Abstract: A method of drilling a flowline below ground surface includes the step of supporting a pilot rod of a directional boring machine with hooks extending downwardly through substantially vertical relief holes while the rod bores an underground pilot hole. The hooks are removed as the rod pulls a reamer head backwards through the pilot hole to form a large diameter pipe hole so that the reamer head does not hit the hooks. The location of the reamer head is tracked or monitored using a transmitter on the pilot rod which sends a signal to an above ground receiver, so that an operator knows when to stop the back reaming process and temporarily remove each support hook as the reamer head approaches the vertical hole.

Abstract: A drilling assembly control system is designed to mitigate drilling vibration by detecting and classifying lateral vibrations. Vibrations are detected along a bottom hole assembly using one or more inertial measurement units, those vibration measurements are classified by lateral vibration type, and mitigating actions are determined.

Abstract: A system and method that include receiving offset well data collected from an offset well, wherein the offset well data comprises data representing a trajectory of an offset. The system and method also include receiving subject well data comprising a trajectory of at least a portion of a subject. The system and method additionally include determining a similarity value between the trajectory of the offset well and the subject well. The system and method also include selecting at least one offset well for offset well analysis based on the similarity value. The system and method further include adjusting at least one parameter of the subject well based on the offset well analysis.

Abstract: In some aspects, the disclosed technology provides solutions for using a residual gravitational noise signal to perform anomaly detection. In one aspect, a process of the disclosed technology includes steps for receiving a residual signal, wherein the residual signal is based on one or more magnetic field signals and at least one gravitational field signal corresponding with a drilling tool orientation over time, analyzing the residual signal to identify one or more tool vibration harmonics, and identifying one or more drilling anomalies based on the one or more tool vibration harmonics. Systems and machine-readable media are also provided.

Abstract: A method may include obtaining a plurality of historical drilling signals for a plurality of wells and generating a plurality of drilling parameters from the plurality of historical drilling signals of drilling activities of the plurality of wells into one real-time database of a computer processor. The method further includes applying Fourier Transform to decompose a plurality of functions into the plurality of drilling parameters and determining an optimum drilling parameter based on one or more optimized drilling parameters. The method further includes recomposing the plurality of functions to automate drilling activities for new wells by generating trends of the one or more optimized drilling parameters and using the trends in the drilling activities. The method further includes creating Key Performance Indexes (KPIs) for the plurality of optimized drilling parameters to evaluate performance and monitor the drilling activities in real time using machine learning algorithms.

Abstract: Downhole measurement systems and methods include deploying a bottomhole assembly having a multipole transmitter into a formation and transmitting acoustic signals into the formation. The multipole transmitter is of order n?2. Acoustic signals are received at respective receivers that are circumferentially aligned with the multipole transmitter, and are axially offset from the multipole transmitter, and axially offset from each other. The order of the first and second multipole receivers are equal to the order of the multipole transmitter. A controller is used to obtain first and second acoustic multipole data from the first and second multipole receivers at one or more azimuthal angles of a rotation of the bottomhole assembly in a formation during a drilling operation. Acoustic azimuthal anisotropy of the formation is determined from the first acoustic multipole data and the second acoustic multipole data.

Abstract: A method comprises generating, via a pulse generator, a first pressure pulse in a fluid in a pipe and detecting, via a transducer, a first reflected pressure pulse based on the first pressure pulse, wherein the first pressure pulse is reflected by a pipe feature to generate the first reflected pressure pulse. The method comprises generating, with the pulse generator, a second pressure pulse at a later time relative to generating the first pressure pulse, wherein timing of generating of the second pressure pulse is such that the second pressure pulse is superposed with the first reflected pressure pulse such that an amplitude of the second pressure pulse is greater than an amplitude of the first pressure pulse. The method comprises detecting, via the transducer, a second reflected pressure pulse based on the second pressure pulse, and detecting a pipe feature based on the second reflected pressure pulse.

