face scan, and / or eye scan), the user may be prompted by the system to provide one or more preferences, such as the type of report(s) to be received, the timing of the video(s) to be received, the manner in which the video(s) are to be delivered (e.g., text, email, website link, copy of the video versus link or both), the format of the video file to be provided, and any other preferences, such as additional text, graphic, or other information to be provided with the video(s). Alternatively or additionally, the system may allow the user to set such preferences, or modify such preferences, after the user’s account and security information has been provided. Various other security features may be implemented by the system as desired.

[0357] When a recipient accesses a video, the video may be displayed in an app, a video player, and / or a web browser, and / or as otherwise desired. In some embodiments, the video may be displayed on a user’s device with additional information, such as but not limited to a title of the video file being displayed, a “play” icon (such that by clicking on the play icon, the user may start the video playing), and a video control toolbar (such that the toolbar includes icons which allow the user to initiate the playing of the video file, skip ahead or fast forward the video file, adjust the sound volume for the sound associated with the video file, reverse the video file, freeze or pause the video file, and possibly also download or share the video file onsocial media or other websites, such as FaceBook, Twitter, Instagram, TikTok, YouTube, and the like), combinations thereof, and / or as otherwise desired.

[0358] In some implementations, the video generator 1102 may generate the video 1114 such that the video 1114 may be configured to allow a user to adjust the view presented by the display of the video to the user and / or any other characteristic of the video as desired.

[0359] As a non-limiting example, the video may be configured to allow a user to zoom in and out on the illustration as it is displayed, move forward or backward along the wellbore displayed as part of the illustration, and / or to change a type of view, combinations thereof, and / or as otherwise desired.

[0360] In some embodiments, the video generator 1102 generates the video 1114 such that the information displayed in the video 1114 automatically may change to match the location of the well that is the focus of the user’s adjustment of the display of the animation.

[0361] Additionally, or alternatively, the illustration display may be configured to allow the user to modify the display presented by providing a user input to change the view. In some cases, the user may be able to modify the illustration by 360 degrees, looking at the well from below, from above, from behind, from in front, from either side, and from any other angle. In one example, the video as presented may be configured to allow a user to use a game controller to adjust the view presented of the wellbore in a manner much like that described in U.S. Patent No. 11,162,356, issued on November 2, 2021, and titled “Downhole Display,” which is hereby incorporated by reference as if fully set forth herein.

[0362] The video generator 1102 may save and / or store some or all of the videos described above in the storage 1110.

[0363] In some embodiments, the system may be programmed with software to store, index, and retrieve the videos in response to requests from users authorized to do so. Optionally, each of the videos may be associated with one or more tags or identifiers or other metadata.

[0364] Optionally, the system may obtain information from the users who access the videos. As a non-limiting example, for each video file consumed (in any duration) by eachuser (on any device), the system in one embodiment may track and store one or more of the following information: platform used for access to server (e.g., desktop, laptop, tablet, etc., and operating system, such as iOS, Windows, Android, etc.); all video metadata tags for video clips begun; duration (e.g., total running time) of video files started; percent of video completed (total time watched and time into video TRT where exited / skipped); time of day for consumption of video file; skip click actions; bit rate at which each video file was streamed; and interact! on(s) with the video's progress bar; combinations thereof, and / or as otherwise desired. Optionally, such user actions may be logged and stored in a database in non-volatile storage.

[0365] The foregoing descriptions have referred to a number of different tags or identifier information associated with each video file. The tags may be data files or identifiers in a variety of forms which may be associated with their corresponding video files in a variety of ways. Examples of tags that might be useful include the following: name of well, measured depth range, date of time period covered by report, owner or operator name, personnel name (e.g., company man on site), whether the video involves an incident, a type of incident or event that occurred during the time interval of the video, weather conditions encountered, and / or any of the drilling parameters noted above, such as WOB, ROP, differential pressure, torque, rotary versus slide drilling operations, RPMs, and the like, geological conditions, such as any of those described above, including geological formations encountered, hardness, porosity, stickiness, and so forth, and any equipment used, such as BHA, drill bit, cutters, and so forth.

[0366] Although not shown, in some embodiments, the video generator 1102 may provide a search function (optionally as part of the video 1114) for searching for the information and video files stored in a database. As a non-limiting example, a user may be presented with a “Search” bar on the user’s device or displayed on a web browser which allows the user to enter any information desired by user, such as alphanumeric information or standard characters, which is then transmitted as a search request to the server. The system may receive the search request and performs a search of the database for matching tags. The system may retrieve information from the user’s profile to determine the user’s preferences previously indicated,prior viewing history and log information, prior likes and dislikes, and the like as described above.

[0367] In some embodiments, the system may sort and rank the video files and information which best match the search received from the user to rank the matching video files and transmit a list of the matching video files with the highest ranked matching video files listed first. Optionally, the system may provide a list of ranked videos to the user that is limited based on criteria and / or quantity. As a non-limiting example, the system may provide a list of five or ten videos ranked by the system.

[0368] In certain embodiments, the matching and / or ranking by the system may be performed by searching for tags that match some or all of the search string from the user. As a non-limiting example, it may be that there are multiple video files associated with tags that match several of the search string inputs. In such cases, a “best” match may be determined by various algorithms. As a non-limiting example, the videos may be ranked based on the greatest number of identical matches, or based on a points weighting approach, in which each file tag that matches or is deemed “close” to a search input string receives a set of points, with the “best” match being the video which has the highest point total for tags matching the search input. The system may provide the user with a list of “matching” videos, ranked in order of matches (e.g., point totals) or may simply provide the user with the “best” matching video. The system could also leverage large language models (like ChatGPT) or other AI / ML to speak to the application in order to search for the desired report. In an example, the system is asked to find a video of a well similar to x, or a well for a particular owner or operator, a well within the same formation, or a well (or wells) within a specified distance of a specified well. Once the user sees the results, they might specify something different to get to the desired result.

[0369] Process 1700 may include additional implementations, such as any single implementation or any combination of implementations described below and / or in connection with one or more other processes described elsewhere herein. In a first implementation, the graphical depiction may include a three-dimensional rendering of the drilling operation.

[0370] It should be noted that while FIG. 17 shows example blocks of process 1700, in some implementations, process 1700 may include additional blocks, fewer blocks, differentblocks, or differently arranged blocks than those depicted in FIG. 17. Additionally, or alternatively, two or more of the blocks of process 1700 may be performed in parallel.

