Well planning for automated execution

Abstract

Methods, systems, and computer readable media for establishing well plans. The method includes receiving one or more design conditions for a well; determining one or more design elements selected from the group consisting of the design trajectory, the downhole component, and the drilling fluid; analyzing a system including the one or more design elements based on the one or more design conditions; and determining system pass. The method also includes constructing a well plan including a well trajectory, equipment, and drilling operations in response to determining that the system passes.

Description

[0001] This application is a divisional application of the invention patent application with the application date of April 17, 2015, the application number of 201510185455.X, and the invention name of "Well Planning for Automatic Execution". Background Art

[0002] Well planning is a procedure according to which the path of a well is planned in order to reach a reservoir and achieve the ultimate goal of economically extracting fluids from the reservoir. Usually, constraints are imposed on the design of the wellbore. Such constraints can be imposed by known geological conditions in the subsurface domain or the presence of other wells in the area (e.g., collision avoidance). Other constraints can be imposed by the capabilities of the tools used. Still other constraints can be related to drilling time and risk tolerance.

[0003] Generally, well planning is created based on constraints and known information. The well plan is then provided to the well owner, approved, and then implemented by a drilling service provider (e.g., a directional driller or "DD"). Well design software may not directly or comprehensively consider the capabilities of the envisioned drilling system. Therefore, it may be required that drilling engineers take these capabilities into account when creating various designs and specifications. In some cases, the software allows users to input limitations, and the system will warn the user if those limitations are exceeded. Brief Description of the Drawings

[0004] The drawings included in this specification and constituting a part of the specification illustrate embodiments of the present teachings together with the specification and are used to explain the principles of the present teachings. In the drawings:

[0005] Figure 1 A schematic diagram showing the workflow of a distributed collaborative well planning platform according to one embodiment is shown.

[0006] Figure 2 A flowchart showing a method for planning and drilling according to one embodiment is shown.

[0007] Figure 3 A flowchart showing the workflow for well planning according to one embodiment is shown.

[0008] Figure 4 A flowchart showing the workflow for well planning that can employ an automatic rig according to one embodiment is shown.

[0009] Figure 5 A schematic diagram of a computing system according to one embodiment is shown. Detailed Description of the Embodiments

[0010] Next, reference will be made in detail to the embodiments, examples of which are illustrated in the accompanying drawings. In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the present invention. However, it will be apparent to those skilled in the art that the present invention may be practiced without these specific details. In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.

[0011] It will also be understood that although terms such as "first," "second," etc. may be used herein to describe various elements, these elements should not be limited by these terms. These terms are only used to distinguish one element from another. For example, a first object or step could be named a second object or step, and similarly, a second object or step could be named a first object or step, without departing from the scope of the present invention. The first object or step and the second object or step are both objects or steps, but they should not be considered the same object or step.

[0012] The terms used in the description of the present invention are merely for the purpose of describing particular embodiments and should not be regarded as limiting the present invention. As used in the description and claims of the present invention, the singular forms "a" and "the" are intended to also include the plural forms, unless expressly stated otherwise. It will also be understood that the term "and / or" as used herein refers to and encompasses any and all possible combinations of one or more of the associated listed items. It should also be understood that the terms "comprises" and "comprising" used in this specification mean that there are the stated features, integers, steps, operations, elements, and / or components, and do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and / or combinations thereof. In addition, the term "if" as used herein may be construed to mean "when," "once," or "in response to determining" or "in response to detecting," depending on the context.

[0013] Next, attention will be directed to processing procedures, methods, techniques, and workflows according to some embodiments. Some of the operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined, and / or the order of some of the operations may be changed.

[0014] Figure 1FIG. 100 is a schematic diagram showing a workflow for a distributed collaborative well planning platform according to one embodiment. The workflow 100 may be implemented as or by computer software, hardware, or a combination thereof. For example, a server may maintain one or more databases, data files, etc., which may be accessed and modified by one or more client computers, for example, using a web browser, a remote terminal, etc. Moreover, a client computer may modify a database or data file online, and / or may include a "sandbox" that may allow the client computer to modify at least a portion of the database or data file offline without affecting the database or data file as seen by other client computers. The client computer executing the "sandbox" may then modify the database or data file after completing the operations in the sandbox.

