# US 12,590,527 B2 · Rotary steerable system advisor with autonomous mode > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 12,590,527 B2 - Document ID: US12590527B2 - Status: Granted - Kind: B2 - Application number: 18/910,191 - Filed: 2024-10-09 - Published: 2025-04-24 - Granted: 2026-03-31 - Earliest claimed: 2023-10-18 - Assignees: Schlumberger Technology Corporation - Applicants: Schlumberger Technology Corporation - Inventors: Samba Ba; Juan Carlos Fernandez - Web page: https://patentgrep.com/patent/US12590527B2 ## CPC - E21B 7/04: Directional drilling - E21B 44/00: Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions - E21B 7/06: Deflecting the direction of boreholes - E21B 47/024: of devices in the borehole (determining slope or direction of the borehole E21B47/022) - E21B 47/04: Measuring depth or liquid level - E21B 47/12: Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling - E21B 2200/20: Computer models or simulations, e.g. for reservoirs under production, drill bits - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## Abstract A method for steering a downhole tool to drill a wellbore in a subterranean formation includes receiving an initial wellbore plan for the downhole tool to drill through the subterranean formation. The method also includes receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan. The method also includes comparing the initial wellbore plan to the drilling data. The method also includes determining a downlink command to transmit to the downhole tool based upon or in response to the comparison. The method also includes determining an importance of the downlink command based upon the comparison. The method also includes determining a time to transmit the downlink command to the downhole tool. The time is determined based upon the importance of the downlink command. The method also includes transmitting the downlink command to the downhole tool at the determined time. ## Claims ### Claim 1 A method for steering a downhole tool to drill a wellbore in a subterranean formation, the method comprising: receiving an initial wellbore plan for the downhole tool to drill through the subterranean formation; receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan; comparing the initial wellbore plan to the drilling data; determining a downlink command to transmit to the downhole tool, wherein the downlink command is based upon or in response to the comparison; determining an importance of the downlink command based upon the comparison; determining a time to transmit the downlink command to the downhole tool, wherein the time is determined based upon the importance of the downlink command; and transmitting the downlink command to the downhole tool at the determined time. ### Claim 2 (depends on 1) The method of claim 1, wherein the initial wellbore plan comprises: a planned direction that the downhole tool is to drill at a plurality of different locations in the subterranean formation; and a planned curvature of the downhole tool to be achieved at the plurality of different locations. ### Claim 3 (depends on 2) The method of claim 2, wherein the drilling data comprises: a measured direction that the downhole tool is drilling at the plurality of different locations in the subterranean formation; a measured curvature of the downhole tool at the plurality of different locations; a measured depth of the downhole tool at the plurality of different locations; a measured number of rotations per minute (RPM) of the downhole tool at the plurality of locations; a measured rate of penetration (ROP) of the downhole tool at the plurality of different locations; a measured weight on a drill bit (WOB) of the downhole tool at the plurality of locations; a measured flow rate of a fluid being pumped into the wellbore when the downhole tool is at the plurality of different locations; a measured position of a block on a drilling rig at a surface when the downhole tool is at the plurality of different locations; settings of the downhole tool when the downhole tool is at the plurality of different locations, wherein the settings comprise a steering mode of the downhole tool, an orientation of a tool face of the downhole tool, a steering ratio of the downhole tool, a steering efficiency factor of the downhole tool, or a combination thereof; or a combination thereof. ### Claim 4 (depends on 3) The method of claim 3, wherein the comparison identifies that the downhole tool has encountered or is approaching an unplanned event that is not accounted for in the initial wellbore plan and/or the drilling data, wherein the unplanned event comprises a previous downlink command not being received by the downhole tool, the drilling data deviating from the initial wellbore plan by more than a predetermined threshold, or both, and wherein the drilling data deviating comprises the measured curvature differing from the planned curvature by more than the predetermined threshold. ### Claim 5 (depends on 1) The method of claim 1, wherein the time to transmit the downlink command is also based upon a measured rate of penetration (ROP) of the downhole tool. ### Claim 6 (depends on 1) The method of claim 1, further comprising displaying the downlink command to a user. ### Claim 7 (depends on 1) The method of claim 1, further comprising providing a user with a predetermined amount of time to accept or reject the downlink command, wherein the predetermined amount of time is based upon a time that an uplink command from the downhole tool is received at a surface and/or a frequency of data points in the drilling data. ### Claim 8 (depends on 7) The method of claim 7, wherein the predetermined amount of time expires before the determined time to transmit the downlink command to the downhole tool. ### Claim 9 (depends on 7) The method of claim 7, wherein the downlink command is transmitted by modulating a flow rate of a fluid being pumped into the downhole tool or a number of rotations per minute (RPM) of the downhole tool, and wherein the downlink command is transmitted in response to the user accepting the downlink command or not rejecting the downlink command. ### Claim 10 (depends on 1) The method of claim 1, wherein the downlink command causes the downhole tool to vary a direction that the downhole tool is drilling, a curvature of the downhole tool, a rate of penetration (ROP) of the downhole tool, a weight-on-bit (WOB) of the downhole tool, a flow rate of a fluid flowing through the downhole tool, or a combination thereof. ### Claim 11 A computing system, comprising: one or more processors; and a memory system coupled to the one or more processors and comprising one or more non-transitory 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 comprising: receiving an initial wellbore plan for a downhole tool to drill through a subterranean formation toward one or more