[0371] The following is an example of how the videos system may be used. Suppose a well being drilled progresses 1000 feet from 6 p.m. to 4 a.m. The equipment used to drill the well (e.g., rig, pipe diameter, pipe type, number of stands added to the drill string, drill bit, BHA, etc.) is known. During that time interval, a number of surveys will be taken, and the MWD information obtained will establish the location of the BHA at the survey station locations during the drilling. In addition, the LWD information will provide logs (e g., gamma ray logs) for that drilling interval. The drilling mud may be examined and may reveal geological information, such as the type of rock formation(s) drilled during that time interval. Much additional information will be available for the drilling operations during that time interval, such as toolface, differential pressure, mud flow rate, and the like.

[0372] Upon the completion of the time interval, which is to be the subject of the video, the system 1102 may be programmed to obtain the information for the video from the data obtained and stored during the time interval that is the subject of the video. In addition, the system 1102 may obtain the relevant portions of the well plan and or offsetting wells or synthetic wells (composite wells, or tech limit wells, etc) that correspond to the time interval. The system 1102 then generates an animation showing the progress and location of the BHA as drilling occurred during that time interval. The system 1102 generates an audio narration from the data obtained during that time interval to describe key points about the drilling operations during that time interval, such as the number of feet drilled, any significant deviations from plan, any incidents noted, any well path trajectory changes, any changes to the well plan, geological formations drilled, and the like. The system 1102 further generates text to be included, such as shown in the exemplary screen grabs in FIGS. 12-16, that shows various data from the drilling operations as the well was drilled during that time interval. The system 1102 may also use the well plan to generate an animation, audio narration, and text information to be included in the video that describes the planned drilling operations during the next time interval, which may be of the same length or a different length than that of the 6 p.m. to 4 a.m. interval. Additionally, the log information from the time interval may be included in the video.As a non-limiting example, the gamma ray log obtained during drilling operations for that interval might be included as an animation showing the log as it was obtained during the time period. The log obtained during drilling may be displayed side-by-side or overlayed with one or more corresponding gamma ray log portions from one or more reference wells that are included in the well plan. A system like the steering control system 168 may be used to automatically correlate the gamma ray log obtained with one or more portions of the logs from the one or more reference wells, and the correlation process (with or without an animation thereof) may be generated for inclusion in the video.

[0373] In some drilling applications, computer vision systems may be used. As described in U.S. Patent No. 10,957,177, issued on March 23, 2021, titled “Systems and Methods for Oilfield Drilling Operations Using Computer Vision”, which is hereby incorporated herein as if fully set forth herein, computer visions may be used to automatically determine a great deal of information during drilling. If the well being drilled is drilled using one or more computer vision systems like those described in the ‘177 patent noted, some of the video obtained by the computer vision system(s) may be included in the video. As a non-limiting example, one potential use of a computer vision system is to automatically identify safety concerns. If a safety incident occurs during the time interval, a user may provide input to the system 1102 and a time period during which the safety incident occurred. The system 1102 may then retrieve the appropriate video from the computer vision system and include that video in the video, together with the automatically generated audio narration of the incident. Another example of the use of the computer vision system described in the ‘ 177 patent is to maintain a pipe tally. The system 1102 may obtain the pipe tally information from the computer vision system and may include that pipe tally data in the video. These are just a few examples of how the information and / or video obtained by the computer vision system may be incorporated in the video generated by system 1102.

[0374] Once the system 1102 has generated the animation, the audio narration, and the text information to be included, the video file for the video is generated. As noted above, the system 1 102 may be programmed to generate a plurality of video files for a given report, if it is desired for stakeholders to view the video on different devices running different video displaysoftware. Once the video file has been generated, the video file may be saved and stored on a server that is connected to and accessible from the internet. A link to the video file may be generated and then sent by email, text message, or otherwise to stakeholders authorized to receive the same and view the video. In some implementations, the video file may be automatically posted to one or more video hosting services, such as Snapchat, FaceBook, Instagram, TikTok, YouTube, and the like. In addition, or alternatively, the video file may be made available only to users of an application downloaded onto the user’s device, such as a phone, tablet, computer, or other video display device. The user may then activate the application, which may play the video for the user. In some implementations, the video may be delivered to users, the video may be delivered via a link delivered to users, or users may be notified of the availability of a new video. In some situations, the video may not be delivered and no notification may be delivered; if the stakeholders for a given well all know that a new daily report will be available at 6 a m. each day during drilling of the well, as a non-limiting example, no notifications may be needed.

[0375] Referring now to FIG. 18, a second example of rig control systems 500 is illustrated in schematic form. It is noted that rig control systems 500 may include fewer or more elements than shown in FIG. 18 in different embodiments. As shown, ng control systems 500 includes steering control system 168 and drilling rig 210. Specifically, steering control system 168 is shown with logical functionality including an autodriller 510, a bit guidance 512, and an autoslide 514. Drilling rig 210 is hierarchically shown including rig controls 520, which provide secure control logic and processing capability, along with drilling equipment 530, which represents the physical equipment used for drilling at drilling rig 210. As shown, rig controls 520 include WOB / differential pressure control system 522, positional / rotary control system 524, fluid circulation control system 526, and sensor system 528, while drilling equipment 530 includes a draw works / snub 532, top drive 140, mud pumping equipment 536, and MWD / wireline equipment 538.

[0376] Steering control system 168 represent an instance of a processor having an accessible memory storing instructions executable by the processor, such as an instance of controller 1000 shown in FIG. 10. Also, WOB / differential pressure control system 522,positional / rotary control system 524, and fluid circulation control system 526 may each represent an instance of a processor having an accessible memory storing instructions executable by the processor, such as an instance of controller 1000 shown in FIG. 10, but for example, in a configuration as a programmable logic controller (PLC) that may not include a user interface but may be used as an embedded controller. Accordingly, it is noted that each of the systems included in rig controls 520 may be a separate controller, such as a PLC, and may autonomously operate, at least to a degree. Steering control system 168 may represent hardware that executes instructions to implement a surface steerable system that provides feedback and automation capability to an operator, such as a driller. As anon-limiting example, steering control system 168 may cause autodriller 510, bit guidance 512 (also referred to as a bit guidance system (BGS)), and autoslide 514 (among others, not shown) to be activated and executed at an appropriate time during drilling. In particular implementations, steering control system 168 may be enabled to provide a user interface during drilling, such as the user interface 850 depicted and described below with respect to FIG. 8. Accordingly, steering control system 168 may interface with rig controls 520 to facilitate manual, assisted manual, semi-automatic, and automatic operation of drilling equipment 530 included in drilling rig 210. It is noted that rig controls 520 may also accordingly be enabled for manual or user-controlled operation of drilling and may include certain levels of automation with respect to drilling equipment 530.