[0015] In some examples, the client and / or server computing systems may be in remote locations relative to each other, and / or may each include two or more remote processing units. As used herein, two systems are in a "remote" location relative to each other if they are not physically adjacent to each other. For example, depending on the circumstances, two devices located on different sides of a room, in different rooms, in different buildings, in different cities, different countries, etc., may be considered remote. In some embodiments, two or more of the client computing systems may be adjacent to each other, and / or one or more of the client computing systems and the server may be adjacent to each other.

[0016] It will be appreciated that various aspects of the following workflow 100 may be completed automatically, may be implemented partially automatically, or may be completed manually, for example, by a user interacting with a software application. Moreover, the workflow 100 may be cyclic and, as an example, may include four phases: evaluation 101-1, planning 101-2, engineering 101-3, and execution 101-4. Although these phases are numbered sequentially, the workflow 100 may start at any position in the schematic diagram shown. As a convenient example, the workflow 100 is described herein as starting with an evaluation 101-1, which may include, for example, a geological service provider 102 evaluating a formation at reference numeral 104. The geological service provider 102 may perform a formation evaluation at reference numeral 104 using a computing system executing a software package suitable for the operation. However, any other suitable geological platform may also be employed. Accordingly, the geological service provider 102 may evaluate the formation, for example, using geological models, geophysical models, basin models, rock composition models, combinations thereof, and / or similar models. Such models may consider a variety of different inputs, including offset well data, seismic data, pilot well data, other geological data, etc. The model and / or the inputs may be stored in a database maintained by the server and accessed by the geological service provider 102.

[0017] Workflow 100 may then proceed to a geological and geophysical (“G&G”) service provider 106, which may generate a well trajectory, e.g., at reference numeral 108. The operation of generating the well trajectory at reference numeral 108 may be implemented by executing one or more G&G software packages. Examples of such software packages include which may be obtained in the market from Schlumberger. The G&G service provider 106 may determine the well trajectory or a portion of the well trajectory, e.g., based on models and / or other data provided by the formation evaluation at reference numeral 102 (e.g., obtained from a database maintained by the server). The well trajectory may take into account various “basic design” (BOD) constraints, e.g., overall surface location, target (e.g., reservoir) location, etc. The trajectory may also incorporate information regarding tools, bottom hole assemblies, casing sizes, etc. that may be used in the drilling. The well trajectory determination may also consider a variety of other parameters, including: risk tolerance, fluid weight and / or planning, bottom hole pressure, drilling time, etc.

[0018] Workflow 100 may proceed to a first engineering service provider 110 (e.g., one or more processing machines associated therewith), which may verify the well trajectory and relief well design, e.g., at reference numeral 112. Such verification at reference numeral 112 may include evaluating physical properties, computational results, risk tolerance, integration with other aspects of workflow 100, etc. The parameters determined for this may be maintained by the server and / or the first engineering service provider 110; similarly, the models, well trajectories, etc. may be maintained by the server and may be accessed by the first engineering service provider 110. For example, the first engineering service provider 110 may include one or more computing systems that execute one or more software packages. If the first engineering service provider 110 rejects the well trajectory or otherwise recommends an adjustment to the well trajectory, the well trajectory on the server may be adjusted or a message or other notification may be sent to the G&G service provider 108 requesting such modification.

[0019] The first engineering service provider 110 or one or more second engineering service providers 114 may provide, e.g., at reference numeral 116, a casing design, bottom hole assembly design, fluid design (planning), and / or similar designs to implement the well trajectory. In some embodiments, the second engineering service provider 114 may perform such designs using one or more software applications. Such designs may be stored in a database maintained by the server, which may employ and may be accessed by one or more of the other service providers in workflow 100.

[0020] The second engineering service provider 114 may seek confirmation of the design established along with the well trajectory from the third engineering service provider 118. The third engineering service provider 118 may consider various factors to judge whether the well engineering plan is acceptable, such as economic variables (e.g., oil production forecast, cost per barrel of oil, risk, drilling time, etc.), and may request authorization of the cost, for example, at reference numeral 120, from representatives of the operating company, representatives of the well owner, etc. At least some of the data on which such determination is based may be stored in a database maintained by the server. It is understood that the first, second, and / or third engineering service providers 110, 114, 118 may be provided by a single engineering team or even a single engineer, and thus may or may not be separate entities.