Abstract: The disclosure recognizes the benefit in determining the dimensions of a wellbore for updating a performance model and changing drilling parameters in real time for steering a drill bit. The disclosed system and method provide improved control for steering a drill bit by obtaining dimension measurements of the wellbore proximate a drill bit and considering the dimension measurements to adjust one or more of the drilling parameters in real time. A method of drilling a wellbore a drilling system, and a drilling tool are disclosed herein. In one example, the method includes: (1) receiving dimension measurements of a wellbore during drilling of the wellbore by a drilling tool, (2) updating an existing performance model of the drilling tool in real time based on the dimension measurements, and (3) operating the drilling tool based on the updated performance model.

Abstract: A method of mapping reservoir fluid in a mature field includes identifying a region of interest within a hydrocarbon field, drilling a plurality of production wells through the region of interest, and collecting mud gas data as each production well is drilled. This mud gas data is used to generate a reservoir fluid property log, such as gas-oil ratio log, along a length of each of the production wells, which is in turn used to generate a refined model based on the 4D seismic data. The refined model permits better reservoir fluid mapping and has an improved vertical resolution at the region of interest than the first model of the field.

Abstract: A drill bit for a drilling system. The drill bit may include blades and a first depth of cut sensor. The blades may each comprise cutters. The first depth of cut sensor may be coupled to one of the blades and positioned to measure a distance between the first depth of cut sensor and a downhole surface of the borehole and transmit the distance measurement to a control system of the drilling system.

Abstract: A system and a method for a look-ahead drill bit. The system may comprise an ultra-deep transmitter operable to transmit a low frequency signal into a formation, a shallow tool operable to transmit a high frequency signal into the formation, at least one ultra-deep receiver operable to record a reflected low frequency signal, and at least one pair of collocated receivers, wherein the at least one pair of collocated receivers are operable to record a reflected high frequency signal. A method may comprise transmitting a high frequency signal from the shallow tool into the formation, transmitting a low frequency signal from the ultra-deep transmitter into the formation, evaluating the reflected high frequency signal and the reflected low frequency signal on an information handling system with a look-ahead inversion, and steering the bottom hole assembly in the formation based on the subterranean formation property.

Abstract: The embodiment of the present disclosure provides methods and Internet of Things systems for visual management of smart gas data center processes. The method is executed by a smart gas management platform of the Internet of Things system. The method includes: obtaining a data acquisition feature and first sampling data; obtaining a data summary feature and second sampling data; obtaining a first task list and a second task list, determining a first processing feature of the first task list and a second processing feature and a queuing feature of the second task list; determining an estimation feature, the estimation feature at least including an estimated completion time of the at least one gas task, and an estimated queuing time of the at least one pending gas task; generating first visualization data; and controlling at least one target platform to display the first visualization data.

Abstract: Methods and an apparatuses are for determining at least one property of a wellbore fluid system. A measurement apparatus having one or more pipe sections is provided, a drilling fluid is communicated through the pipe section, at least one density which is associated with at least one condition of pressure and temperature of the drilling fluid in the pipe section is measured, and the density of the drilling fluid is measured to determine the property of the wellbore fluid system.

Abstract: Automatic recognition of drilling activities based on daily reported operational codes includes obtaining a drilling report for a well. The drilling report includes codes. The method further includes obtaining a template comprising rules comprising a rule. The rule maps one or more codes of the multiple codes from the drilling report to an activity label of activity labels. Mapping the activity labels to the drilling report is performed using the rules to identify an occurrence of an activity from the drilling report with the activity label. An activity list is presented that includes the activity label with timing information for the activity at the well.

Abstract: A precise deep oil and gas navigation system based on structural evaluation of a sand/shale formation, and a device are provided. The precise deep oil and gas navigation system is implemented by: acquiring basic data of a target well location as well as basic data and an acoustic LWD curve of an adjacent well; dividing a basic data group; retaining extremely strongly correlated data and strongly correlated data of the basic data group, and performing dimensionality reduction; constructing a three-dimensional fusion feature data volume based on a dimensionality-reduced fusion feature parameter and a time-frequency spectrum; predicting a missing curve according to the three-dimensional fusion feature data volume; and correcting a stratigraphic structure model based on the missing curve to guide the design of a drilling trajectory.