[0377] In rig control systems 500 of FIG. 18, WOB / differential pressure control system 522 may be interfaced with draw works / snubbing unit 532 to control WOB of drill string 146. Positional / rotary control system 524 may be interfaced with top drive 140 to control rotation of drill string 146. Fluid circulation control system 526 may be interfaced with mud pumping equipment 536 to control mud flow and may also receive and decode mud telemetry signals. Sensor system 528 may be interfaced with MWD / wirelme equipment 538, which may represent various BHA sensors and instrumentation equipment, among other sensors that may be downhole or at the surface.

[0378] In rig control systems 500, autodriller 510 may represent an automated rotary drilling system and may be used for controlling rotary drilling. Accordingly, autodriller 510 may enable automate operation of rig controls 520 during rotary drilling, as indicated in thedrill plan. Bit guidance 512 may represent an automated control system to monitor and control performance and operation drilling bit 148.

[0379] In rig control systems 500, autoslide 514 may represent an automated slide drilling system and may be used for controlling slide drilling. Accordingly, autoslide 514 may enable automate operation of ng controls 520 during a slide and may return control to steering control system 168 for rotary drilling at an appropriate time, as indicated in the drill plan. In particular implementations, autoslide 514 may be enabled to provide a user interface during slide drilling to specifically monitor and control the slide. As a non-limiting example, autoslide 514 may rely on bit guidance 512 for orienting a toolface and on autodriller 510 to set WOB or control rotation or vibration of drill string 146.

[0380] FIG. 18 illustrates the video generator 1102 that interacts with the steering control system 168. The steering control system 168 may send information from the drilling rig 210 to the video generator 1102 as described above. In various embodiments, the video generator 1102 may provide instructions to the steering control system 168 and / or other control system of the drilling ng as desired.

[0381] It should be appreciated that longer or shorter time intervals may be the subject of the videos described herein, and that the stakeholders may prefer the availability of reports at different times during a day (e g., early morning, early afternoon, late evening, etc.). One advantage of the system 1102 is that it offers a great deal of flexibility for the various stakeholders in a well in terms of the information to be delivered and when it is to be delivered, while still providing a concise, understandable, and easily retrieved summary of drilling operations with context quickly after they occur.

[0382] The description and figures included herein focus primarily on the creation and distribution of videos regarding a wellbore during the drilling of the same. The same or similar systems and methods as described herein may be used to automatically generate and distribute videos regarding the completion of a wellbore (as opposed to its drilling). Well completion is the process of making a well ready for production (or injection) after drilling operations. There are a number of types of completion processes commonly used, including barefoot completion, open hole completion, use of a pre-drilled liner or a slotted liner, and so forth. Hydraulicfracturing may be included as part of the completion process. Completion usually involves preparing the bottom of the hole to the required specifications, running in the production tubing and its associated downhole tools as well as perforating and stimulating the well as required. Generally, running in and cementing the casing in the wellbore is part of the well completion process. The casing is provided so that the well does not close in upon itself and also protects the hydrocarbon fluids from water or sand.

[0383] From this very brief overview of the completion process, it will be appreciated that, as with the drilling of a well, a number of stakeholders at a number of companies may be interested and require reports on the progress of the completion efforts, and that while some of the stakeholders may be the same as those for the drilling operations, the stakeholders for completion may be different.

[0384] The system described herein for generating and distribution videos for drilling activities may be used to obtain information from one or more surface and / or downhole sensors and from equipment used during the completion process to generate videos showing the progress of the completion process and related activities during a preceding time interval, as well as the planned completion activities to follow in a successive time interval. A non-limiting example of this is a customer is running a 24 hour zipper fracturing job where multiple wellbores are being completed simultaneously, the video would visualize the different frac stages that were completed, the associated volumes / pressures of water, proppant, chemicals, etc, plus the visualization of what was upcoming in a certain amount of time. The system may generate a video showing one or more of the following: health of the surface equipment pumps, average and peak / trough flowrates and pressures, the graphical representation of the pressure profiles from various sensors for each stage. Optionally, the video could highlight the overall operation as well as the challenges faced. On the upcoming operations, the video could show historical completions in the similar area, lessons learned, challenges faced, and comparisons between the different wells as they completed them. In a situation with a microcosmic job where they were tracking the locations of the frac, or any other type of sensors at surface intended to track where the fractures were being created in the subsurface, the video could visualize (in 3D or 2D) what the planned fracture propagation vs the actual propagation andshow effective percentage of propagation. Additional sensors at surface measuring vibration from other wellheads, measurements from offsetting fiber optic lines run along the wellbores and such could also be visualized to show the effectiveness of the frac as well as challenges of the stimulation. Such a video for the completion process may be automatically generated and distributed to stakeholders in the completion by the same or a similar system like that described above. Videos for completion activities may be stored, searched, tagged, and protected as described above with respect to videos for drilling activities. Those, including the different personas illustrated above, interested in receiving the videos for the well completion activities may register or signup for the same in the same or similar manner as that described above for stakeholders interested in the drilling videos. The wellbore would be mapped based on the drilling of the actual well, and the placement of the different plugs and perforations along the wellbore would be visualized. The relative rock hardness from the existing wellbore would be visualized to see the optimum frac placement. Each of the wells would have “layers” to overlay the drilling data over the frac data to visualize potential issues or opportunities for the completion operation. Things like loss zones, unusual situations, excess Dog Leg Severity, micro DLS, logs of hole geometry showing larger washouts in the hole, cement bond logs showing potential issues with the cement, etc. could be overlay ed on the visualization to ensure that the operations were aware of the challenges. Other layers would be previous microseismic mapping showing where existing fracs have propagated overlayed in the area of concern to show where communication might exist between a parent and child well, offsetting well, well in a lower formation or upper formation from the current wellbore, and the user would be able to see these representations in 3D.

