Abstract: Aspects of the present disclosure relate to projecting control parameters of equipment associated with forming a wellbore, stimulating the wellbore, or producing fluid from the wellbore. A system includes the equipment and a computing device. The computing device is operable to project a control parameter value of the equipment using an equipment control process, and to receive confirmation that the projected control parameter value is within an allowable operating range. The computing device is also operable to adjust the equipment control process based on the confirmation, and to control the equipment to operate at the projected control parameter value. Further, the computing device is operable to receive real-time data associated with the forming of the wellbore, the stimulating of the wellbore, or the producing fluid from the wellbore. Furthermore, the computing device is operable to adjust the equipment control process based on the real-time data.

Abstract: A method is presented wherein inversion for formation anisotropic constants is achieved using borehole sonic data.

Abstract: A computer-implemented method, medium, and system for converting borehole images into three dimensional structures for numerical modeling and simulation applications are disclosed. In one computer-implemented method, multiple CT-scan images of a core sample of a rock are received, where the core sample includes a borehole, and the multiple CT-scan images are cross-section images of the core sample at multiple depths of the borehole. A triangulation process is performed on pixels of each CT-scan image and with respect to each of multiple circumferential position angles. Multiple radii of the borehole corresponding to the multiple circumferential position angles are determined for each CT-scan image. Multiple nodal coordinates of 3D numerical model mesh of the borehole are generated based on the multiple radii of the borehole. An advisory on drilling window limits of mud weight is provided based on the multiple nodal coordinates of the 3D numerical model mesh of the borehole.

Abstract: A method for predicting oil flow rates is provided. The method includes accessing historical data from a plurality of databases, accessing historical perforation data and historical reservoir properties data from a simulation model, and determining fluid flow values and rock quality index values associated with perforated intervals of the plurality of wells. The method further includes corresponding the fluid flow values and rock quality values to the well production data, training, using the plurality of input values, a machine learning model for predicting oil flow values at perforated intervals of a plurality of target wells, predicting, using the trained machine learning model, the oil flow values at the perforated intervals of the plurality of target wells, and generating a synthetic production log that includes the predicted oil flow values at the perforated intervals of the plurality of target wells.

Abstract: Provided are techniques for generating and validating facies logs for a horizontal wellbore, including: obtaining facies data for a subsurface formation, including vertical wellbore core data and wireline log data; determining (based on the facies data) a depositional model; determining (based on the facies data) a facies model of a horizontal portion of a wellbore in an target interval of the formation, including a predicted facies log; determining (based on the depositional model) a facies thickness mapping; determining for different locations within the formation (based on a comparison of the predicted facies log and the facies thickness mapping), a discrepancy between the facies of the predicted facies log and the facies thickness mapping for the location; and for locations of a discrepancy, modifying the predicted facies for the location based on the facies indicated for location by the facies thickness mapping, to generate a modified predicted facies log.

Abstract: A wellbore pumping unit comprising a main pump, a power source, a controller, and a plurality of sensors is provided. A method of performing a diagnostic check of the unit controller and the plurality of sensors when power is applied to the unit controller. A diagnostic application executing in memory writes a status of the plurality of analog inputs of a plurality of valve position sensors, a status of a plurality of frequency inputs of a plurality of flowmeters, and a plurality of calibration data files that correlate to a plurality of sensors to a diagnostic report file. The status of the sensor inputs and calibration data files can be a pass or a fail. The status of the sensor inputs can be displayed on a human machine interface.

Abstract: Examples described herein provide a computer-implemented method that includes analyzing a first dataset by applying the first dataset to a first model to generate a first result. The method further includes analyzing a second dataset by applying the second dataset to a second model to generate a second result. The method further includes performing validation on the first model and the second model by comparing the first result to the second result. The method further includes, responsive to determining that the first result and the second result match, modifying an operational action of a surface assembly based on at least one of the first result or the second result. The method further includes, responsive to determining that the first result and the second result do not match, updating at least one of the first model or the second model.