Abstract: A method for drilling a subterranean wellbore includes rotating a bottom hole assembly (BHA) in the subterranean wellbore to drill, in which the BHA includes a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar and configured to rotate with respect to the drill collar, and triaxial accelerometer and triaxial magnetometer sets deployed in the roll-stabilized housing. Triaxial accelerometer and triaxial magnetometer measurements and a drill collar rotation rate measurement are made while the BHA rotates. A wellbore inclination and a gravity tool face of the roll-stabilized housing are computed from the triaxial accelerometer measurements. The computed inclination and gravity toolface, the triaxial magnetometer measurements, and the measured rotation rate of the drill collar are processed to compute an azimuth of the subterranean wellbore in which influences of eddy currents and magnetometer biases are accounted.

Abstract: A method for predicting a stick-slip event includes measuring one or more surface properties using a sensor at the surface. The method also includes measuring one or more downhole properties using a downhole tool in a wellbore. The method also includes determining that the one or more surface properties and the one or more downhole properties match a distribution. The distribution occurs before two or more previously-detected stick-slip events. The method also includes determining a likelihood that a stick-slip event will occur based at least partially upon the distribution that the one or more surface properties and the one or more downhole properties match.

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 and equipment (apparatus) for estimating motor parameters includes: receiving an operating parameter of an electric motor, estimating an estimated first motor parameter based on the operating parameter and on an initially determined second motor parameter and estimating an estimated second motor parameter based on the operating parameter and on an initially determined first motor parameter. The equipment (apparatus) and the method further include estimating a revised estimated second motor parameter based on the estimated first motor parameter and on the operating parameter, and estimating a revised estimated first motor parameter based on the estimated second motor parameter and on the operating parameter.

Abstract: A method includes determining, by an analysis system, a system aspect of a system for an issue recovery communications evaluation. The method further includes determining, by the analysis system, at least one evaluation perspective and at least one evaluation viewpoint for use in performing the issue recovery communications evaluation on the system aspect. The method further includes obtaining, by the analysis system, issue recovery communications data regarding the system aspect in accordance with the at least one evaluation perspective and the at least one evaluation viewpoint. The method further includes calculating, by the analysis system, an issue recovery communications rating as a measure of system issue recovery communications maturity for the system aspect based on the issue recovery communications data, the at least one evaluation perspective, the at least one evaluation viewpoint, and at least one evaluation rating metric.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: receiving real-time drilling data of a drilling operation of drilling a wellbore; using the drilling data to calculate at least one indicator of a tripping operation performed during the drilling operation; detecting, based on the least one indicator of the tripping operation, a drilling problem with the drilling operation; determining a corrective action to avoid or mitigate the drilling problem; and performing the corrective action to avoid or mitigate the drilling problem.

Abstract: Systems and methods are disclosed for identifying one or more vibration mechanisms or other mechanism associated with tool failure. In one example, a machine learning data system comprises a data pre-processing module, a machine learning training module, and a predictive module. The pre-processing module analyzes dynamic sensor input to identify one or more vibration mechanisms associated with a downhole tool. The machine learning training module identifies a correlation between dynamic sensor data and failure data for a plurality of downhole tools. The predictive module correlates the one or more vibration mechanism with tool failure or performance.

Abstract: Provided is a method for selecting one of a plurality of convergence paths that may be drilled by a bottom hole assembly (BHA) comprising identifying, by a computer system, a plurality of geometric convergence paths, wherein each of the geometric convergence paths provides a convergence solution from a defined bottom hole assembly (BHA) location to a target drilling path of a well plan. An offset distance is calculated for drilling by the BHA each of the geometric convergence paths connecting the BHA location to the target drilling path. A drill path curvature associated with drilling each of the geometric convergence paths by the BHA is determined by the computer system. A time required for drilling each of the geometric convergence paths by the BHA is determined by the computer system.

