System and method of automating a slide drilling operation

#At the outset of a drilling operation, drillers typically establish a drilling plan that includes a target location and a drilling path to the target location. Once drilling commences, the bottom hole assembly is directed or “steered” from a vertical drilling path in any number of directions, to follow the proposed drilling plan. For example, to recover an underground hydrocarbon deposit, a drilling plan might include a vertical well to a point above the reservoir, then a directional or horizontal well that penetrates the deposit. The operator may then steer the bit through both the vertical and horizontal aspects in accordance with the plan.

#In some embodiments, such directional drilling requires accurate orientation of a bent segment of the downhole motor that drives the bit. In such embodiments, rotating the drill string changes the orientation of the bent segment and the toolface and can also cause torque to become trapped in the drill string. Thus, a transition from rotating drilling to slide drilling requires multiple steps to properly orient the bent segment and the toolface. This typically requires the operator to manipulate the drawworks brake, and rotate the rotary table or top drive quill to find the precise combinations of hook load, mud motor differential pressure, and drill string torque, to properly position the toolface. This can be difficult, time consuming, and complex. Each adjustment has different effects on the toolface orientation, and each must be considered in combination with other drilling requirements to drill the hole. Thus, transitioning from rotating drilling to slide drilling is very complex, labor intensive, and often inaccurate process. A more efficient, reliable method for executing sliding instructions is needed.