Abstract: A system includes a first wellbore operation controller for controlling a wellbore operation and generating a first broadcast indicating a first data topic desired for controlling the wellbore operation. The system also includes a second wellbore operation controller for generating a data stream associated with a wellbore and for generating a second broadcast indicating a second data topic that promotes the data stream. The system includes a mediator computing device that receives the first broadcast and the second broadcast and determines that the first wellbore operation controller is subscribed to the data stream by comparing the first data topic to the second data topic. In response to determining that the first wellbore operation controller is subscribed to the data stream, the mediator computing device creates a data link between the first wellbore operation controller and the second wellbore operation controller.

Abstract: Systems and methods include a method for aggregating source data to form ontological frameworks. Aggregation functions are defined for ontological frameworks modeling categories of components of a facility. Each aggregation function defines a target component selected from a Things category, an Events category, and a Methods category. Defining the target component includes aggregating information from one or more components selected from one or more of the Things category, the Events category, and the Methods category. Source data is received in real-time from disparate sources and in disparate formats. The source data provides information about the components of the facility and external systems with which the facility interacts. Using the aggregation functions, the source data is aggregated to form the ontological frameworks. Each ontological framework models a component of the Things category, a component of the a Events category, or a component of the Methods category.

Abstract: A method may comprise forming a data matrix, extracting chromatographs of a mud filtrate and a formation fluid, extracting concentration profiles of the mud filtrate and the formation fluid, and decomposing a data set on an information handling machine using a bilinear model. A system may comprise a downhole fluid sampling tool and an information handling tool. The downhole fluid sampling tool may comprise one or more multi-chamber sections, one or more fluid module sections, one or more gas chromatographers, wherein the one or more gas chromatographers are disposed in the one or more fluid module sections, and an information handling system.

Abstract: Embodiments of the disclosure include a casing installation monitoring system that monitors surface equipment (that is, equipment of a rig), provides information on casing installation operations (for example, hook load, torque, RPM, and cumulative fatigue) at various times and depths, provides initial casing installation guidelines, and provides alarms before and during the casing installation operation.

Abstract: Temperature data collected from a distributed temperature sensing system may be used to prepare a temporal thermal profile of the wellbore. The temporal thermal profile may be used to determine a generalized heat transfer coefficient (k) and/or a generalized geothermal profile (Tae). The temporal thermal profile and the generalized heat transfer coefficient (k) and/or the generalized geothermal profile (Tae) may be used to estimate thermal properties of a wellbore, such as well as fluid and flow characteristics. A heat of hydration index may also be determined based on the temporal thermal profile.

Abstract: A method for controlling a rotary steerable system (RSS) may comprise disposing the RSS into a borehole, storing a curvature for the borehole into an information handling system, storing one or more steering commands in the information handling system, taking a first attitude measurement at a first sensor and a second sensor disposed on the RSS at a first location in the borehole, and calculating a first relative attitude from the first attitude measurement at the first sensor and the second sensor. The method may further comprise taking a second attitude measurement at the first sensor and the second sensor disposed on the RSS at the second location in the borehole, calculating a second relative attitude from the second attitude measurement at the first sensor and the second sensor, and comparing the first relative attitude to the second relative attitude to find a difference.

Abstract: Sonic logging data including a sonic waveform associated with a plurality of shot gathers is accessed. A transformation operator is applied to the sonic logging data to provide a transformed sonic image, the transformation operator including at least one of a short time average long time average (STA/LTA) operator, a phase shift operator, and a deconvolution operator. A machine learning process is performed using the transformed sonic image to determine a sonic slowness associated with the sonic logging data. The sonic slowness is provided as an output.

Abstract: Methods for determining properties of a media on an exterior of a casing in downhole systems are described. The methods include conveying a logging tool through a casing in a downhole formation, stimulating shear waves and flexural waves in the casing, obtaining a shear attenuation rate measurement and a flexural attenuation rate measurement within the casing responsive to the media on the exterior of the casing, comparing the measured shear attenuation rate and the measured flexural attenuation rate against a plurality of respective division boundary values, and determining one or more properties of the media on the exterior of the casing based on the comparison of the measured shear attenuation rate and the measured flexural attenuation rate against the plurality of respective interfaces.