Abstract: A method may include obtaining, in real-time with a drilling operation, density data regarding a drilling fluid circulating in a wellbore. The method may further include determining mud velocity data of the drilling fluid in the wellbore based on flow rate data and a borehole area of the wellbore. The method may further include determining a cuttings weight of the drilling fluid in the wellbore based on the density data. The cuttings weight and the mud velocity data may correspond to a respective segment length among various segment lengths of the wellbore. The method may further include determining, based on the cuttings weight, the mud velocity data, and a hole cleaning model, various hole cleaning efficiency (HCE) values for the segment lengths of the wellbore. The method may further include determining whether an HCE value among the HCE values fails to satisfy a predetermined criterion.

Abstract: A model is used to generate corrections to mitigate ideal condition artifacts in acoustic property values of an annular material in a cased wellbore. A mathematical model that generates acoustic property values at ideal conditions introduces artifacts into the acoustic property values. Acoustic measurements of an annular material are used to generate features that represent wellbore conditions and are not accounted for in the mathematical model that generates acoustic property values. A model will generate corrections for acoustic property values of an annular material with the features to yield a more accurate acoustic property profile for the annular material of a cased hole.

Abstract: A computer system provides location-based weather services. Weather data is processed to determine one or more weather values for a location. The one or more weather values are compared to baseline weather data for the location to identify a weather event, wherein the weather event is identified in response to determining that the one or more weather values deviate from a corresponding one or more baseline values of the baseline weather data by a threshold amount. A request is received from a user device for weather information for the location. Information relating to the weather event is provided to the user device. Embodiments of the present invention further include a method and program product for providing location-based weather services in substantially the same manner described above.

Abstract: Multicomponent data are acquired using a downhole acoustic tool having transmitters and receiver stations distributed azimuthally in a plane perpendicular to the axis of the tool. The receiver stations are located at several receiving stations along the axis of the tool. At each acquisition depth, waveforms are processed through a multi-dimensional fast Fourier transform, extrapolation and inverse multi-dimensional fast Fourier transform. At each receiver station, waveforms are combined to produce the standard monopole waveforms and the inline and crossline dipole waveforms along fixed azimuths. These oriented waveforms produce a finer azimuthal sampling of the surrounding formation, and can then be used for imaging geological features within the surrounding formation.

Abstract: Aspects and features of this disclosure relate to projecting physical drilling parameters to control a drilling operation. A computing system applies Bayesian optimization to a model incorporating the input data using varying values for an adverse drilling factor to produce a target function. The computing system determines a minimum value for the target function. The computing system provides a projected value for the physical drilling parameters based on the minimum value. The computing system generates an alert responsive to determining that the projected value for the physical drilling parameters exceeds a prescribed limit.

Abstract: A method for a well includes obtaining a dynamic input parameter combination for the well, determining measurements for a rotating control device using a sensor, and predicting a rotating control device wear estimate using rotating control device estimation methods, the measurements, and the dynamic input parameter combination. The method for a well further includes maximizing an instantaneous rate of penetration, while reducing rotating control device failure, to determine an optimized average rate of penetration using the rotating control device wear estimate. Finally, the optimized average rate of penetration is executed for a well.

Abstract: Current disclosure proposes calibration methodology that uses the knowledge learned from historical data and real-time data to update a simplified physics-based borehole propagation model for real time steering control of a directional drilling system. The proposed methodology updates model parameters of the simplified physics-based model in real time through a process of setting up and optimizing an objective function, which indicates the difference between the estimated trajectory and the feedback from the real-time data. Penalizing terms, which prevent the parameters from deviating drastically from the prior knowledge of the parameter, and various components of the objective function are learned from the historical data. As a result, the updated model can accurately estimate and predict the system behavior allowing an input sequence of the system to be accurately mapped to the output response.

Abstract: Various implementations directed to a system and method for using a magnetometer in a gyro-while-drilling (GWD) survey tool are provided. In one implementation, a method may include acquiring gyroscopic data using gyroscopic sensors of a GWD survey tool while the tool is disposed at a first position within a wellbore. The method may also include acquiring first magnetic data using a magnetometer of the GWD survey tool while the tool is disposed at the first position. The method may further include determining an offset value for the magnetometer based on the gyroscopic data and the first magnetic data. The method may additionally include acquiring second magnetic data using the magnetometer while the tool is disposed at second positions within the wellbore. The method may also include determining magnetic azimuth values for the tool disposed at the second positions based on the second magnetic data and the offset value.