#In one example aspect, the present disclosure is directed to a method of automating a slide drilling operation that includes a plurality of tasks, the method including presenting selectable indicators, on a graphical user interface, wherein each selectable indicator is associated with one task from the plurality of tasks related to the slide drilling operation; wherein the graphical user interface is operably coupled to a controller that is in communication with drilling equipment, wherein the controller is configured to: receive data from the drilling equipment; and control the operation of at least a portion of the drilling equipment using a predetermined workflow and task parameters; and wherein each task is associated with at least one predetermined workflow; receiving by the controller a first selection command associated with a first selectable indicator presented on the graphical user interface, a first task, and a first predetermined workflow; presenting on the graphical user interface, in response to the receipt of the first selection command, a first dialogue box for receiving a first plurality of task parameters associated with the first predetermined workflow; receiving, using the first dialogue box, the first plurality of task parameters; and executing, using the controller and at least a portion of the drilling equipment, the first task using the first predetermined workflow and the first plurality of task parameters. In some embodiments, the plurality of tasks includes one or more of: removing trapped torque from a drill string; auto-oscillating the drill string; tagging bottom using the drill string; obtaining a target toolface angle; maintaining the target toolface angle; and evaluating a slide drilling operation. In some embodiments, the method also includes: automatically presenting the selectable indicators on the graphical user interface during or after the execution of the first task; receiving by the controller a second selection command associated with: a second selectable indicator of the selectable indicators; a second task; and a second predetermined workflow; presenting on the graphical user interface, in response to the receipt of the second selection command, a second dialogue box configured to receive a second plurality of task parameters; receiving, using the second dialogue box, the second plurality of task parameters; and automatically executing, using the controller and at least a portion of the drilling equipment, the second task using the second predetermined workflow and the second plurality of task parameters. In some embodiments, the first task is removing trapped torque from a drill string that is coupled to a bottom hole assembly used in the slide drilling operation; the first task of removing trapped torque from the drill string is associated with a workflow to move the drill string vertically in first and second opposing directions, and with a workflow to rotate the drill string; wherein the method further includes: presenting, on the graphical user interface, a second dialogue box for receiving a second selection command selecting the workflow to move the drill string vertically as the first predetermined workflow or the workflow to rotate the drill string as the first predetermined workflow; and receiving, by the controller, the second selection command; wherein, when the workflow to move the drill string vertically in the first and second opposing directions is the first predetermined workflow, the first plurality of task parameters includes: a speed at which the drill string is to be moved vertically in the first and second opposing directions; a number of repetitions of moving the drill string vertically in the first and second opposing directions; or a vertical distance over which the drill string is to be moved vertically in the first and second opposing directions with each repetition; and wherein, when the workflow to rotate the drill string is the first predetermined workflow, the first plurality of task parameters includes a number of rotations of the drill string. In some embodiments, the second selection command selects the workflow to rotate the drill string as the first predetermined workflow; wherein the drilling equipment includes a top drive; and wherein executing the first task using the first predetermined workflow and the first plurality of task parameters includes automatically rotating, in response to the receipt of the second selection command and first plurality of task parameters, the drill string the number of rotations using the top drive. In some embodiments, the second selection command selects the workflow to move the drill string vertically as the first predetermined workflow; wherein the drilling equipment includes a drawworks; and wherein executing the first task using the first predetermined workflow and the first plurality of task parameters includes automatically lifting the drill string, in response to the receipt of the second selection command and the first plurality of task parameters, the vertical distance at the speed for the number of repetitions using the drawworks. In some embodiments, the drilling equipment further includes a top drive brake, wherein the workflow to move the drill string vertically as the first predetermined workflow also includes releasing the top drive brake; and wherein executing the first task using the first predetermined workflow and the first plurality of task parameters further includes automatically releasing the top drive brake. In some embodiments, the first task is auto-oscillating the drill string, wherein the drilling equipment includes: a top drive, and a weight on bit sensor; wherein the first plurality of task parameters includes measuring a minimum weight on bit threshold measurement; wherein the method further includes: receiving, by the controller, data from the weight on bit sensor; determining, using the data from the weight on bit sensor and the controller, an estimated weight on bit; and wherein executing the first task using the first predetermined workflow and the first plurality of task parameters includes automatically oscillating the drill string, using the top drive, upon the controller determining that the estimated weight on bit exceeds the minimum weight on bit threshold measurement. In some embodiments, the drilling equipment includes: a bottom hole assembly (“BHA”) coupled to a drill string that extends within a wellbore; a toolface sensor coupled to the BHA; and a top drive configured to rotate the drill string at the surface of the wellbore, wherein the first task is tagging bottom using the BHA; wherein the first plurality of task parameters includes a drill string rotation parameter; wherein executing the first task using the first predetermined workflow and the first plurality of task parameters includes: receiving, by the controller and from the toolface sensor, data associated with a first estimated toolface angle of the BHA while the BHA is off-bottom of the wellbore; determining, by the controller and based on the data associated with the first estimated toolface angle of the BHA, the first estimated toolface angle while the BHA is off-bottom; determining while the BHA is off-bottom, by the controller, a target toolface angle of the BHA; calculating, by the controller, a first difference measured in a clockwise direction between the target toolface angle and the first estimated toolface angle; when the first difference is greater than 180 degrees, calculating, by the controller, an adjusted drill string rotation parameter using a first rule and the drill string rotation parameter; when the first difference is equal to or less than 180 degrees, calculating, by the controller, the adjusted drill string rotation parameter using a second rule and the drill string rotation parameter; rotating, by the controller and using the top drive, the drill string by the adjusted drill string rotation parameter while the BHA is off-bottom; and tagging bottom, using the BHA, after rotating the drill string by the adjusted drill string rotation parameter. In some embodiments, the first rule includes adding the drill string rotation parameter to a second difference between 360 degrees and the first difference; and wherein the second rule includes subtracting the first difference from the drill string rotation parameter. In some embodiments, the drill string rotation parameter is defined by a number of rotations of the drill string in a first direction. In some embodiments, the drilling equipment further includes: a bottom hole assembly (“BHA”) coupled to a drill string that extends within a wellbore; a toolface sensor coupled to the BHA; and a top drive configured to rotate the drill string at the surface of the wellbore; wherein the first task is either obtaining a target toolface angle or maintaining toolface the target toolface angle during the slide drilling operation; wherein the first plurality of task parameters includes a selected period of time; wherein, executing, using the controller and the drilling equipment, the first task using the first predetermined workflow and the first plurality of task parameters includes: receiving, by the controller and from the toolface sensor, first drilling data from the BHA; determining, by the controller and using the first drilling data, a first estimated toolface angle of the BHA; determining, by the controller, if the first estimated toolface angle of the BHA is within a threshold deviation from the target toolface angle; when the first estimated toolface angle is not within the threshold deviation, then incrementing a count of a toolface counter from zero to one; receiving, by the controller and from the toolface sensor, second drilling data from the BHA; determining, by the controller and using the second drilling data, a second estimated toolface angle of the BHA; determining, by the controller, if the second estimated toolface angle of the BHA is within the threshold deviation from the target toolface angle; and when the second estimated toolface angle is not within the threshold deviation and the toolface counter is at one, then determining whether a difference between the first estimated toolface angle and the second estimated toolface angle, measured in a clockwise direction from the first estimated toolface angle is between 20 degrees and 180 degrees; when the difference is not between 20 degrees and 180 degrees, then pausing, using the controller and the top drive, rotation of the drill string for the selected period of time; and when the difference is between 20 degrees and 180 degrees, then resetting the count of the toolface counter to zero. In some embodiments, the threshold deviation includes: up to 60 degrees measured in the counterclockwise direction from the target toolface angle; and up to 120 degrees measured in a clockwise direction from the target toolface angle. In some embodiments, the selected period of time is about 10 seconds. In some embodiments, the drilling equipment further includes a mud pump; and wherein pausing drilling activities further includes ceasing operation of the mud pump. In some embodiments, pausing drilling activities reduces a downhole pressure differential In some embodiments, the plurality of tasks includes: a first task of removing trapped torque from a drill string; a second task of auto-oscillating the drill string; a third task of tagging bottom using the drill string; a fourth task of obtaining a target toolface angle; a fifth task of maintaining a toolface angle during the slide drilling operation; and a sixth task of evaluating a slide drilling operation; and wherein the method further includes automatically executing, using the controller and at least a portion of the drilling equipment: the fifth task after completion of the fourth task; the fourth task after completion of the third task; the third task after completion of the second task; or the second task after completion of the first task.