Abstract: The present disclosure relates to a seismic imaging free gas structure identification method and system. The method includes: acquiring a seismic imaging dataset, and annotating free gas structures in the seismic imaging sample data set to obtain a training dataset; using a generative adversarial network (GAN) to expand the training dataset for network training, wherein the GAN includes a generative network and a discrimination network; conducting domain conversion on original label data of the free gas training samples to obtain annotating labels; training a Bayesian neural network according to the free gas training datasets and labels, to obtain a free gas structure identification model; acquiring actual seismic imaging data of a target work area; and conducting, according to the actual seismic imaging data, identification by using the free gas structure identification model.

Abstract: A method may comprise identifying one or more pressure dissipation mechanisms that drop pressure within a fluid handling system, identifying one or more open flowpath elements, performing a matching algorithm with an information handling system, and initializing the matching algorithm with an estimate of a coefficient. A system may comprise a fluid handling system and an information handling system. The fluid handling system may comprise a fluid supply vessel, wherein the fluid supply vessel is disposed on a surface, pumping equipment, wherein the pumping equipment is attached to the fluid supply vessel and disposed on the surface; a wellbore supply conduit, wherein the wellbore supply conduit is attached to the pumping equipment and disposed in a formation, and a flowpath element, wherein the flowpath element fluidly couples the wellbore supply conduit to the formation.

Abstract: A method may include determining a stuck pipe event in a well operation for a well. The method may further include obtaining well data regarding the well operation and stuck pipe data regarding the stuck pipe event. The method may further include determining, using the well data and the stuck pipe data, a diagnostic action for the stuck pipe event. The method may further include transmitting a command to a stuck pipe adapter to perform the diagnostic action. The stuck pipe adapter may be a substitute adapter for a drill string or a work string in the well. The method may further include obtaining diagnostic data regarding the stuck pipe event in response to the stuck pipe adapter performing the diagnostic action. The method may further include determining a predicted location in the well of the stuck pipe event based on the diagnostic data and a machine-learning algorithm.

Abstract: A movement space information processing system includes moving bodies and an information processing device. The information processing device determines one or more moving bodies that are movably located within a predetermined movement range in the space from the moving bodies, and performs an identification task of identifying, from the determined one or more moving bodies, at least one moving body to accordingly perform a setting task of setting the identified at least one moving body as the at least one representative moving body. At least one moving body identified as the at least one representative moving body acquires an image of the space and extracts, from the image, probe information related to the space. The information processing transmits device The moving-body information item including the probe information and performs development of the spatial information based on the probe information.

Abstract: A system for managing proppant inventory includes a plurality of silos, each silo having a sensor to sense a proppant level of proppant stored therein. The system also determines an amount of proppant that is expected to become available, and automatically creates and sends an order to request additional proppant upon determining that the combination of the proppant level within the at least one of the plurality of silos and the amount of proppant that is expected to become available is less than a predetermined threshold or expected to fall below the predetermined threshold. The system also automatically selects one or more of the plurality of silos to unload the additional proppant into based upon the proppant level in each of the plurality of silos at the time of unloading the additional proppant and at least one of a user preference parameter or historical data from a previous operation.

Abstract: Embodiments of a system, controller, and method for operating a plurality of pumps for a turbine driven fracturing pump system used in hydraulic fracturing are disclosed. In an embodiment, a method of operating a plurality of pumps associated with a hydraulic fracturing system includes receiving a demand Hydraulic Horse Power (HHP) signal. The demand HHP signal may include the Horse Power (HP) required for the hydraulic fracturing system to operate and may include consideration for frictional and other losses. The method further includes operating available pump units at a percentage of rating below Maximum Continuous Power (MCP) level, based at least in part on the demand HHP signal. Furthermore, the method may include receiving a signal for loss of power from one or more pump units. The method further includes operating one or more units at MCP level and operating one or more pump units at Maximum Intermittent Power (MIP) level to meet the demand HHP signal.