targets; receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan; comparing the initial wellbore plan to the drilling data, wherein the comparison identifies that the downhole tool is approaching an unplanned event that is not accounted for in the initial wellbore plan and/or the drilling data; determining a downlink command to transmit to the downhole tool, wherein the downlink command is based upon or in response to the comparison; determining an importance of the downlink command based upon the comparison; determining a time to transmit the downlink command to the downhole tool, wherein the time is determined based upon the importance of the downlink command; and transmitting the downlink command to the downhole tool at the determined time. ### Claim 12 (depends on 11) The computing system of claim 11, wherein the unplanned event comprises the drilling data deviating from the initial wellbore plan by more than a predetermined threshold, and wherein the drilling data deviating comprises a measured curvature differing from a planned curvature by more than the predetermined threshold. ### Claim 13 (depends on 11) The computing system of claim 11, wherein the operations further comprise providing a user with a predetermined amount of time to accept or reject the downlink command. ### Claim 14 (depends on 13) The computing system of claim 13, wherein the predetermined amount of time is based upon a time that an uplink command from the downhole tool is received at a surface and/or a frequency of data points in the drilling data, and wherein the predetermined amount of time expires before the determined time to transmit the downlink command to the downhole tool. ### Claim 15 (depends on 11) The computing system of claim 11, wherein the downlink command is transmitted by modulating a flow rate of fluid flowing through the downhole tool or a number of rotations per minute (RPM) of the downhole tool, wherein the downlink command is transmitted in response to a user accepting the downlink command or not rejecting the downlink command, wherein the downlink command causes the downhole tool to vary a technique that the downhole tool uses to process measurements that are captured by the downhole tool, wherein varying the technique comprises switching from 3-axis accelerometer measurements and 3-axis magnetometer measurements to single-axis accelerometer measurements to determine an azimuth of the downhole tool. ### Claim 16 A non-transitory, 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 comprising: receiving an initial wellbore plan for a downhole tool to drill through a subterranean formation toward one or more targets; receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan; comparing the initial wellbore plan to the drilling data, wherein the comparison identifies that the downhole tool is approaching an unplanned event that is not accounted for in the initial wellbore plan and/or the drilling data, wherein the unplanned event comprises a previous downlink command not being received by the downhole tool, the drilling data deviating from the initial wellbore plan by more than a predetermined threshold, or both, and wherein the drilling data deviating comprises a measured curvature differing from a planned curvature by more than the predetermined threshold; determining a downlink command to transmit to the downhole tool, wherein the downlink command is based upon or in response to the comparison; determining an importance of the downlink command, wherein the importance is based upon the comparison; determining a time to transmit the downlink command to the downhole tool, wherein the time is determined based upon the importance of the downlink command and a measured rate of penetration (ROP) of the downhole tool; displaying the downlink command to a user; providing the user with a predetermined amount of time to accept or reject the downlink command; and transmitting the downlink command to the downhole tool at the determined time. ### Claim 17 (depends on 16) The non-transitory, computer-readable medium of claim 16, wherein the initial wellbore plan is based at least partially upon a seismic image or a model of the subterranean formation, and wherein the initial wellbore plan comprises: a planned direction that the downhole tool is to drill at a plurality of different locations in the subterranean formation; and a planned curvature of the downhole tool to be achieved at the plurality of different locations. ### Claim 18 (depends on 17) The non-transitory, computer-readable medium of claim 17, wherein the drilling data comprises: a measured direction that the downhole tool is drilling at the plurality of different locations; a measured curvature of the downhole tool at the plurality of locations; a measured depth of the downhole tool at the plurality of locations; a measured rotations per minute (RPM) of the downhole tool at the plurality of locations; a measured rate of penetration (ROP) of the downhole tool at the plurality of different locations; a measured weight on a drill bit (WOB) of the downhole tool at the plurality of locations; a measured flow rate of a fluid being pumped into a wellbore of the initial wellbore plan when the downhole tool is at the plurality of locations; a measured position of a block on a drilling rig at a surface when the downhole tool is at the plurality of locations; and settings of the downhole tool when the downhole tool is at the plurality of locations, wherein the settings comprise a steering mode of the downhole tool, an orientation of a tool face of the downhole tool, a steering ratio of the downhole tool, and a steering efficiency factor of the downhole tool. ### Claim 19 (depends on 18) The non-transitory, computer-readable medium of claim 18, wherein the predetermined amount of time is based upon a time that an uplink command from the downhole tool is received at the surface and a frequency of data points in the drilling data, and wherein the predetermined amount of time expires before the determined time to transmit the downlink command to the downhole tool. ### Claim 20 (depends on 19) The non-transitory, computer-readable medium of claim 19, wherein the downlink command is transmitted by modulating the flow rate or the RPM, wherein the downlink command is transmitted in response to the user accepting the downlink command or not rejecting the downlink command, wherein the downlink command causes the downhole tool to vary the direction that the downhole tool is to drill, the curvature of the downhole tool, the ROP, the WOB, the flow rate, and a technique that the downhole tool uses to process measurements that are captured by the downhole tool, wherein varying the technique comprises switching from 3-axis accelerometer measurements and 3-axis magnetometer measurements to single-axis accelerometer measurements to determine an azimuth of the downhole tool.