[0021] If it is not economically acceptable or the authorization is rejected for other reasons, the third engineering service provider 118 may recommend changes to the casing, well bottom, and / or fluid design, or otherwise notify and / or return control to the second engineering service provider 114, such that the second engineering service provider 114 may adjust the casing, well bottom, and / or fluid design. If it is not feasible to modify one or more of these designs within the well constraints, trajectory, etc., the second engineering service provider 114 may recommend adjusting the well trajectory and / or the workflow 100 may return to or otherwise notify the first engineering service provider 110 and / or the G&G service provider 106, such that either or both may modify the well trajectory at reference numeral 106.

[0022] The workflow 100 may also include considering the well trajectory at the second geological service provider 122, including the accepted well engineering plan and formation evaluation, and the second geological service provider 122 may be the same or a different entity from the first geological service provider 108. Moreover, the workflow 100 may then transfer control to the drilling service provider 126, and the drilling service provider 126 may implement the well engineering plan, for example, at reference numeral 128, to establish safe and efficient drilling, maintain well integrity, report progress, and operating parameters. Moreover, the operating parameters, the formations encountered, the data collected during drilling (e.g., using logging-while-drilling or measurement-while-drilling techniques) may be returned to the geological service provider 122 for evaluation. The geological service provider 122 may then re-evaluate the well trajectory or any other aspect of the well engineering plan, and may, in some cases and potentially within predetermined constraints, adjust the well engineering plan based on the actual drilling parameters.

[0023] According to certain embodiments, regardless of whether the well is fully drilled or only a part thereof is completed, the workflow 100 can proceed to a post-review, such as at reference numeral 130 in the drawings. As shown at reference numeral 132, the post-review 130 can include a review of the drilling performance, e.g., the drilling performance reported at reference numeral 128. Additionally, as shown at reference numeral 132, the post-review 130 can also include reporting the drilling performance, e.g., to relevant engineering design, geological, or G&G service providers.

[0024] However, in some embodiments, the operations described above as part of the workflow 100 may not be performed sequentially, but rather out of order, e.g., partially based on information from templates, nearby wells, etc., to fill in any gaps in the information to be provided by another service provider. Also, performing one operation can affect the results or the basis for another operation, such that changes may be required, either manually or automatically, in one or more of the operation results in the workflow 100. In cases where the server stores such information on a central database accessible to various service providers, such changes can be sought by communicating with the appropriate service providers, can be made automatically, or can otherwise be presented as suggestions to the relevant service providers. Different from a sequential and segmented working method, this can present an overall approach to well engineering workflows.

[0025] Moreover, in some embodiments, the cyclic workflow 100 can be repeated multiple times during the process of drilling a wellbore. For example, in an automated system, feedback from the drilling service provider 126 can be provided in real time or near real time, and the data obtained during the drilling process at reference numeral 128 can be fed to any other service provider, who can then adjust the segments of the workflow 100 accordingly. Since there may be dependencies in other areas of the workflow 100, such adjustments can be made throughout the workflow, e.g., in an automated manner. In some embodiments, the cyclic process can additionally or alternatively occur after achieving a certain drilling objective, e.g., after completing a section of the wellbore and / or after drilling the entire wellbore, or based on criteria such as daily, weekly, monthly, etc.

[0026] Generally, embodiments of the present disclosure can provide a design evaluator for evaluating a design, e.g., in a collaborative workspace, after one or more modifications to a well plan. Such modifications can cause changes in the parameters of other designs, which may result in other designs being outside of the design parameters. The design evaluator can manage or eliminate such "contradictions" or "conflicts" between the designs sent by different designers to the collaborative workspace. In one embodiment, a hierarchy can be established for each design element, e.g., based on roles, expertise, seniority, qualifications, employee experience, etc. For example, the design evaluator can then consider the conflicts and can prefer or select the design submitted by a designer with a higher position in the hierarchy for the design operation.