Abstract: Centrally optimizing production of a reservoir that has a plurality of wells comprises monitoring production of each well in the reservoir using one or more respective sensors at each well. Sensor data indicative of the monitored production of each well from the one or more respective sensors is input to a central processing device for processing to evaluate the production of each well. The production of each well is evaluated to identify opportunities for optimizing production by the plurality of wells in the reservoir. In addition, one or more actions are taken using the central processing device to optimize production by the plurality of wells based on the identified opportunities for optimizing production.

Abstract: The present invention relates to a multi-capillary force curve averaging method based on the overall virtual measurement of a plurality of samples. The method includes the following steps: 1, taking m types of rock samples, obtaining a capillary force-saturation curve, an apparent volume and a porosity of each sample; 2, inspecting the quality of the capillary force-saturation curve of each sample and preprocessing the end points of each curve; 3, calculating an averaged wet phase saturation corresponding to different capillary force values of the plurality of samples under the overall virtual measurement of a plurality of samples; and 4, denoting data points on a graph by using the wet phase saturation as the abscissa and capillary force as the ordinate, and finally connecting all data points smoothly to obtain the averaged capillary force curve.

Abstract: A transmission system comprising a tool comprising an annular groove. An inductive coupler comprising a housing disposed within the annular groove, and an annular MCEI trough within the housing. An annular coil wire being laid within the annular MCEI trough; the coil wire being connected to coaxial cable within the tool. The coaxial cable comprising a mesh reinforced polymeric composite dialectic material intermediate a center electrical conductor and an outer electrically conducting sheath. The dialectic material comprising MCEI fibers in sufficient volume to capture an electromagnetic field surrounding the center conductor and shield a signal being transmitted along the center conductor from outside electromagnetic interference. The center conductor may run through MCEI mesh reinforced beads embedded within the dialectic material. The coaxial cable may extend within the tool or to the opposite end of the tool with the center conductor being connected to a similarly configured inductive coupler.

Abstract: A system can include a processor; memory operatively coupled to the processor; and processor-executable instructions stored in the memory to instruct the system to: receive a marker on a well log for a well in a geographic region; and iteratively propagate the marker automatically to a plurality of well logs for other wells in the geographic region.

Abstract: Certain aspects and features relate to a system that includes a well tool configured to transmit an acoustic signal, detect a reflection signal, and transmit data representing the reflection signal. A processor analyzes the data to identify a pulse portion of the reflection signal, which is distinct from a reverberation portion. The processor determines a value for an attribute of the reflection signal, and executes a model to generate a first set of synthetic values for the attribute of the reflection signal and a second set of synthetic values for an impedance of a cement casing. The processor can then generate a lookup table that correlates the first set of synthetic values to the second set of synthetic values. By referencing the lookup table, processor can determine the impedance of the cement casing and alter a drilling plan or a completion plan based on the impedance of the cement casing.

Abstract: Systems and methods are disclosed for managing skin in a subterranean wellbore. In an embodiment, the method includes oscillating a drawdown pressure of the subterranean wellbore in a predetermined pattern that comprises a plurality of alternating drawdown pressure increases and drawdown pressure decreases. The drawdown pressure increases of the predetermined pattern comprise increasing the drawdown pressure at a first rate, and the drawdown pressure decreases of the predetermined pattern comprise decreasing the drawdown pressure at a second rate that is different from the first rate.

Abstract: A device and method to compress and store ultrasound data from an ultrasound logging device. The logging device is deployed in a well or pipe to be logged with one or more ultrasound transducers, preferably an array of transducers. On-board the device, are processors and memory units for convolving the ultrasound data with a wavelet transformation to generate wavelet coefficients and then compress the wavelet coefficients to generate compressed wavelet coefficients. The compressed wavelet coefficients are stored on the memory units and transferred to a remote computer once the device leaves the well or pipe.