[0385] Production phase videos may be generated and distributed as described above for drilling and completion videos. The production stage generally is when oil and gas are produced from the well. At this stage, the drilling ng used to drill and complete the well is usually gone, and the top of the well usually has a collection of valves called a Christmas tree or production tree. These valves regulate pressures, control flows, and allow access to the wellbore in case further completion work is needed. The outlet of the production tree may be connected to a distribution network of pipelines and tanks. In some wells, an artificial lift system may be employed to bring the oil and gas from downhole to the surface. In some cases,a workover of the well may be needed to enhance production from the well, and / or enhanced recovery methods may be used to increase production of oil and gas in some wells. The enhanced recovery methods may include water flooding, steam flooding, or CO2 flooding. As with drilling and completion activities, videos for production activities and for the amount of production from one or more oil and gas wells may be generated and distributed using the same or similar systems and methods described herein for drilling and / or completion activities. One or more surface sensors and downhole sensors may be used to collect and provide information to a system to be used to generate the production reports, as well as any enhanced recovery or workover operations on a well. Stakeholders interested in the production videos may sign up for the same using the same or similar systems and methods as described above. An example is a video showing the trend of an existing well that has just been brought on to production. It could show flowback rates and volumes of sand / water / oil and gas, amount produced, pressures through the different choke settings. Once flowback is complete, it could show rpms on downhole pumps, cycles from production pump jacks vs total production on a daily basis. It could show the type curve and if its ahead or behind budgeted production. It could show accumulated production per well, total costs per well, total revenue per well, future planned workover work, etc.

[0386] This disclosure provides systems and methods for generating one or more reports during drilling, completion, and / or production operations for one or more wells, including systems and methods performed by a processor executing software on a computer system that may include any or all of the following steps, and wherein the computer system may be coupled to one or more control systems or equipment associated with a drilling ng, equipment for completion activities, and / or production: accessing a well plan for one or more drilling, completion, and / or production activities for one or more wells, including a plurality of wells in a single pad, or a plurality of wells in a single field; receiving a plurality of parameters for the drilling, completion and / or production activities for the well;• after a first time interval during which one or more drilling, completion or production activities occurred, generating one or more reports therefor, wherein the one or more reports includes:• a graphical depiction of the drilling, completion, and / or the production activities for the well during the first time interval based on the plurality of parameters for the drilling, completion or production activities, respectively, the graphic depiction including an animated and / or video illustration of the drilling, completion or production activities within the first time interval, wherein the animated and / or video illustration comprises a display showing the progress of the drilling, completion or production activities in the well during the first time interval, and a comparison of the progress of the drilling, completion or production activities with a plan for the drilling, completion or production activities for the well;• a plurality of metrics associated with the drilling, completion or production activities;• a summary of planned drilling, completion or production activity for the well for a future second time interval;• saving the video in a database on a server connected to a network; and• providing the video or access to the video to at least one user.

[0387] The graphical depiction may comprise a three-dimensional rendering of the well as drilled, planned to be drilled, and / or the target well path, and the planned activity may further comprise a summary of geological changes or other events or well conditions anticipated for the future predetermined time period, the video may be generated automatically via the use of a plurality of application programming interfaces that connect the video generating system to one or more control systems associated with the drilling rig or other equipment for drilling, completion, or production. The plurality of metrics may include a number times that a plan achieved a desired target (or failed to achieve a target, missed by a particular margin or threshold, etc.), toolface orientation, weight on bit (WOB), rate of penetration (ROP), rotaryspeed, torque, mud flow rate, depth of cut, mechanical specific energy, trajectory, slide drilling operations, rotary drilling operations, curvature, vibration, accelerations, other drilling dysfunctions, differential pressure, distance drilled, logging, geological formations, performance metrics, combinations thereof, and / or as otherwise desired. The video may also include a probability that the plan will achieve the desired target, such as but not limited to a target during the second time interval or the overall well plan drilling time target. The video may further comprise projected challenges for a defined time period for the completion or production activity based on the plurality of parameters, an audio or text narration. Providing the video to at least one user may comprises generating a link to the video and transmitting the link to the video to the at least one user, including transmitting the link to the video at a preset time, the videos may be configured to change in response to user input to allow the user to manipulate the display presented to the user, thereby allowing the user to view a display of the illustration from any one of 360 degrees, and / or to allow a user to freeze the illustration, fast forward the illustration, and / or reverse the illustration, and / or to add tags to the video, wherein the tags are associated with the video in a searchable database for searching, the video may further comprise links to data and / or a link to the video may be transmitted via at least one of an email message, a text message, and a chat message, the video may be automatically generated, and may include one or more tags identifying information in the video. The length of the video may be less than 30 seconds in duration, and / or may be between 30 and 60 seconds in duration, or may be greater than 60 seconds in duration, the videos may be stored in a searchable database of prior reports, the videos may be varied to provide additional information using artificial intelligence generated inputs based on user searches associated with the videos.Illustrative Embodiments

[0388] A collection of exemplary embodiments is provided below, including at least some explicitly enumerated as an “Illustration” providing additional description of a variety of example embodiments in accordance with the concepts described herein. These illustrations are not meant to be mutually exclusive, exhaustive, or restrictive; and the disclosure not limitedto these example illustrations but rather encompasses all possible modifications and variations within the scope of the issued claims and their equivalents.

[0389] Illustration 1. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving a plurality of drilling parameters for the drilling operation; generating a video including: a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated or video illustration of the drilling operation within a past predetermined time period; a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; and providing the video to at least one user.

[0390] Illustration 2. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the graphical depiction comprises a three-dimensional rendering of the drilling operation.

[0391] Illustration 3. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the planned activity further comprises a summary of geological changes for the future predetermined time period.

[0392] Illustration 4. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is generated via a plurality of application programming interfaces that connect to one or more drilling systems coupled to a drilling rig that is drilling the well.

[0393] Illustration 5. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the plurality of metrics includes a number of times that a forward plan achieved a desired target time over N number of previous drilling wells.

[0394] Illustration 6. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise assigning a probability that the forward plan will achieve the desired target time during a current drilling operation.

[0395] Illustration 7. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises projected challenges for a defined time period for the drilling operation based on the plurality of drilling parameters.

[0396] Illustration 8. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video comprises audio narration regarding the drilling operation.

[0397] Illustration 9. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein providing the video to at least one user comprises: generating a link to the report; and transmitting the link to the video to at least one user.

[0398] Illustration 10. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise transmitting a link to the video at a preset time.

[0399] Illustration 11. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise uploading the video to a social media platform accessible via the internet.