[0027] Figure 2 FIG. 2 shows a method 200 for planning and drilling according to one embodiment. Method 200 may include the interaction of two (or more) computing systems that may be operated by different users or the same user. Additionally, the two computing systems may be part of a single overall computing system (whether local, remote, distributed, etc.), or may be constituted, for example, by two or more separate computers operated by different entities.

[0028] In one embodiment, the two entities may be a well planning system 202 and a drilling system 204. The well planning system 202 may include one or more computing systems that execute software configured to generate a well plan. The drilling system 204 may also include one or more computing systems that execute software configured to generate a well plan. In one embodiment, the “engine” for generating the well plan may be the same in both systems 202, 204 such that the same well plan is generated for the same input. Thus, in certain embodiments, systems 202, 204 may be provided with constraints rather than a complete well plan.

[0029] Turning now to method 200, the well planning system 202 may receive “basic design” (BOD) constraints, as at reference numeral 206. The basic design constraints may include information regarding economics, risk tolerance, the presence of nearby wells, and / or similar aspects. Additionally, the BOD constraints may also include the surface location where the well is to start and the target subsurface location, such as a hydrocarbon reservoir, that the well is to reach.

[0030] Method 200 may also include receiving data collected based on nearby delineation wells, as at reference numeral 208. This data may provide an understanding of the geology and other conditions related to drilling, and thus may provide information, for example, regarding the build depth at which a vertical wellbore trajectory may transition to a horizontal trajectory.

[0031] This information may be used to generate points through which the wellbore may extend. The points, constraints, etc. may then be sent to a well planning engine that may use them to construct one or more well plans, as at reference numeral 210. The well planning engine may establish one or more such plans that satisfy the constraints. Additionally, the well planning engine may perform one or more simulations, as at reference numeral 212, based in part on the one or more well plans, for example in order to select one or more of the well plans for execution. The selected well plan may then be sent to the well owner for approval. Once approved, the well plan may be sent to the drilling system 204 for execution.

[0032] However, as described above, in some examples, well constraints (e.g., BOD constraints, as indicated by reference numeral 214) may be passed to substitute for full well planning. Since the drilling system 204 may operate using the same planning engine as the well planning system 202, the drilling system 204 may construct the same well plan based on the constraints. In other embodiments, the well plan may be transformed.

[0033] Method 200 may then proceed such that the drilling system 204 constructs one or more well plans using the same planning engine as the well planning system 202, as indicated by reference numeral 216. The drilling system 204 may then transform the well plan into execution instructions, as indicated by reference numeral 218. Such execution instructions may specify the operating parameters to be employed, such as weight on bit, steering parameters, time, depth, pipe size, etc., and may specify the order in which they are to be employed.

[0034] Method 200 may then include executing the well plan based on the execution instructions, as indicated by reference numeral 220. In some embodiments, the drilling system 204 may include drilling equipment that is proximate to or remote from the computing system of the drilling system 204. The drilling system 204 may be computer controlled, for example, to follow the execution instructions as well as the well plan.

[0035] During execution, method 200 may include receiving feedback from the drilling system, as indicated by reference numeral 222. Such feedback may be provided in the form of log records, drilling records, core samples, gas chromatography, etc. The feedback may then be used to determine whether to adjust the well plan, as indicated by reference numeral 224. For example, the drilling system 204 may compare the feedback with information known from offset wells, seismic data, etc. to determine whether the drilling will proceed as expected, e.g., using the same force levels, drilling times, etc., as predicted in the well plan. If not, method 200 may include adjusting the well plan based on the feedback at reference numeral 224 (e.g., a "yes" decision). Otherwise, the decision at reference numeral 224 may be "no", in which case method 200 may include continuing to execute the well plan (e.g., performing the drilling operation).

[0036] If the decision at reference numeral 224 is "yes", method 200 may proceed to determine whether the adjustment is outside a predetermined threshold, as indicated by reference numeral 226. The threshold may be different depending on the type of parameter being adjusted. For example, specific thresholds may be set for the distance the well may miss a point, maximum dogleg severity, different forces on the casing, bottom hole assembly, etc. Thus, when considering an adjustment, a trade-off may be made with the appropriate threshold. In some cases, the threshold adjustment may be zero, i.e., out of range if any adjustment is needed.