Abstract: Disclosed are computer implemented techniques for conducting a simulation of physical properties of a porous medium. The features include receiving a micro-CT 3D image that captures a representative elemental volume of the porous medium, the porous medium defined as having mineral types and fluid types with individual grains and grain to grain contacts, labeling the micro-CT 3D image as individual voxels according to mineral and fluid types and labeling the mineral type voxels as belonging to separated and fixed individual grains. The features also include transforming the labeled voxels into an unstructured conformal mesh representation for all grains and applying the unstructured conformal mesh representation to a parametric cohesive contact engine, with the parametric cohesive contact engine executing a parametric cohesive contact model that has an adjustable parameter, a critical separation ?0 conditioned according to consolidation level.

Abstract: Methods, computing systems, and computer-readable media for detecting sensor malfunctioning status. The method includes receiving sensor measurements of a first type from a first type of sensor, deriving a first value for a metric from the sensor measurements of the first type, receiving sensor measurements of a second type from a second type of sensor, wherein the second measurements of the second type include a second value for the metric, comparing the first value to the second value, determining whether the first type of sensor or the second type of sensor is malfunctioning based on the comparing, and storing or outputting information indicating whether first type of sensor and the second type of sensor are malfunctioning.

Abstract: A method for determining a real-time pore pressure log of a well in a reservoir, including the steps: storing existing data logs of surface drilling parameters, logging while drilling (LWD), and mud gas of existing wells in a database, storing existing pore pressure logs of the existing wells in the database, wherein the existing pore pressure logs correspond to the existing data logs, determining a relationship between the existing data logs and the existing pore pressure logs, drilling a new well into the reservoir, determining new data logs of surface drilling parameters, LWD, and mud gas of the new well while drilling the new well, inputting the new data logs of the new well into the relationship while drilling the new well, determining a real-time pore pressure log of the new well by outputting an estimated pore pressure at a certain depth by the relationship while drilling the new well.

Abstract: Methods, systems, and apparatuses for remote well operation control. Methods include conducting, with a plurality of remote well operation control hosts operating on corresponding remote well logging data acquisition management systems, a well operation using a well operation system at a well, wherein the well operation system includes a carrier having disposed thereon at least one logging instrument. Methods may include establishing a first operational control relationship between the carrier and a first of the plurality of remote well operation control hosts sufficient for the first remote well operation control host to control the carrier; and establishing a second operational control relationship between a selected one of the at least one logging instrument and a second remote well operation control host different than the first, the operational control relationship sufficient for the second remote well operation control host to control the at least one logging instrument and receive logging data.

Abstract: A system and a method for parameter optimization with adaptive search space and a user interface using the same are provided. The system includes a data acquisition unit, an adaptive adjustment unit and an optimization search unit. The data acquisition unit obtains a set of executed values of several operating parameters and a target parameter. The adaptive adjustment unit includes a parameter space transformer and a search range definer. The parameter space transformer performs a space transformation on a parameter space of the operating parameters according to the executed values. The search range definer defines a parameter search range in a transformed parameter space based on the sets of the executed values. The optimization search unit takes the parameter search range as a limiting condition and takes optimizing the target parameter as a target to search for a set of recommended values of the operating parameters.

Abstract: System and methods for event prediction during drilling operations are provided. Regression data associated with coefficients of a predictive model are retrieved for a downhole event during a drilling operation along a planned path of a wellbore. The regression data includes a record of changes in historical coefficient values associated with prior occurrences of the event. As the wellbore is drilled over different stages of the operation, a value of an operating variable is estimated based on values of the coefficients and real-time data acquired during each stage. A percentage change in coefficient values adjusted between successive stages of the operation is tracked. An occurrence of the downhole event is estimated, based on a correlation between the percentage change tracked for at least one coefficient and a corresponding change in the historical coefficient values. The path of the wellbore is adjusted, based on the estimated occurrence of the event.