[0400] Illustration 12. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise transmitting a link to the video within a preset time following the end of operations.

[0401] Illustration 13. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, whereinthe video further comprises links to drilling data generated during the time interval covered by the report.

[0402] Illustration 14. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein a link to the video is transmitted via at least one of an email message, a text message, and a chat message.

[0403] Illustration 15. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise storing a link to the video on a website, wherein the video is not accessible for viewing until after a user login.

[0404] Illustration 16. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is automatically generated.

[0405] Illustration 17. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video includes one or more tags associated with information in the report.

[0406] Illustration 18. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is less than 30 seconds in duration.

[0407] Illustration 19. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is between 30 and 60 seconds in duration.

[0408] Illustration 20. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is between 60 seconds and 120 seconds in duration.

[0409] Illustration The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprisinga video database, wherein the video database is searchable and comprises a plurality of reports, each associated with a well.

[0410] Illustration 22. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video comprises information different from that in a previous video generated by the same system, wherein the different information results from modifications by the system in response to user searches or user requests.

[0411] Illustration 23. A method performed by a processor executing software on a computer system, the method comprising, accessing a well plan for drilling a well; receiving a plurality of drilling parameters for drilling the well; after drilling the well for a predetermined time interval, generating a report, wherein the video includes: a graphical depiction of the drilling of the well during the time interval based on the plurality of drilling parameters for the drilling, the graphic depiction including an animated or video illustration of the drilling within the time interval, wherein the animated or video illustration comprises a display showing the progress of a bottom hole assembly in the well as it is being drilled during the time interval, the trajectory of the well, and a comparison of the trajectory of the well and a planned trajectory of the well; a plurality of metrics associated with the drilling; and a summary of planned drilling activity for drilling the well for a future predetermined time period; saving the video in a database on a server connected to a network; and providing a copy of the video or access to the video to at least one user.

[0412] Illustration 24. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the graphical depiction comprises a three-dimensional rendering of the well trajectory.

[0413] Illustration 25. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the planned activity further comprises a summary of geological changes anticipated for the future predetermined time period.

[0414] Illustration 26. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is generated via a plurality of application programming interfaces that connect to one or more drilling systems coupled to a drilling rig that performs the drilling.

[0415] Illustration 27. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the plurality of metrics includes a number times that a forward plan achieved a desired target time over N number of previous drilling wells.

[0416] Illustration 28. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising assigning a probability that the forward plan will achieve the desired target time during a current drilling operation.

[0417] Illustration 29. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises projected challenges for a defined time period for the drilling based on the plurality of drilling parameters.

[0418] Illustration 30. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises narration.

[0419] Illustration 31. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein providing the video to at least one user comprises: generating a link to the report; and transmitting the link to the video to the at least one user.

[0420] Illustration 32. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising transmitting the link to the video at a preset time.

[0421] Illustration 33. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, whereinthe display of the animated or video illustration of the video is configured to change in response to user input to allow the user to manipulate the display presented to the user, thereby allowing the user to view a display of the illustration from any one of 360 degrees.

[0422] Illustration 34. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the display of the illustration is further configured to allow a user to freeze the illustration, fast forward the illustration, and / or reverse the illustration, and / or to add tags to the report, wherein the tags are associated with the video in a searchable database for searching.

[0423] Illustration 35. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises links to drilling data.

[0424] Illustration 36. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein a link to the video is transmitted via at least one of an email message, a text message, and a chat message.

[0425] Illustration 37. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise storing a link to the video on a website for viewing after user login.

[0426] Illustration 38. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is automatically generated.

[0427] Illustration 39. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video includes one or more tags identifying information in the report.

[0428] Illustration 40. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is less than 30 seconds in duration.

[0429] Illustration 41. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is between 30 and 60 seconds in duration.

[0430] Illustration 42. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is greater than 60 seconds in duration.

[0431] Illustration 43. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is stored in a searchable database of prior reports.

[0432] Illustration 44. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising receiving artificial intelligence generated inputs based on user searches.

[0433] Illustration 45. A non-transitory, computer readable medium storing instructions that when executed cause one or more processors to perform operations, the operations comprising: accessing a drill plan for a drilling operation; accessing one or more offset wells of the current well and / or one or more synthetic wells (composite best wells, technical limit wells, etc); receiving a plurality of drilling parameters for the drilling operation; generating a video including: a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated or video illustration of the drilling operation within a past predetermined time period; a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future predetermined time period, saving the video on a server connected to a network; and providing the video to at least one user.

[0434] Illustration 46. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the graphical depiction comprises a three-dimensional rendering of the drilling operation.

[0435] Illustration 47. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, whereinthe planned activity further comprises a summary of geological changes for the future predetermined time period.

[0436] Illustration 48. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is generated via a plurality of application programming interfaces that connect to one or more drilling systems that perform the drilling operation.

[0437] Illustration 49. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the plurality of metrics includes a number times that a forward plan achieved a desired target time over N number of previous drilling wells.

[0438] Illustration 50. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising assigning a probability that the forward plan will achieve the desired target time during a current drilling operation.

[0439] Illustration 51. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises projected challenges for a defined time period for the drilling operation based on the plurality of drilling parameters.

[0440] Illustration 52. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video comprises custom narration.

[0441] Illustration 53. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein providing the video to at least one user comprises: generating a link to the report; and transmitting the link to the video to the at least one user.

[0442] Illustration 54. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise transmitting a link to the video at a preset time.

[0443] Illustration 55. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise transmitting a link to the video at a preset time.

[0444] Illustration 56. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise transmitting a link to the video within a preset time following the end of operations.

[0445] Illustration 57. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises links to drilling data.

[0446] Illustration 58. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein a link to the video is transmitted via at least one of an email message, a text message, and a chat message.

[0447] Illustration 59. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise storing a link to the video on a website for viewing after user login.

[0448] Illustration 60. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is automatically generated.

[0449] Illustration 61. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video includes one or more tags identifying information in the report.

[0450] Illustration 62. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is less than 30 seconds in duration.

[0451] Illustration 63. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is between 30 and 60 seconds in duration.

[0452] Illustration 64. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is greater than 60 seconds in duration.

[0453] Illustration 65. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is stored in a searchable database of prior reports.

[0454] Illustration 66. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, the operations further comprising receiving artificial intelligence generated inputs based on user searches.