[0037] If the decision at reference numeral 226 is "yes", i.e., the adjustment is out of range, a new well can be planned and / or presented to the well owner for approval. Thus, method 200 can return to construct one or more well plans in well planning system 202, as at reference numeral 210. Such a new well plan can take into account the adjusted constraints, as provided by the feedback at reference numeral 222. Otherwise, method 200 can return to construct one or more well plans using the well planning engine executed on drilling system 204, as at reference numeral 216. The new well plan constructed at drilling system 204 can also take into account the real-world feedback for the adjustments determined at reference numeral 222.

[0038] Figure 3 A flowchart of a well design system according to one embodiment is shown. As shown, certain well engineering software can assist a user in designing a well and, for example, can specify the equipment that can be used to construct the well. The design and specification can be reviewed to ensure that the well can be drilled safely and successfully.

[0039] Similarly, an architect designs a house and specifies the materials that should be used to build the house. Just as an architect does not explicitly specify the specific operations of the construction workers, a drilling engineer may not explicitly specify the specific operations or drilling parameters that a driller should follow.

[0040] The drilling engineer creates a design and, in some cases, does not create a set of instructions for implementing the design. The drilling engineer may assume that the driller can follow the design and drill a well that matches the design.

[0041] When designing a well, the drilling engineer may make assumptions about the capabilities and / or behaviors of the driller and the available equipment. These assumptions can affect the design. For example, the drilling engineer may assume that the driller may build angle 200' higher than specified by the design. Thus, the drilling engineer may specify the build point 200' lower than it should be so that when the driller deviates from the design, the build point will be what the drilling engineer actually expects.

[0042] Figure 4 A flowchart of a workflow for well design for drilling by an automated system according to one embodiment is shown. An automated drilling system may have different characteristics compared to a human driller. These different characteristics can include:

[0043] 1. The system will attempt to drill the design without changing the design.

[0044] 2. The system will accept instructions, while a human driller would want to make decisions on how to drill.

[0045] 3. The system has the ability to handle designs, controls, and information at a very fine level that a human driller does not have.

[0046] Understanding these differences will enable the drilling engineer to create a detailed drilling plan that includes a well design suitable for automated drilling.

[0047] More particularly, as shown, the workflow may include receiving conditions from a customer or other source. This may include a variety of information such as wellhead location, geological target zones, geological environment, geomechanical rock properties, available drilling equipment, specifications of the rig, etc.

[0048] A partial description of the drilling system to be used for drilling may then be established. The functionality of the overall drilling system may be less than that of the control system. For example, the control system may be able to send commands to the bottom hole assembly (BHA) every minute, but the particular BHA being used may be able to change its configuration every five minutes. This may limit the overall functionality of the system to change BHA settings to no more frequently than every five minutes.

[0049] Additionally, a human driller may be regarded and modeled as a "control system". The input description may partially describe the overall drilling system since the design and planning procedures may specify various elements as part of the system. For example, the input description may include details about the rig (rather than about the bit).

[0050] The workflow may also include creating one or more designs for the various elements to be created. Additionally, the overall system may be analyzed and the drilling operation may be simulated. This results in a description of the operations necessary for drilling. These operations may include the sequence of operations and the parameters describing the operations, such as the planned weight on bit, rotational speed (revolutions per minute (RPM)), and / or mud weight.

[0051] The workflow may also include evaluating the proposed design, analysis, and simulation results against a variety of criteria, which may include initial requirements, best practices, economic objectives, or risks. If the design fails the evaluation, the design or the specification may be amended.

[0052] The workflow may also include creating a well plan. Creating a well plan may include providing a design for the well, including the trajectory. Creating a well plan may also include providing a description of the various components for constructing the well, such as casing depth and casing type. Creating a well plan may also include formulating or considering the equipment to be used for drilling, such as the BHA, bit, and drilling fluid. Creating a well plan may additionally include specifying the operations that may be implemented to create the well.