Abstract: A method for evaluating a downhole working condition of a PDC bit includes: performing an indoor test, including performing a drilling test in different full-sized cores by using the PDC bit with different degrees of abrasion and balling under condition of given WOB and rotational speed, to acquire change characteristics of a WOB, a rotational speed, a torque, a ROP and a bit vibration of the PDC bit in different time domains; improving and perfecting an existing prediction model and evaluation method for the downhole working condition through data obtained by the test to obtain the method; reading parameters of the WOB, the rotational speed, the torque and the ROP in real time during drilling; determining the downhole working condition of the PDC bit by using the method in the improving and perfecting.

Abstract: A method for detecting the occurrence of an event at a well comprising: recording a first set of measurements collected from the well; processing the recorded measurements to provide a first set of data; calculating a first score based on the first set of processed data; recording a second set of measurements collected from the well; processing the second set of recorded measurements to provide a second set of data; calculating a second score based on the second set of processed data; wherein the first set of processed data and the second set of processed data is the number median of absolute difference from normal; combining the first score and the second score using a weighted average; and comparing the combined scores to a predetermined rule based on a specified time frame; and allowing an operator to adjust parameters of the well operation based on the score comparison.

Abstract: The calibration of fracture models for naturally fractured reservoirs using fracture properties from X-ray micro-computed tomography (X-ray MicroCT). A core plug is obtained from a subsurface naturally fractured hydrocarbon reservoir, and a fracture property such as fracture porosity and a fracture effective permeability of the hydrocarbon reservoir are determined. A natural fracture model is generated using reservoir parameters and fluid flow paths, and fracture properties such as fracture porosity and a fracture effective permeability are determined from the natural fracture model. The fracture properties of the natural fracture model are calibrated using the fracture properties from the X-ray MicroCT analysis of the core plug.

Abstract: A method of automatic optimization of ROP. The method obtains a plurality of drilling surface parameters for a field of interest, and determines an UCS data and a MSE data for a targeted formation based on well logs. The method further trains a ML model using the drilling surface parameters as inputs, and outputs a plurality of weights for drilling parameters in a ROP equation and in a Teale's MSE equation for the field of interest. The method further combines the ML ROP equation with the Teale's MSE equation to determine a plurality of optimum drilling parameters by simultaneously solving the set of ML ROP equation and the Teale's MSE equation. Furthermore, the method generates a work order to adjust the drilling parameters and cause display of the work order and the determined optimum drilling parameters in a user interface of a client device.

Abstract: Stratigraphic analysis includes determining misfit values between stratigraphic vertical depth of an offset wellbore, SVDow and measured depth of a subject wellbore. A likelihood that the target measured depth is equal to or within a tolerance of stratigraphic vertical depth of the subject wellbore, SVDsw, for sequences of stratigraphic vertical depth is calculated. A probability weighted average and an uncertainty that the target measured depth for the subject wellbore, TMDsw, is equal to or within a tolerance of stratigraphic vertical depth of the subject wellbore, is calculated. A continuous probability function over a range of measured depth that the target measured depth for the subject wellbore, TMDsw, is equal to or within a tolerance of stratigraphic vertical depth of the subject wellbore, SVDsw, is calculated.

Abstract: Methods and systems for quantifying and minimizing wellbore breakouts are disclosed. The methods include obtaining a mechanical earth model (MEM), determining a critical collapse pressure (CCP) using an inclination angle and the MEM, and determining an initial mud weight based on the CCP. The methods also include generating a breakout analysis using the initial mud weight, the MEM and a numerical modeling algorithm, updating the inclination angle of the planned wellbore, updating the CCP based on the updated inclination angle and the MEM, and updating the breakout analysis using the initial mud weight, the updated CCP, the MEM, and the numerical modeling algorithm. The methods further include selecting the updated CCP based, on the updated inclination angle that meets the stopping condition, calculating a final mud weight for the planned wellbore based on the updated CCP, and conditioning a drilling mud to the final mud weight, using a mud system.