[0455] Illustration 67. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the instructions further comprise instructions for accessing information associated with one or more offset wells and incorporating information associated with the one or more offset wells in the report.

[0456] Illustration 68. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the one or more offset wells comprise one or more composite wells and / or one or more technical limit wells.

[0457] Illustration 69. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the summary of planned activity comprises an animation or video illustration of the drilling operation for a future predetermined time period.

[0458] Illustration 70. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, furthercomprising: accessing information associated with one or more offset wells and incorporating information associated with the one or more offset wells in the report.

[0459] Illustration 71. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the one or more offset wells comprise one or more composite wells and / or one or more technical limit wells.

[0460] Illustration 72. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the summary of planned activity comprises an animation or video illustration of the drilling operation for a future predetermined time period.

[0461] Illustration 73. A method performed by a processor executing software on a computer system, the method comprising, accessing a well plan for one or more completion activities or one or more production activities for a well; receiving a plurality of parameters for the completion or production activities for the well; after a first time interval during which one or more completion or production activities occurred, generating a report, wherein the video includes: a graphical depiction of the completion activities or the production activities for the well during the first time interval based on the plurality of parameters for the completion or production activities, the graphic depiction including an animated or video illustration of the completion or production activities within the first time interval, wherein the animated or video illustration comprises a display showing the progress of the completion or production activities in the well during the first time interval, and a comparison of the progress of the completion or production activities with a plan for completion or production activities for the well; a plurality of metrics associated with the completion or production activities; a summary of planned completion or production activity for the well for a future second time interval; saving the video in a database on a server connected to a network; and providing the video or access to the video to at least one user.

[0462] Illustration 74. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the graphical depiction comprises a three-dimensional rendering of the well.

[0463] Illustration 75. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the planned activity further comprises a summary of geological changes anticipated for the future predetermined time period.

[0464] Illustration 76. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is generated via a plurality of application programming interfaces that connect to one or more systems.

[0465] Illustration 77. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the plurality of metrics includes a number times that a plan achieved a desired target.

[0466] Illustration 78. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising assigning a probability that the plan will achieve the desired target.

[0467] Illustration 79. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations wherein the video further comprises projected challenges for a defined time period for the completion or production activity based on the plurality of parameters.

[0468] Illustration 80. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises narration.

[0469] Illustration 81. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein providing the video to at least one user comprises: generating a link to the report; and transmitting the link to the video to the at least one user.

[0470] Illustration 82. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising transmitting the link to the video at a preset time.

[0471] Illustration 83. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the display of the animated or video illustration of the video is configured to change in response to user input to allow the user to manipulate the display presented to the user, thereby allowing the user to view a display of the illustration from any one of 360 degrees.

[0472] Illustration 84. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the display of the illustration is further configured to allow a user to freeze the illustration, fast forward the illustration, and / or reverse the illustration, and / or to add tags to the report, wherein the tags are associated with the video in a searchable database for searching.

[0473] Illustration 85. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video further comprises links to data.

[0474] Illustration 86. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein a link to the video is transmitted via at least one of an email message, a text message, and a chat message.

[0475] Illustration 87. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the operations further comprise storing a link to the video on a website for viewing after user login.

[0476] Illustration 88. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is automatically generated.

[0477] Illustration 89. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video includes one or more tags identifying information in the report.

[0478] Illustration 90. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is less than 30 seconds in duration.

[0479] Illustration 91. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is between 30 and 60 seconds in duration.

[0480] Illustration 92. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the length of the video is greater than 60 seconds in duration.

[0481] Illustration 93. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, wherein the video is stored in a searchable database of prior reports.

[0482] Illustration 94. The system, method, and / or non-transitory computer readable medium of any preceding or subsequent illustration or combination of illustrations, further comprising receiving artificial intelligence generated inputs based on user searches.

[0483] Illustration 95. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving information obtained from one or more sensors during the drilling operation, wherein the drilling operation comprises drilling a well during a first time interval; receiving information related to one or more drilling parameters for the drilling operation; generating a video including: a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated and / or video illustration of the drilling operation within a past predetermined time period; a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; and providing the video to at least one user.

[0484] Illustration 96. A method performed by a computer system, the method comprising, accessing, by the computer system, a well plan for drilling a well; receiving, by the computer system, information from one or more sensors during drilling of a well during a first time interval and a plurality of drilling parameters for drilling the well during the first time interval; after drilling the well for the first time interval, generating, by the computer system, a video, wherein the video includes: a graphical depiction of the drilling of the well during the first time interval based on the information from the one or more sensors and the plurality of drilling parameters for the drilling, the graphic depiction including an animated and / or video illustration of the drilling within the time interval, wherein the animated and / or video illustration comprises a display showing the progress of a bottom hole assembly in the well as it is being drilled during the first time interval, a three-dimensional rendering of a portion of a trajectory of the well, a comparison of the trajectory of the well and a corresponding portion of a planned traj ectory of the well, and text or audio narration; a plurality of metrics associated with the drilling; and a summary of planned drilling activity for drilling the well for a future predetermined time period; saving, by the computer system, the video in a database on a server connected to a network; and providing, by the computer system, a copy of the video or access to the video to at least one user.

[0485] Illustration 97. A non-transitory, computer readable medium storing instructions that when executed cause one or more processors to perform operations, the operations comprising: accessing a well plan for a drilling operation; accessing one or more offset wells of the current well and / or one or more synthetic wells (composite best wells, technical limit wells, etc); receiving a plurality of drilling parameters for the drilling operation; generating a video including: a graphical depiction of the drilling operation based on the plurality of drilling parameters for the drilling operation, the graphic depiction including an animated and / or video illustration of the drilling operation within a past predetermined time period; a plurality of metrics associated with the drilling operation as provided by the drill plan; and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; and providing the video to at least one user.

[0486] Illustration 98. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving information obtained from one or more sensors during the drilling operation, wherein the drilling operation comprises drilling a well during a first time interval; receiving information related to one or more drilling parameters for the drilling operation; automatically generating a video based on the well plan, the information obtained from one or more sensors, and the information related to one or more drilling parameters, wherein the video comprises a graphical depiction of the drilling operation within a predetermined time period, a plurality of metrics associated with the drilling operation as provided by the drill plan, and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; and providing the video to at least one user.