Abstract: A wellbore drilling system can generate a machine-learning model trained using historic drilling operation data for monitoring for a lost circulation event. Real-time data for a drilling operation can be received and the machine-learning model can be applied to the real-time data to identify a lost circulation event that is occurring. An alarm can then be outputted to indicate a lost circulation event is occurring for the drilling operation.

Abstract: A method of calculating the temperature and/or porosity of a geological structure, wherein there is provided at least two geophysical parameters of the geological structure, the method including inverting the at least two geophysical parameters to estimate the temperature and/or porosity of the geological structure.

Abstract: A technique facilitates nonintrusive monitoring of a fluid constituent within an overall fluid flow. The system and methodology may be used downhole to monitor, e.g., the volume fraction of water in produced well fluid. The system comprises a sensor system combined with a component, e.g. a well component, having a flow passage for receiving a fluid flow. At least a portion of the fluid flow moves through the sensor system which may comprise a main electrode, a guard electrode, and an insulator to isolate the main electrode and the guard electrode. The main electrode and the guard electrode are oriented circumferentially around the fluid flow to obtain capacitance data on the fluid flowing through the sensor system. The capacitance data may be processed to determine the fraction of a specific constituent within the fluid flow, e.g. to determine the volume fraction of water in a well fluid flow.

Abstract: The present invention relates to a method for monitoring axial loads in structures by identifying natural frequencies. The analyzed structures are made up of elements connected by means of contact and are subjected to tractive loads, such as mooring lines. The proposed method uses bench testing and a computer model of the structure to determine the variation in the natural frequencies in relation to the variation in load. Monitoring is carried out using vibration sensors, in particular accelerometers, laser position sensors or strain gauges, to measure the dynamic behaviour of the structure, a data capture and signal conditioning unit and a computer to correlate the load applied and the vibration behaviour using a computer algorithm, and also to present the result. The invention discloses an easy calibration method for the dimensional template of the structures in question, high accuracy and easy installation and operation in the field.

Abstract: A method may comprise: disposing an acoustic logging tool in a wellbore, wherein the acoustic logging tool comprises a transmitter and a receiver; emitting a flexural wave from the transmitter; recording a four component dipole waveform with the receiver, wherein the four component dipole waveform comprises XX, XY, YX, and YY components; rotating the four component dipole waveform using Alford rotation to produce rotated waveform components, wherein the rotated waveform components comprise XX?, XY?, YX?, and YY? components; comparing a travel time of XX? and YY? components to identify a fast wave and a slow wave from the rotated waveform components; processing the fast wave and the slow wave using high-resolution data-driven processing to obtain a fast wave flexural dispersion curve and a slow wave flexural dispersion curve; determining a frequency dependent anisotropy curve using the fast wave flexural dispersion curve and the slow wave flexural dispersion curve; and determining a low-resolution shear anisot

Abstract: Described herein are methods to determine an amount of shale inhibitor in drilling fluids used in wellbore operations. In some cases, methods include receiving a sample of a drilling fluid, removing solids from the sample to produce a solids-free fluid, contacting the solids-free fluid with an anion to produce a precipitate in a test solution, and determining an amount of an amine-based shale inhibitor within the sample by measuring the amount of the precipitate in the test solution.

Abstract: A method and system for estimating clean fluid composition and properties. A method may comprise disposing a downhole fluid sampling tool into a wellbore, wherein the downhole fluid sampling tool comprises optical instrumentation, obtaining a fluid sample with the downhole fluid sampling tool, wherein the fluid sample comprises a reservoir fluid contaminated with a well fluid, identifying input parameters from at least one sensor response on the optical instrumentation, and predicting a clean fluid sample of the reservoir fluid using an asymptote of a dimensional reduction analysis and equation of state. A system may comprise a downhole fluid sampling tool and a processing unit. The downhole fluid sampling tool may further comprise an optical instrumentation operable to obtain fluid samples of a reservoir fluid contaminated with a well fluid while the downhole fluid sampling tool is disposed in a wellbore.