Abstract: A method includes determining, by an analysis system, a system aspect of a system for an issue recovery improvement evaluation. The method further includes determining, by the analysis system, at least one evaluation perspective and at least one evaluation viewpoint for use in performing the issue recovery improvement evaluation on the system aspect. The method further includes obtaining, by the analysis system, issue recovery improvement data regarding the system aspect in accordance with the at least one evaluation perspective and the at least one evaluation viewpoint. The method further includes calculating, by the analysis system, an issue recovery improvement rating as a measure of system issue recovery improvement maturity for the system aspect based on the issue recovery improvement data, the at least one evaluation perspective, the at least one evaluation viewpoint, and at least one evaluation rating metric.

Abstract: A device for determining an error probability value for a transformer component, including a signal input interface, a processor unit, and a storage unit, wherein the signal input interface is configured for direct or indirect coupling to a measurement system for a power transformer, the measurement system having multiple sensors that are each designed to record a physical and/or chemical property of the power transformer, the power transformer having multiple transformer components, and each sensor being coupled to at least one of the transformer components of the power transformer by way of a respective related direct or indirect connection, wherein the physical and/or chemical property of the power transformer recorded by the respective sensor is influenced by at least one of the transformer components, wherein the signal input interface is configured to receive a status signal of the measurement system, the status signal representing multiple, different status variables.

Abstract: A method for drilling a subterranean wellbore includes rotating a drill string in the wellbore to drill. The drill string includes a roll-stabilized housing deployed in a drill collar and survey sensors deployed in the roll-stabilized housing. Sensor measurements are acquired while the drill string is rotating. High bandwidth accelerometer measurements may be obtained by combining triaxial accelerometer measurements and gyroscopic sensor measurements. Survey parameters, including a wellbore azimuth, may be computed from the high bandwidth accelerometer measurements. Triaxial magnetometer measurements may be processed to compute an eddy current induced wellbore azimuth error which may be removed from a previously computed wellbore azimuth to obtain a corrected wellbore azimuth.

Abstract: A method can include receiving block position data of a rig prior to addition of a length of pipe to a drillstring, where the drillstring is disposed at least in part in a borehole and supported by the rig; receiving block position data of the rig after addition of the length of pipe to the drillstring; and controlling position of the drillstring with respect to time using the rig and at least a portion of the block position data for landing a drill bit of the drillstring on a bottom of the borehole.

Abstract: The accuracy of directional surveys may be improved using accelerometers, magnetometers, or both. A control system containing accelerometers is configured specifically to correct errors in bias and gain of each accelerometer by requiring the measured field strengths to be as constant as possible over several tool face angles over multiple points in a wellbore, even when all measurements are within a tangent or lateral section of a wellbore. Corrections for the bias and gain errors determined based on one or more measurements from the accelerometers are applied to measurements at other survey points to improve the accuracy of surveys and the efficiency of drilling operations.

Abstract: Systems and methods of estimating well parameters are disclosed. In one embodiment, a method of estimating well parameters includes receiving a plurality of wells, each well defined by a plurality of well attributes, receiving a plurality of historic wells, each historic well of the plurality of historic wells defined by a plurality of historic well attributes, and comparing the plurality of well attributes of the plurality of wells with the plurality of historic well attributes of the plurality of historic wells. The method further includes selecting one or more matched historic wells based at least in part on a similarity between the plurality of well attributes for an individual well with the plurality of historic well attributes of the one or more matched historic wells, and calculating one or more well parameters based at least in part on the one or more matched historic wells.

Abstract: A method for determining a hydrocarbon concentration from drilling fluid includes pumping the drilling fluid into a wellbore and circulating a sample of the drilling fluid uphole from the wellbore so that ?13C isotopic signatures can be determined for one or more hydrocarbon components and for methane in the sample where the methane includes natural methane originating from the earth formation and artificially-produced methane caused by drill bit metamorphism (DBM). A processor is adapted to determine the concentration of the natural methane in the sample based in part on the ?13C isotopic signatures which may be performed during the drilling of the wellbore.