[0487] Illustration 100. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving information obtained from one or more sensors during the drilling operation, wherein the drilling operation comprises drilling a well during a first time interval; receiving information related to one or more drilling parameters for the drilling operation; predicting a future event or condition of the drilling operation based on at least one of the well plan, the information obtained from one or more sensors, or the information related to one or more drilling parameters; automatically generating a video based on the well plan the information obtained from one or more sensors, and the information related to one or more drilling parameters, the video comprising an animated or video illustration of the drilling operation within a predetermined time period, a plurality of metrics associated with the drilling operation as provided by the drill plan, and a prediction of the future event or condition in a future predetermined time period; saving the video on a server connected to a network; and providing the video to at least one user.

[0488] Illustration 101. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving information obtained fromone or more sensors during the drilling operation, wherein the drilling operation comprises drilling a well during a first time interval; receiving information related to one or more drilling parameters for the drilling operation; determining a drilling operation time period based on an identified user; automatically generating a video based on the well plan, the information obtained from one or more sensors, and the information related to one or more drilling parameters, the video comprising an animated or video illustration of the drilling operation during the drilling operation time period, a plurality of metrics associated with the drilling operation, and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; and providing the video to the identified user.

[0489] Illustration 102. A system comprising: one or more processors; a memory for storing instructions that when executed by the one or more processors perform operations comprising: accessing a well plan for a drilling operation; receiving information obtained from one or more sensors during the drilling operation, wherein the drilling operation comprises drilling a well during a first time interval; receiving information related to one or more drilling parameters for the drilling operation; automatically generating a video based on the well plan, the information obtained from one or more sensors, and the information related to one or more drilling parameters, the video comprising an animated or video illustration of the drilling operation within a predetermined time period, a plurality of metrics associated with the drilling operation as provided by the drill plan, and a summary of a planned activity for a drilling operation for a future predetermined time period; saving the video on a server connected to a network; providing the video to at least one user; providing instructions to a steering control system based on the video and controlling drilling equipment or a drilling operation based on the video.

[0490] Illustration 103. A system comprising: one or more processors; a memory f...

Claims

[0532] WHAT IS CLAIMED IS :

1. A system comprising: one or more processors; and a memory for storing instructions that when executed by the one or more processors perform operations comprising: receiving information from a well plan for a drilling operation of a well being drilled; receiving information obtained from one or more sensors coupled to a drilling rig during a drilling of the well; automatically generating a video based on the well plan, the information obtained from one or more sensors, and the information from one or more third party service providers, wherein the video comprises: a depiction of the drilling operation within a predetermined time period; a plurality of metrics associated with the drilling operation; and a summary of a planned activity for a drilling operation for a future predetermined time period; automatically saving the video on a server connected to a network; and automatically providing the video to at least one user.

2. The system of claim 1, wherein the information from the one or more sensors comprises one or more of location of a bottom hole assembly (BHA), coupled to a drill string located in the well, inclination of the BHA, azimuth of the BHA, wellbore trajectory, toolface orientation, RPM, torque, differential pressure, mud flow rate, ROP, mechanical specific energy, gamma ray, resistivity, neutron density, contents of the drilling mud, rock characteristictics, and / or WOB.

3. The system of claim 1, wherein the plurality of metrics comprises two or more of toolface orientation, MWD, WOB, ROP, RPM, torque, mud flow rate, mechanical specific energy, trajectory, slide drilling operations, rotary drilling operations, curvature, vibration, accelerations, other drilling dysfunctions, differential pressure, performance metrics based on the well plan, geological formations, logging, distance drilled, or combinations thereof.

4. The system of claim 1, further comprising receiving information from one or more third party service vendors , wherein the information associated from the one or more third party service vendors comprises information associated with well logs, location of a bottom hole assembly (BHA), coupled to a drill string located in the well, inclination of the BHA, azimuth of the BHA, wellbore trajectory, toolface orientation, RPM, torque, differential pressure, mud flow rate, ROP, mechanical specific energy, gamma ray, resistivity, neutron density, contents of the drilling mud, rock characteristictics, and / or WOB.

5. The system of claim 1, wherein the summary of planned activity comprises one or more of: continuing of planned drilling parameters, continuing of adjusted drilling parameters, geological formations, changes or a modification to drilling operations, one or more parameters included in the drill parameters, one or more parameters adjusted from those included in the well plan, location of a bottom hole assembly (BHA), coupled to a drill string located in the well, inclination of the BHA, azimuth of the BHA, wellbore trajectory, toolface orientation, RPM, torque, differential pressure, mud flow rate, ROP, mechanical specific energy, gamma ray, resistivity, neutron density, contents of the drilling mud, rock characteristictics, and / or WOB.

6. The system of claim 1, wherein the planned activity further comprises: identifying a corrective action based on the well plan, the information obtained from one or more sensors, and the information from one or more third party service providers; and generating the video with the corrective action as at least one planned activity for the drilling operation for the future predetermined time period.

7. The system of claim 1, wherein the drilling further further comprises: identifying the occurrence of an event or condition based on the well plan, the information obtained from one or more sensors, and the information from one or more third party service providers; determining a control response for the event or condition; and generating the video with the control response.

8. The system of claim 1 , wherein the depiction comprises a three-dimensional rendering of the drilling operation.

9. The system of claim 1, further comprising receiving information from one or more third party service vendors providing one or more services for drilling the well by receiving the information via a plurality of application programming interfaces that connect the one or more processors to one or more control systems coupled to a drilling rig that is drilling the well.

10. The system of claim 1, wherein generating the video comprises automatically generating the video with audio narration regarding the drilling operation.

11. The system of claim 1 , wherein automatically providing the video to at least one user comprises: receiving a designated file format for the video from the at least one user or automatically determining the designated file format based on the at least one user; generating the video in the designated file format specified for the at least one user; and providing the video to the at least one user.

12. The system of claim 1, wherein generating the video further comprises generating one or more selectable links to drilling data generated during the predetermined time period and embedding them in the video.

13. The system of claim 12, wherein the one or more selectable links is at least one hyperlink, and wherein automatically providing the video to the at least one user comprises transmitting the at least one hyperlink via at least one of: an email message, a text message, and a chat message.

14. The system of claim 1, wherein generating the video comprises generating the video with one or more metatags associated with information in the video, and wherein the one or more metatags comprise at least one of the following metatags: a well identifier; a pad identifier; a field identifier; a date identifier; a bottom hole assembly identifier; a drill bit identifier; an owneror operator identifier; a depth identifier; a geological formation identifier; an incident or event identifier; a result identifier; a personnel identifier; and a rig identifier.

