Abstract: A fault indicator calculator, a method for determining a fault indicator, and a fault indicator calculating system are disclosed herein. One embodiment of a fault indicator calculator includes: 1) an interface configured to receive seismic data, and 2) a processor configured to scan a manifold-shaped operator through said seismic data at a range of dips and azimuths and calculate fault throws at various orientations of said dips and azimuths independent of determining other fault indicators.

Abstract: Multiple projected rate of penetration (ROP) values can be determined for purposes of adjusting well tools and well characteristics. For example, surface data can be determined based on a surface sensor signal. Downhole data can be determined based on a downhole sensor signal. A first value indicating a first projected ROP of a drill bit can be determined by providing the surface data as input to a first machine-learning model. A second value indicating a second projected ROP of the drill bit can be determined by providing the downhole data as input to a second machine-learning model. A third value indicating a third projected ROP of the drill bit can be determined by providing the first value and the second value input to a third machine-learning model. An operating characteristic of a well tool can be adjusted based on the third value.

Abstract: A method for determining annular fluid expansion (“AFE”) within a borehole with a sealed casing string annulus. The method may include defining a configuration of the borehole. The method may further include defining a production operation and a borehole operation. The method may also include determining AFE within the borehole when performing the production operation. The method may further include determining AFE within the borehole when performing the borehole operation based on the AFE within the borehole when performing the production operation.

Abstract: A method for fracturing a formation is provided. Real-time fracturing data is acquired from a well bore during fracturing operation. The real-time fracturing data is processed using a recurrent neural network trained using historical data from analogous wells. A real-time response variable prediction is determined using the processed real-time fracturing data. Fracturing parameters for the fracturing operation are adjusted in real-time based on the real-time response variable prediction. The fracturing operation is performed using the fracturing parameters that were adjusted based on the real-time response variable prediction.

Abstract: A model optimizer for predicting a drill bit variable can select a model from multiple models based on a learned preference. The preference may be updated according to preference indicator received from a user in response to an output model selection.

Abstract: Aspects of the subject technology relate to systems and methods for predicting physical characteristics of a physical environment using a physical characterization model trained based on simulated states of a modeled physical environment. A physical characterization model can be generated based on a plurality of simulated states of a modeled physical environment. Specifically, the physical characterization model can be trained by mapping simulated spatial properties of the modeled physical environment temporally across the plurality of simulated states of the modeled physical environment. Further, input state data describing one or more input states of a physical environment can be received. One or more physical characteristics of the physical environment can be predicted by applying the physical characterization model to the one or more input states of the physical environment.

Abstract: A system can output a graphical user interface for use in planning or performing a wellbore operation. The system can receive a location of a geological point location of interest for subterranean exploration and a geological time-frame for the geological point location of interest. The system can determine present-day data about the geological point location of interest from the received location. The system can generate a pseudo-well and reconstruct geological-historical parameters in separate time-intervals based on the received location, plate-tectonic models, and paleo-geographic datasets. The system can generate a graphical user interface including present-day data, paleo-geographic data, plate-tectonic data, and plate-interaction data. The system can output the graphical user interface for use in planning or performing a wellbore operation to extract hydrocarbon fluid.

Abstract: Hydrocarbon exploration and extraction can be facilitated using machine-learning models. For example, a system described herein can receive seismic data indicating locations of geological bodies in a target area of a subterranean formation. The system can provide the seismic data as input to a trained machine-learning model for determining whether the target area of the subterranean formation includes one or more types of geological bodies. The system can receive an output from the trained machine-learning model indicating whether or not the target area of the subterranean formation includes the one or more types of geological bodies. The system can then execute one or more processing operations for facilitating hydrocarbon exploration or extraction based on the seismic data and the output from the trained machine-learning model.

Abstract: The invention concerns a computer implemented method for underbalanced drilling. In one embodiment, the method includes determining a plurality of gas injection rate versus bottom hole pressure curves for a plurality of liquid injection rates for a specified minimum and maximum gas injection rate and a minimum and maximum liquid injection rate. Next, the method determines a set of four interception curves including a minimum motor equivalent liquid rate interception curve, a minimum vertical liquid velocity intercept curve, a minimum horizontal liquid velocity intercept curve, and a maximum motor equivalent liquid rate intercept curve for a specified minimum and maximum mud motor rate range and a minimum horizontal and vertical annulus velocity.

Abstract: Systems, methods, and computer-readable media are provided for rig monitoring and in particular, to receiving data from a plurality of sensors in real-time, mapping the data from the plurality of sensors with a micro-activity and a macro-activity, generating a message based on the mapping of the data from the plurality of sensors with the micro-activity and the macro-activity, selecting a parameter to be compared with a bit depth, tuning the parameter and the bit depth with a corresponding model based on the message, generating a parameter uncertainty array and a bit depth uncertainty array based on the tuning of the parameter and the bit depth, and generating dynamic uncertainty ellipses based on the parameter uncertainty array and the bit depth uncertainty array.