[0053] The evaluation criteria and the design, description, and operation can be different in the case of drilling using an automated system compared to the case of drilling by a human operator. Specific examples of the differences include: automated operations may require frequent changes in drilling parameters, the trajectory may require frequent changes in drilling parameters, and the planning may be at the possible technological limits to quickly identify problems or deviations according to the automated drilling system and take corrective actions (faster or better than what a human driller can do).

[0054] In addition, the drilling system may not have a control system. A human driller may control the drilling. In this case, the description of the drilling system may describe the ability and willingness of the human driller to perform specific operations. (For example, a human driller may only be willing to change the BHA configuration once per hour)

[0055] In some embodiments, the methods of the present disclosure may be performed by a computing system. Figure 5 An example of such a computing system 500 according to some embodiments is shown. The computing system 500 may include a computer or computer system 501A, which may be a separate computer system 501A or an arrangement of distributed computer systems. The computer system 501A includes one or more analysis modules 502 configured to perform various tasks according to some embodiments (such as one or more methods disclosed herein). To perform these various tasks, the analysis modules 502 execute alone or in cooperation with one or more processors 504 connected to one or more storage media 506. The processor 504 is also connected to a network interface 507 to enable the computer system 501A to communicate with one or more additional computer systems and / or computing systems on a data network 509, such as 501B, 501C, and / or 501D (it should be noted that the computer systems 501B, 501C, and / or 501D may or may not share the same architecture as the computer system 501A and may be located in different physical locations. For example, the computer systems 501A, 501B may be located in a processing facility while communicating with one or more computer systems (such as 501C and / or 501D) located in one or more data centers and / or in various countries on different continents).

[0056] The processor may include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, or other control or computing devices.

[0057] The storage media 506 may be implemented as one or more computer-readable or machine-readable storage media. It should be noted that although Figure 5In an example of an embodiment, the storage medium 506 is shown as being located within the computer system 501A. However, in certain embodiments, the storage medium 506 may be arranged within and / or on multiple internal and / or external attachments of the computer system 501A and / or additional computer systems. The storage medium 506 may include one or more different forms of memory devices including semiconductor memory devices such as dynamic or static random access memory (DRAM or SRAM), erasable and programmable read only memory (EEPROM), electronically erasable and programmable read only memory (EEPROM), and flash memory, magnetic media such as fixed disks, floppy disks, and removable disks, other magnetic media including magnetic tape, optical media such as compact discs (CDs) or digital video discs (DVDs), or other types of optical memory, or other types of storage devices. It should be noted that the instructions described above may be provided on a computer-readable or machine-readable storage medium, or alternatively, may be provided on multiple computer-readable or machine-readable storage media arranged in a large system that may have multiple nodes. Such computer-readable or machine-readable storage media or media are considered to be part of an article (or article of manufacture). An article or article of manufacture may refer to any single component or multiple components that are manufactured. The storage medium or media is located on a machine that runs machine-readable instructions, or at a remote site from which the machine-readable instructions can be downloaded over a network for execution.

[0058] In certain embodiments, the computing system 500 includes one or more well planning modules 508. In an example of the computing system 500, the computer system 501A includes the well planning module 508. In certain embodiments, a single well planning module may be used to perform some or all aspects of one or more of the embodiments disclosed herein. In alternative embodiments, multiple well planning modules may be used to perform some or all aspects of the methods herein.

[0059] It should be understood that the computing system 500 is merely an example of a computing system, and the computing system 500 may have more or fewer components than shown, may incorporate Figure 5 additional components not shown in the exemplary example, and / or the computing system 500 may have a different configuration or structure than Figure 5 that shown. Figure 5 The components shown include one or more signal processing and / or application specific integrated circuits, and may be implemented as hardware, software, or a combination of hardware and software.

[0060] In addition, the steps of the processing method described herein are implemented by running one or more functional modules on an information processing device such as a general-purpose processor or a dedicated chip, such as an ASIC, FPGA, PLD, or other suitable device. These modules, combinations of these modules, and / or their combinations with general hardware are all covered by the scope of protection of the present invention.