Abstract: A system for creating a 4D guided history matched model may include a network of saturation sensors and a model processing hub. The saturation sensors may identify water production rates. The model processing hub may be in communication with the network of saturation sensors and may include a reservoir simulation model and a processor. The processor of the model processing hub may build a 4D saturation model, compare the reservoir simulation model and the 4D saturation model to generate a saturation ?, calculate updated permeability distribution data, and update the reservoir simulation model with the updated permeability distribution data to create the 4D guided history matched model. A method of creating a 4D guided history matched model may include comparing a reservoir simulation model and a 4D saturation model, calculating updated permeability distribution data, and updating the reservoir simulation model to create the 4D guided history matched model.

Abstract: A system for blast hole data collection for use in a mine site incorporates an instrument configured to acquire geological property data of a blast hole for processing in the system or remotely and a vehicle having a handling system configured to move the instrument into and out of the blast hole as an interchangeable element with a drill string or prior to explosives charging.

Abstract: Various downhole logging tools and methods of using and making the same are disclosed. In one aspect a method evaluating cement bond quality in a well is provided. In a well with a particular casing/tubing configuration, waveforms of acoustic energy returning from the tubing and the casing with the tubing present are recorded. A frequency spectrum from the recorded waveforms is determined. Amplitudes of the returning acoustic energy at one or more preselected frequency(s) of interest of a range of frequencies at which the amplitudes are noticeably affected by cement bond quality for the particular casing/tubing configuration are determined. The determined amplitudes are compared with one or more baseline amplitudes to look for indications of cement bond quality. Other aspects involve time domain analysis.

Abstract: A method is provided. Cells of a digital model of a formation are classified corresponding with one or more classes based on minerals and/or pore sizes. Wettability of the formation in the digital model is calibrated based on imbibition and/or drainage curves from physical experimentation for a rock sample and the one or more classes of the cells of the digital model.

Abstract: A conveyance model for predicting an output in response to an input, wherein: the input comprises one or more of a wireline input, a toolstring input, a well input, and/or a conveyance input; and the output comprises one or more of a surface weight versus depth output, a cable head tension versus depth output, and a jarring effect output.

Abstract: A method for characterizing a subsurface formation includes receiving image data of the subsurface formation obtained by a sensor tool and receiving a plurality of non-image data logs, each non-image data log being obtained by a different type of sensor tool. The method also includes performing an electrofacies analysis on the plurality of non-image data logs where the electrofacies analysis includes defining clusters wherein each cluster has a similar property to provide a plurality of electrofacies blocks with each electrofacies block representing a depth interval. The method further includes partitioning the image data into multiple high-resolution depth segments that share a similar property, feature, and/or pattern for each electrofacies block and assigning data from the plurality of non-image data logs into a corresponding high-resolution depth segment to provide a high-resolution data log that characterizes the subsurface formation.

Abstract: A method may include obtaining, by a computer processor, seismic data regarding a geological region of interest. The method may further include obtaining, by the computer processor, well log data from a wellbore within the geological region of interest. The method may further include determining, by the computer processor, a formation top depth using the seismic data, the well log data, a stratigraphic column, and a machine-learning model. The stratigraphic column may describe an order of various formations within the geological region of interest. The machine-learning model may assign a feature among the seismic data and the well log data to a formation among the formations in the stratigraphic column to determine the formation top depth.

Abstract: An apparatus includes a mechanical wave source; a set of mechanical wave sensors in a borehole to provide subsurface wave measurements based on formation waves from the mechanical wave source, and a processor. The apparatus also includes a machine-readable medium having program code to acquire the subsurface wave measurements, select a first set of tool wave measurements based on the subsurface wave measurements, and generate a set of filtered subsurface wave measurements by filtering the subsurface wave measurements based on the first set of tool wave measurements. The program code also includes instructions to generate a time-domain semblance map based on the set of filtered subsurface wave measurements, wherein the time-domain semblance map includes an initial set of compression wave peaks, determine a selected qualified compression wave peak based on a semblance value in the time-domain semblance map, and determine a compression wave slowness based on the selected qualified compression wave peak.