Abstract: Methods and systems for analyzing a well system design including determining a volume change of trapped annular regions based on a plurality of initial temperatures and a plurality of final temperatures and an initial pressure. Analyzing the trapped annular regions to determine an enclosure volume change, a fluid expansion volume, and an annular pressure buildup for a safe well system and generating a graphical representation of the bounds of the safe well system envelop.

Abstract: Aspects of the present disclosure relate to receiving data associated with a subterranean reservoir to be penetrated by a wellbore and training a neural network with both the data and a physics-based first principles model. The neural network is then used to make predictions regarding the properties of the subterranean reservoir, and these predictions are in turn used to determine one or more controllable parameters for equipment associated with a wellbore. The controllable parameters can then be used to control equipment for formation, stimulation, or production relative to the wellbore.

Abstract: System and methods for optimizing wellbore tubular design are provided. Design parameters for a wellbore tubular component are determined based on different types of axial loads expected during a downhole operation. The design parameters include load conditions at load points along the tubular component. An equivalent axial load is calculated for each load point, based on the corresponding load conditions. Design limits for the different types of axial loads are determined based on associated design parameters. A counter-load pressure is determined for at least one load point selected for each type of axial load, based on the corresponding equivalent axial load for each load point and a corresponding design limit for each type of axial load. At least one of the design limits is adjusted for the different types of axial loads, based on the counter-load pressure of the selected load point for each type of axial load.

Abstract: A method for detecting anomalies in a piece of wellsite equipment. The method may include measuring data related to the piece of wellsite equipment. The method may also include encoding the measured data with a first autoencoder to produce a first set of encoded data. The method may further include performing a first Gaussian process regression (“GPR”) on the first set of encoded data to produce a first set of results that identifies a first anomaly in the measured data and that provides a first confidence interval for the first anomaly.

Abstract: Strata surfaces can be identified in well logs and correlated across the well logs taking into account manual corrections. For example, a computing device can receive well logs. The computing device can determine multiple stratum-surface correlations based on the well logs. Then, the computing device can receive user input indicating a correction to a particular stratum-surface correlation. Based on the correction to the particular stratum-surface correlation, the computing device can update some or all of the other stratum-surface correlations.

Abstract: A system can access geological data describing a plurality of rock types in a physical rock sample drilled from a reservoir. The system can generate synthetic rock samples and execute single phase upscaling to compute absolute permeabilities for the physical rock sample and the synthetic rock samples. The system can execute a first multiphase upscaling based on the single phase upscaling to determine relative permeabilities for the physical rock sample and the synthetic rock samples. The system can compare the relative permeability of the physical rock sample to the relative permeabilities for the synthetic rock samples and select a synthetic rock sample that varies the least from the physical rock sample. The system can perform at least one additional multiphase upscaling on the physical rock sample and the synthetic rock samples to determine a second multiphase upscaling result and to develop a plan for drilling operations.

Abstract: Map projections necessarily distort the Earth's surface in some fashion as a result of the transformation to a coordinate system. However, different map projection systems can preserve some properties of geospatial data (e.g., area) at the expense of other properties (e.g., distance or azimuth). To produce a minimally distorted global raster, a global raster generator creates a number and variety of projections using as input geospatial data. The generator intelligently selects the projection systems based on properties of the input data and desired properties of an output global raster. The generator then applies interpolation algorithms to the projections to produce smooth and continuous projections. The generator then re-projects the interpolated projections to a desired output projection system and filters the projections to identify and remove regions of the projections which exhibit distortion. The generator merges the filtered projections which results in a minimally distorted global raster.

Abstract: Systems and methods for controlling drilling operations are provided. A controller for a drilling system may provide drilling parameters such as weight-on-bit and rotation rate parameters to the drilling system, based on a machine-learned reward policy and a model-based prediction. The machine-learned reward policy may be generated during drilling operations and used to modify recommended values from the model-based prediction for subsequent drilling operations to achieve a desired rate-of-penetration.

Abstract: Systems and methods for determining a numerical age for new geological events within a new scheme by ordering relations between geological events within a new scheme and/or within a new scheme and a preexisting scheme into a preferred hierarchy, dynamically excluding lower relations in the preferred hierarchy that conflict with higher relations due to irreconcilable ages of the relations, and using the ordered relations remaining in the preferred hierarchy to determine a numerical age for the new geological events within the new scheme.

Abstract: A system is described for controlling wellbore drilling operations autonomously using satisficing parameters. The system can determine a wellbore-drilling envelope defining a zone for satisficed values of drilling parameters for a drilling operation. The system can receive real-time data for the drilling parameters and can compare the real-time data to the wellbore-drilling envelope. The system can output a command for automatically controlling the drilling operation in response to comparing the real-time data to the wellbore-drilling envelope.