[0061] Importantly, it is necessary to realize that geological interpretations, models, and / or other interpretive aids can be refined in an iterative manner; this idea can be applied to the methods discussed above. This can include the use of feedback loops performed algorithmically, such as on a computer device (e.g., computing system 100, Figure 3 ) and / or through manual control by a user, who can make a decision by considering whether the settings for a given step, action, template, model, or curve have become accurate enough to be used to evaluate the three-dimensional geological structure.

[0062] The foregoing description has been presented for purposes of illustration with reference to specific embodiments. However, the above discussion is not intended to be exhaustive or to limit the invention to the precise form disclosed. Many modifications and variations are possible in light of the above teachings. In addition, the order in which the elements of the methods described herein are shown and described may be rearranged, and / or one or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principles of the invention and its practical application, so that those skilled in the art can best utilize the invention and various embodiments with various modifications for the particular uses contemplated. Other information supporting the disclosure is contained in the accompanying appendices.

Claims

1. A method for creating a well plan, comprising: Receiving one or more design conditions for a well; Determining one or more design elements selected from the group consisting of a design trajectory, a bottomhole assembly, and drilling fluid; Analyzing a system including the one or more design elements based on the one or more design conditions; Deciding to adjust the well plan in response to drilling feedback; Automatically determining whether the adjustment is within one or more tolerances; and And Based on the determination, where the adjustment is within one or more tolerances, automatically adjusting the well plan using a planning engine instead of simulation, and where the adjustment is not within one or more tolerances, automatically adjusting the well plan using simulation and a planning engine; If the system meets the one or more design conditions, then determining that the system passes; and Constructing a well plan including a well trajectory, equipment, and drilling operations in response to determining that the system passes.

2. The method according to claim 1, further comprising: Simulating drilling operations based on the one or more design conditions and the one or more design elements.

3. The method according to claim 2, wherein The simulation includes: Determining whether the controller of the drilling system implementing the drilling operation is manual or automatic; and Configuring different characteristics for the controller based on whether the controller is manual or automatic.

4. A computing system, comprising: One or more processors; And A memory system including one or more non-volatile computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations including: Receiving one or more design conditions for a well; Determining one or more design elements selected from the group consisting of a design trajectory, a bottomhole assembly, and drilling fluid; Analyzing a system including the one or more design elements based on the one or more design conditions; Deciding to adjust the well plan in response to drilling feedback; Automatically determining whether the adjustment is within one or more tolerances; and Based on the determination, where the adjustment is within one or more tolerances, automatically adjusting the well plan using a planning engine instead of simulation, and where the adjustment is not within one or more tolerances, automatically adjusting the well plan using simulation and a planning engine; If the system meets the one or more design conditions, then determining that the system passes; and Constructing a well plan including a well trajectory, equipment, and drilling operations in response to determining that the system passes.

5. The system according to claim 4, wherein, The operations further include: Simulating drilling operations based on the one or more design conditions and the one or more design elements.

6. The system according to claim 5, wherein The simulation includes: Determining whether the controller of the drilling system implementing the drilling operation is manual or automatic; and Configuring different characteristics for the controller based on whether the controller is manual or automatic.

7. A non-volatile computer-readable medium storing instructions that, when executed by at least one processor of a computing system, cause the computing system to perform operations, the operations including: Receiving one or more design conditions for a well; Determining one or more design elements selected from the group consisting of a design trajectory, a bottomhole assembly, and drilling fluid; Analyze a system including the one or more design elements based on the one or more design conditions; Decide to adjust the well plan in response to drilling feedback; Automatically determine whether the adjustment is within one or more tolerances; and Based on this determination, where the adjustment is within one or more tolerances, automatically adjust the well plan using the planning engine instead of simulation, and where the adjustment is not within one or more tolerances, automatically adjust the well plan using simulation and the planning engine; If the system meets the one or more design conditions, then determine that the system passes; and Construct a well plan including a well trajectory, equipment, and drilling operations in response to determining that the system passes.

8. The medium according to claim 7, wherein, The operations further include: simulating drilling operations based on the one or more design conditions and the one or more design elements.

9. The medium according to claim 8, wherein, The simulation includes: Determine whether the controller of the drilling system implementing the drilling operation is manual or automatic; and Configure different characteristics for the controller based on whether the controller is manual or automatic.

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