15. The system of claim 1, wherein generating the video comprises generating the video with a length of less than 30 seconds in duration.

16. The system of claim 1, wherein generating the video comprises generating the video with a length in a range from 30 seconds to 3 minutes.

17. The system of claim 1, wherein generating the video comprises: receiving a maximum video length from the at least one user; and generating the video such that video comprises a duration of less than or equal to the maximum video length.

18. The system of claim 1, wherein generating the video comprises: determining a maximum video length based on a type of the at least one user; and generating the video such that video comprises the duration of less than or equal to the maximum video length.

19. The system of claim 1, further comprising a video database, wherein the video database is searchable by key words and comprises a plurality of reports, each associated with a well.

20. The system of claim 1, wherein the system, in response to a user search or user request, generates a second video with modified information, and wherein the modified information is responsive to the user search or user request.

21. The system of claim 1, wherein the system, in response to a user search or user request, automatically generates and sends a response to the user search or user request.

22. The system of claim 21 , wherein the response to the user search or request comprises a second video, a text response, and / or an audio response.

23. The system of claim 1, wherein the instructions further comprise instructions for accessing information associated with one or more offset wells and incorporating information associated with the one or more offset wells in the video, wherein the informaiton associate with one or more offset wells comprises at least well log information.

24. The system of claim 23, wherein the one or more offset wells comprise one or more composite wells and / or one or more technical limit wells.

25. The system of claim 1, wherein the summary of planned activity comprises a depiction of a future drilling operation for a future predetermined time period.

26. The system of claim 1, wherein the operations further comprise: receiving a first file size for the video from the at least one user; sending the video to the at least one user with the video having less than or equal to the first file size; and automatically storing the video having a second file size larger than first file size in a storage system; and sending a selectable link to access the video having the second file size to the at least one user.

27. The system of claim 1, wherein the operations further comprise: receiving a first file type for the video from the at least one user; sending the video to the at least one user with the video the first file type; and automatically storing the video having a second file type different from the first file type in a storage system; and sending a selectable link to access the video having the second file type to the at least one user.

28. A method performed by a computer system, the method comprising,accessing, by the computer system, a well plan for drilling a well; receiving, by the computer system, information from one or more sensors during drilling of a well and a plurality of drilling parameters for drilling the well during the first time interval; automatically generating, by the computer system, a video based on the well plan, the information obtained from one or more sensors, and the information related to one or more drilling parameters, wherein the video comprises a depiction of the drilling of the well during a predetermined time period, a plurality of metrics associated with the drilling, and a summary of planned drilling activity for drilling the well for a future predetermined time period; automatically saving, by the computer system, the video in a database on a server connected to a network; and automatically providing, by the computer system, each of a plurality of users a copy of the video, wherein the copy received by each user is generated responsive to input from that user, wherein the input from the user comprises one or more of a duration of the video, a file size of the video, a file format of th evideo, and / or content of the video.

29. The method of claim 28, wherein receiving the plurality of drilling parameters comprises receiving the plurality of drilling parameters from a plurality of application programming interfaces that connect the computer systems to one or more drilling systems coupled to a drilling rig that performs the drilling.

30. The method of claim 28, wherein providing the video to at least one user comprises: receiving a desired file format for the video from the at least one user or automatically determining the desired file format based on the at least one user; generating the video in the desired filed format; generating a hyperlink to the video; and transmitting the hyperlink to the video to the at least one user.

31. The method of claim 28, wherein the generating the video comprises generating the video such that the video is configured to change in response to user input to allowthe user to manipulate the display presented to the user, thereby allowing the user to view a display of the illustration from any one of 360 degrees.

32. The method of claim 31, wherein the generating the video comprises generating the video such that the video is configured to allow a user to freeze the video, fast forward the video, reverse the video, and / or to add tags to the video, wherein the tags are associated with the video in a searchable database for searching.

33. The method of claim 28, wherein the generating the video comprises generating the video with hyperlinks to drilling data.

34. The method of claim 33, wherein a hyperlink to the video is transmitted via at least one of an email message, a text message, and a chat message.

35. The method of claim 28, further comprising: accessing, by the computer system, information associated with one or more offset wells and incorporating information associated with the one or more offset wells in the video.

36. The method of claim 35, wherein the one or more offset wells comprise one or more composite wells and / or one or more technical limit wells.

37. A non-transitory, computer readable medium storing instructions that when executed cause one or more processors to perform operations, the operations comprising: accessing a well plan for a drilling operation of a well being drilled; receiving information obtained from one or more sensors coupled to the drilling rig during a drilling of the well; receiving information from one or more third party service vendors providing one or more services for drilling the well; automatically generating a video based on the well plan, the information obtained from one or more sensors, and the information from one or more third party service vendors, wherein the video comprises: a depiction of the drilling operation within a predetermined time period; a plurality of metrics associated with the drilling operation; anda summary of a planned activity for a drilling operation for a future predetermined time period; automatically saving the video on a server connected to a network; and automatically providing the video to at least one user.

38. The non-transitory computer readable medium of claim 37, wherein providing the video to at least one user comprises: receiving a desired fde format for the video from the at least one user or automatically determining the desired file format based on the at least one user; generating the video in the desired filed format; generating a hyperlink to the video; and transmitting the hyperlink to the video to the at least one user.

39. The non-transitory computer readable medium of claim 37, wherein the instructions further comprise instructions for transmitting a link to the video within a preset time following the end of operations.

40. The non-transitory computer readable medium of claim 37, wherein a hyperlink to the video is transmitted via at least one of an email message, a text message, and a chat message, and therein the hyperlink transmitted comprises a hyperlink to a file format associated with a user that receives the hyperlink.

41. The non-transitory computer readable medium of claim 37, wherein the instructions further comprise instructions for: receiving a first file size for the video from the at least one user; sending the video to the at least one user with the video having less than or equal to the first file size; and automatically storing the video having a second file size larger than first file size in a storage system; and sending a selectable link to access the video having the second file size to the at least one user.

42. The non-transitoiy computer readable medium of claim 37, wherein the instructions further comprise instructions for: receiving a first file type for the video from the at least one user; sending the video to the at least one user with the video the first file type; and automatically storing the video having a second file type different from the first file type in a storage system; and sending a selectable link to access the video having the second file type to the at least one user.

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