Abstract: A method for drilling a well includes generating a plurality of proposed drilling actions using a plurality of working agents based on a working environment, simulating drilling responses to the proposed drilling actions using a plurality of validation agents in a validation environment that initially represents the working environment, determining rewards for the proposed drilling actions based on the simulating, using the validation agents, selecting one of the proposed drilling actions, and causing a drilling rig to execute the selected one of the proposed actions.

Abstract: A method is provided for evaluating logging while drilling (LWD) nuclear magnetic resonance (NMR) measurement quality. The method may include rotating a bottom hole assembly (BHA) in a wellbore to drill. The BHA may include an NMR tool deployed at a first location and at least one motion sensor deployed at a second location, wherein the first and second locations are axially spaced apart in the BHA. The method may also include making NMR measurements and corresponding motion sensor measurements while drilling in the wellbore. The method may further include processing the motion sensor measurements to determine the NMR measurement quality of the corresponding NMR measurements.

Abstract: A system and method that include receiving drilling dynamics data simulated by a processor and drilling dynamics data collected by a sensor positioned in a drilling tool and extracting a feature map based on a combination of the drilling dynamics data simulated by the processor and the drilling dynamics data collected by the sensor positioned in the drilling tool. The system and method additionally include determining a feature zone from the feature map. The system and method further include selecting a drilling parameter for a drill string based on the feature zone.

Abstract: A method may include generating an optimal operational window (OOW) that specifies operational parameter values for drilling operations using equipment at a rig site, based on data indicative of rig state and formation characteristics, and based on mutation-based optimization of the operational parameter values; and instructing a control system to perform the drilling operations according to the OOW using the equipment at the rig site.

Abstract: A drill bit includes a bit insert. A bit body of the bit includes an insert cavity. The bit insert is inserted into the insert cavity. The bit insert is secured to the insert cavity, such as by braze or with a connection mechanism. The bit insert may be replaceable, thereby allowing a drilling operator to adjust the configuration of the bit based on which bit insert is used.

Abstract: A system and method that include receiving sensor data during drilling of a portion of a borehole in a geologic environment. The system and method also include selecting a drilling mode from a plurality of drilling modes based at least on a portion of the sensor data. The system and method additionally include simulating drilling of the borehole using the selected drilling mode in a multi-dimensional spatial environment to generate a simulated state of the borehole in the geologic environment. The system and method further include analyzing the simulated state of the borehole and generating a reward using the simulated state of the borehole and a planned borehole trajectory and using the reward to train an agent to provide automated directional drilling with transitions between at least one of: a plurality of drilling modes and a plurality of toolface settings.

Abstract: A method can include receiving real-time data during a drilling operation performed by a drillstring that includes a mud motor and a bit characterized by an expected performance profile; determining actual performance of the drillstring based at least in part on the real-time data; predicting degraded performance of the drillstring based at least in part on the real-time data and a mud motor degradation model; and updating the expected performance profile based on a comparison of the actual performance and the degraded performance.

Abstract: A method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment; determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.

Abstract: Methods, computing systems, and computer-readable media for interpreting drilling dynamics data are described herein. The method can include receiving drilling dynamics data simulated by a processor or collected by a sensor positioned in a drilling tool. The method can further include extracting a feature map from the drilling dynamics data, and determining that a feature zone from the feature map corresponds to a predetermined dynamic state. The feature zone can be determined using a neural network trained to associate feature zones with dynamic states. Additionally, the method can include selecting a drilling parameter for a drill string based on the feature zone.

Abstract: A system and method that include receiving sensor data during drilling of a portion of a borehole in a geologic environment. The system and method also include selecting a drilling mode from a plurality of drilling modes based at least on a portion of the sensor data. The system and method additionally include simulating drilling of the borehole using the selected drilling mode and generating a state of the borehole in the geologic environment based on the simulated drilling of the borehole. The system and method further include generating a reward using the state of the borehole and a planned borehole trajectory and using the reward through deep reinforcement learning to maximize future rewards for drilling actions.

Abstract: A torsional damping system includes a housing having an interior space. An inertia ring is located in the interior space, and a torsion fluid is located between the inertia ring and the housing. The inertia ring is rotatably installed relative to the housing. As the housing oscillates, the inertia ring damps at least a portion of the oscillation. The torsional damping system may be included in a downhole tool or bottomhole assembly, and used to damp oscillations along a drill string or along the bottomhole assembly, including between a downhole motor and a cutting tool.

Abstract: A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

Abstract: A method for evaluating one or more bottom hole assemblies (BHAs) includes receiving a plurality of inputs. The inputs include one or more properties of the one or more BHAs, a planned trajectory of a wellbore, and one or more properties of a subterranean formation into which the wellbore will be drilled. The method also includes simulating drilling the wellbore in the subterranean formation based at least partially upon the inputs. Drilling of the wellbore is simulated with one or more artificial intelligence (AI) agents. Drilling of the wellbore is simulated a plurality of times using each of the one or more BHAs, thereby producing a plurality of simulations. Each simulation is generated using a different one of the AI agents. The method also includes generating one or more outputs in response to simulating drilling the wellbore.

Abstract: A motor bypass valve diverts drilling fluid away from a downhole motor when the motor is off bit. Bypassing the downhole motor reduces the shock and vibration on the BHA caused by the downhole motor, thereby reducing the damage to the BHA. The motor bypass valve may divert fluid out of a housing or into a bore through the rotor of the downhole motor.

Abstract: A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.

Abstract: A method for drilling a well includes generating a plurality of proposed drilling actions using a plurality of working agents based on a working environment, simulating drilling responses to the proposed drilling actions using a plurality of validation agents in a validation environment that initially represents the working environment, determining rewards for the proposed drilling actions based on the simulating, using the validation agents, selecting one of the proposed drilling actions, and causing a drilling rig to execute the selected one of the proposed actions.

Abstract: Management of fatigue life includes partitioning a drilling interval into sections, and calculating a stress value for each section. From the stress value, an equivalent alternative stress amplitude is calculated for each location, and a fatigue life consumption value in each section is computed. The fatigue life consumption value across the sections is aggregated to obtain an aggregated fatigue life consumption value, which is presented.

Abstract: A method, system, and computer readable medium for managing drilling operations include calibrating a drilling model using collected drilling data, and executing, during a drilling operation, a simulation on the drilling model to generate a predicted measurement value for a drilling property. During the drilling operation and from a drillstring, an actual measurement value for the drilling property is obtained. Based on the actual measurement value matching the predicted measurement value, the simulation is extended to generate a simulated state of the drilling operation during the drilling operation, and a condition of the drilling operation is detected. A notification may be presented based on the condition during the drilling operation.

Abstract: A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

Abstract: A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.