Abstract: Methods, systems, and computer-readable medium to perform operations including: obtaining, in real-time from one or more sensors of a drilling system, real-time drilling data of a drilling operation of drilling a wellbore; using the drilling data to calculate a carrying capacity index (CCI) of a drilling fluid and a cutting concentration in an annulus (CCA) of the wellbore; determining that at least one of the CCI and the CCA is outside a respective range; determining a corrective action to adjust the at least one of the CCI and the CCA to be within the respective range; and performing the corrective action.

Abstract: In a method to transform logs, an acoustic logging tool inserted into a borehole includes a source and an array of receiver stations. Each station includes a receiver spaced along the tool from the source by successively greater distances. In the method, the source emits energy (I) to cause the propagation towards the stations of plural signals exhibiting paths characteristic of first and second respective modes and (II) to stimulate a receiver of each station to generate an output signal per station that indicates the signal packets and represents the modes in combination with one another. In the method, the output signals are transformed into transformed signals containing phase/amplitude information of each mode. The phase/amplitude are linked by an operator to the slowness and attenuation of the mode and the transmitter-receiver distance of the station. The phase/amplitude are used to extract slowness and attenuation information for each mode.

Abstract: A system can determine a temperature profile based on a prior production temperature profile and a reference start point pressure for a well. The system can virtually divide the well into a plurality of sections including uphill sections and downhill sections. The system can determine a gas-oil interface depth for each section of the plurality of sections from a water-oil ratio and a gas-oil ratio based on the temperature profile and the reference start point pressure. The system can determine an oil-water interface depth for each section of the plurality of sections from the gas-oil ratio and the water-oil ratio based on the temperature profile and the reference start point pressure.

Abstract: Systems and methods of controlling drilling operations including Sliding With Indexing For Toolface (SWIFT) and Variable Weight Drilling (VWD) techniques. The methods and systems may include systems and devices for controlling the drilling operations, including systems and devices capable of automatically determining drilling parameters and setting operating parameters for drilling in a wellbore. The systems and methods may also determine a change in weight on bit and/or toolface, determine a timeframe for a weight on bit to be delivered to the bit, and/or determine a spindle change to modify the toolface. The systems and methods may also send control signals to apply the spindle change and/or block velocity change to correct any detected or anticipated toolface error.

Abstract: Embodiments for determining a stuck pipe location include determining that a pipe is stuck in a wellbore due to an obstruction; deploying a fiber optic stuck pipe location detector inside the pipe, activating a first fiber optic sensor to detect a baseline reading, and manipulating the pipe. Some embodiments include detecting micro-noises caused by the stretching of the pipe, wirelessly acquiring data related to the micro-noises from the first fiber optic sensor, and determining a location of the obstruction by comparing the baseline reading with the data related to the micro-noises. Some embodiments include recovering the pipe at a predetermined point around the location of the obstruction while leaving the first fiber optic sensor inside the pipe.

Abstract: A method includes receiving well log data for a plurality of wells. A flag is generated based at least partially on the well log data. The wells are sorted into groups based at least partially on the well log data, the flag, or both. A model is built for each of the wells based at least partially on the well log data, the flag, and the groups.

Abstract: A method for producing hydrocarbons in a gas lift well is disclosed. A gas lift rate of the well is monitored while producing hydrocarbons according to an initial gas lift performance curve. One or more well performance parameters for the well are monitored. Disturbances in the well are detected while monitoring the well performance parameters. Transience in the well is modeled. A new gas lift performance curve is derived based on the detected disturbances, the modeled transience, and the initial gas lift performance curve. An optimal allocation of gas lift is determined from the new gas lift performance curve. Hydrocarbons are produced using the determined optimal allocation of gas lift.