A system is described for calculating and outputting micro invisible lost time (MILT). The system may include a processor and a non-transitory computer-readable medium comprising instructions that are executable by the processor to cause the processor to perform various operations. Time-stamp data that includes values of drilling parameters may be received about a drilling operation, and the values of drilling parameters may be classified into a rig state that includes rig activities. For each rig activity, an actual completion time may be determined and compared to an expected completion time for determining a deviation. At least one deviated activity, in which the deviation is greater than a threshold, may be determined. Deviations may be combined into MILT that can be output for controlling the drilling operation.

A method includes attaching a sensor calibration tool to a drill string. The sensor calibration tool includes a first tool sensor configured to measure a first operational parameter. A first tool sensor measurement of the first operational parameter is received from the first tool sensor, where the drill string is disposed at least partially within a wellbore and supported by a surface rig system and the sensor calibration tool is positioned on the drill string at a surface location proximate to the surface rig system. A first rig sensor measurement of the first operational parameter is received from a first rig sensor positioned on a first surface component of the surface rig system. The first rig sensor is calibrated based on a comparison of the first tool sensor measurement with the first rig sensor measurement.

In some examples, a method performed by a drilling rig control center, includes receiving raw data for a first time segment, the raw data related to a drilling operation. In addition, the method includes deriving first drilling state measurements based on the raw data of the first time segment. Further, the method includes deriving first formation state measurements based on the raw data of the first time segment. The method also includes correlating the first derived drilling and formation state measurements of the first time segment with a second derived drilling and formation state measurements of a second time segment. Still further, the method includes generating a control response based on the correlation.

A downhole drilling apparatus, passing through a subterranean borehole, may mark an inner wall of the borehole with a marking element. A sensor, spaced axially from the marking element on the drilling apparatus, may subsequently sense the marking as it passes. A rate of penetration of the drilling apparatus may be calculated by dividing an axial distance, between the marking element and the sensor, by a time interval, between when the marking element marks the inner wall and when the marking is sensed by the sensor. Alternately, a second sensor, spaced axially from the first, may also sense the marking. A rate of penetration may then be calculated by dividing an axial distance, between the two sensors, by a time interval, between when the two sensors sense the marking.

A downhole drilling apparatus, passing through a subterranean borehole, may mark an inner wall of the borehole with a marking element. A sensor, spaced axially from the marking element on the drilling apparatus, may subsequently sense the marking as it passes. A rate of penetration of the drilling apparatus may be calculated by dividing an axial distance, between the marking element and the sensor, by a time interval, between when the marking element marks the inner wall and when the marking is sensed by the sensor. Alternately, a second sensor, spaced axially from the first, may also sense the marking. A rate of penetration may then be calculated by dividing an axial distance, between the two sensors, by a time interval, between when the two sensors sense the marking.

A system for monitoring installation of a utility product pipe within an underground borehole and detecting any issues with the installation process. The system utilizes one or more sensors to measure a parameter concerning the product pipe as the product pipe is pulled into the borehole, and one or more sensors to measure a parameter concerning the drill string as the drill string is pulled out of the borehole. The measured parameters are compared and analyzed to determine if any damage is likely to occur to the product pipe if the installation operation is not stopped and any issues remedied prior to continuing operation.

A method can include receiving sensor data; determining a rate of penetration drilling parameter value using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling a borehole using the determined rate of penetration drilling parameter value.

A method can include receiving sensor data; determining a rate of penetration drilling parameter value using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling a borehole using the determined rate of penetration drilling parameter value.

Planning a wellbore includes determining drillability values from surface drilling parameters for an offset wellbore. The drillability values are used to prepare a protein code sequence of protein codes assigned to a range of drillability values. The protein code sequence from the offset wellbore is used to develop a protein code sequence for a planned wellbore. A machine learning model analyzes the offset surface drilling parameters and protein code sequence, and provides target surface drilling parameters for the planned wellbore.

Planning a wellbore includes determining drillability values from surface drilling parameters for an offset wellbore. The drillability values are used to prepare a protein code sequence of protein codes assigned to a range of drillability values. The protein code sequence from the offset wellbore is used to develop a protein code sequence for a planned wellbore. A machine learning model analyzes the offset surface drilling parameters and protein code sequence, and provides target surface drilling parameters for the planned wellbore.