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

#FIG. 1 is a schematic diagram of a drilling rig apparatus according to one or more aspects of the present disclosure.

#FIG. 2A is another schematic diagram of a portion of the drilling rig apparatus of FIG. 1, according to one or more aspects of the present disclosure, the portion of the drilling rig apparatus including a graphical user interface (“GUI”).

#It is to be understood that the present disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Moreover, the formation of a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.

#The systems and methods disclosed herein automate the execution of sliding instructions, resulting in increased efficiently and speed during slide drilling compared to conventional systems that require significantly more manual input or pauses to provide for input. The invention can advantageously achieve this through the use of data feedback and location detection, processing received data, creating a stand-by-stand drilling plan, and executing automatically the stand-by-stand drilling plan. Prior to drilling, a target location is typically identified and an optimal wellbore profile or planned path is established. Such proposed drilling paths are generally based upon the most efficient or effective path to the target location or locations. As drilling proceeds, the systems and methods disclosed herein determine the position of the BHA, record and analyze results of surveys, create a plan for a next stand, and execute the plan for the next stand. Executing the plan for the next stand includes automatically executing, using the system, an automated slide sequence. Thus, the system and methods disclosed herein automate the execution of sliding instructions.

#Referring to FIG. 1, illustrated is a schematic view of apparatus 100 demonstrating one or more aspects of the present disclosure. The apparatus 100 is or includes a land-based drilling rig. However, one or more aspects of the present disclosure are applicable or readily adaptable to any type of drilling rig, such as jack-up rigs, semisubmersibles, drill ships, coil tubing rigs, well service rigs adapted for drilling and/or re-entry operations, and casing drilling rigs, among others within the scope of the present disclosure.