A method for optimizing a drilling roadmap may include identifying an optimal bottom hole assembly (BHA) setup and drilling parameters for a well located in a field. The BHA setup may be based on historical simulation data of the field and drilling roadmap information. The drilling roadmap information may include initial drilling instructions for implementing the drilling roadmap. The method may include implementing and tracking the drilling roadmap at the well. The drilling roadmap may be based on a location of the well on the field and a type of other applications being performed on the field. The method may include obtaining sensor collected data to determine an accuracy of implementation of the drilling roadmap. The accuracy may be determined based on a comparison between tracked drilling parameters and simulated drilling parameters.

Aspects and features of a system for real-time drilling using automated data quality control can include a computing device, a drilling tool, sensors, and a message bus. The message bus can receive current data from a wellbore. The computing device can generate and use a feature-extraction model to provide revised data values that include those for missing data, statistical outliers, or both. The model can be used to produce controllable drilling parameters using highly accurate data to provide optimal control of the drilling tool. The real-time message bus can be used to apply the controllable drilling parameters to the drilling tool.

Aspects and features of a system for real-time drilling using automated data quality control can include a computing device, a drilling tool, sensors, and a message bus. The message bus can receive current data from a wellbore. The computing device can generate and use a feature-extraction model to provide revised data values that include those for missing data, statistical outliers, or both. The model can be used to produce controllable drilling parameters using highly accurate data to provide optimal control of the drilling tool. The real-time message bus can be used to apply the controllable drilling parameters to the drilling tool.

The disclosure presents processes and methods for determining an adjusted drag friction factor, where the adjusting utilizes a hole cleaning function. In some aspects, the drag friction factor utilizes viscous drag. In some aspects, the drag friction factor utilizes viscous torque. In some aspects, the drag friction factor can be utilized to determine one or more decomposed friction factors. The decomposed friction factors or the adjusted drag friction factor can be utilized in a friction processor to improve the efficiency of borehole operations. The hole cleaning function can utilize various parameters, for example, a cuttings density, a cuttings load, a cuttings shape, a cuttings size, a deviation, a drill pipe rotation rate, a drill pipe size, a flow regime, a hole size, a mud density, a mud rheology, a mud velocity, a pipe eccentricity, and other parameters. A system is disclosed that is capable of implementing the processes and methods.

The disclosure presents processes and methods for determining an adjusted drag friction factor, where the adjusting utilizes a hole cleaning function. In some aspects, the drag friction factor utilizes viscous drag. In some aspects, the drag friction factor utilizes viscous torque. In some aspects, the drag friction factor can be utilized to determine one or more decomposed friction factors. The decomposed friction factors or the adjusted drag friction factor can be utilized in a friction processor to improve the efficiency of borehole operations. The hole cleaning function can utilize various parameters, for example, a cuttings density, a cuttings load, a cuttings shape, a cuttings size, a deviation, a drill pipe rotation rate, a drill pipe size, a flow regime, a hole size, a mud density, a mud rheology, a mud velocity, a pipe eccentricity, and other parameters. A system is disclosed that is capable of implementing the processes and methods.

A method can include determining an ideal activity speed profile of an activity for a well, where the ideal activity speed profile of the activity for the well corresponds to a length of the well; forecasting a start time and a stop time using the ideal activity speed profile of the activity; generating a drilling plan using the start time and the stop time where another activity commences after the stop time; during performance of the activity for the well, receiving data indicative of an actual activity speed of the activity for the well for a corresponding length of the well; during the performance of the activity, deciding to make an adjustment to the performance of the activity for the well using the ideal activity speed profile and the actual activity speed of the activity for the well; and adjusting the stop time of the drilling plan.

A method of and a device, borehole drilling equipment and a computer program product for estimating at least one of down hole speed and down hole torque of borehole drilling equipment while drilling a borehole in an earth formation. The borehole equipment comprising a rotational drive system, a drill string, a bottom hole assembly comprising a drill bit, a top end coupled to the rotational drive system, and a speed controller arranged for controlling rotational top end drive speed by commanding a top end drive torque. The method being performed in a computer based on a two-port spectral domain transfer matrix computational model of the borehole drilling equipment. While drilling, rotational top end drive speed and top end drive torque are obtained and down hole speed and down hole torque of the borehole drilling equipment are calculated by reducing spectral bandwidth of and applying a time delay term to the calculations enabling a causal time domain solution.

A method of and a device, borehole drilling equipment and a computer program product for estimating at least one of down hole speed and down hole torque of borehole drilling equipment while drilling a borehole in an earth formation. The borehole equipment comprising a rotational drive system, a drill string, a bottom hole assembly comprising a drill bit, a top end coupled to the rotational drive system, and a speed controller arranged for controlling rotational top end drive speed by commanding a top end drive torque. The method being performed in a computer based on a two-port spectral domain transfer matrix computational model of the borehole drilling equipment. While drilling, rotational top end drive speed and top end drive torque are obtained and down hole speed and down hole torque of the borehole drilling equipment are calculated by reducing spectral bandwidth of and applying a time delay term to the calculations enabling a causal time domain solution.

Methods for determination of mechanical properties of geological formations using deep learning include receiving, by a computer system, data acquired during drilling a geological formation. The computer system generates features of the data acquired during drilling. The features are indicative of mechanical properties of the geological formation. The computer system segments the features of the data acquired during drilling into sequences readable by a trained temporal convolutional network (TCN). The computer system determines the mechanical properties of the geological formation using the TCN based on the sequences obtained from the features of the data. A display device of the computer system generates a graphical representation of the mechanical properties of the geological formation.

A method for performing a drilling operation of a well in a subterranean formation is disclosed. The method includes obtaining drilling data records each including a revolutions per minute (RPM) value, a weight on bit parameter (WOB) value, and a rate of penetration (ROP) value, analyzing, using a computer processor, the drilling data records to generate a maximum point including a maximum ROP value that is based on a predetermined percentile of an ROP distribution of the drilling data records, generating, using the computer processor and based on the maximum point and a current point, a recommendation point including a recommended RPM value and a recommended WOB value, where the current point includes a current RPM value, a current WOB value, and a current ROP value of the drilling operation, and presenting, to a user, the recommendation point to facilitate the drilling operation.