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 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 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 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 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 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: 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 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: 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: 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 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: 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 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: 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: 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: 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: 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: 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: 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.

Abstract: A method for modeling fluid flow in a wellbore is provided. Hydraulic fracturing is an effective technique to improve well productivity by forming high permeable pathways for hydrocarbons to flow from the rock formation to the wellbore. Fluid flow for hydraulic fracturing is modeled using separated flow components, including a wellbore component (modeling the wellbore(s)), a perforation component (modeling the perforations(s)), a fracture component (modeling the fracture(s)) and a rock component (modeling the rock). Each respective component may be selected independently from a plurality of available components. Further, the respective components may be coupled to one another only at their interfaces, such as at a wellbore-perforation interface, a perforation-fracture interface, and a fracture-rock interface, for continuity of fluid kinematics and properties (such as pressure and density).

Abstract: Embodiments disclosed herein include components, devices, systems, and operations and functions for generating a seismic profile. An optical signal is generated in an optical signal medium disposed in proximity to a formation. A seismic source induces seismic signals within the formation. A backscatter response corresponding to the seismic signals from the optical signal medium is detected and quadrature modulated to generate a quadrature trace. A seismic response is generated by determining phase differences in the backscatter response based on the quadrature modulated backscatter response. Portions of the seismic response above or below a response threshold are removed to generate a threshold seismic response. The threshold seismic response is correlated with at least one of the seismic signals to generate a correlated seismic response.

Abstract: An acoustic logging tool may comprise a center load carrying pipe, a receiver module connected to the center load carrying pipe, one or more transmitter modules connected to the center load carrying pipe, and one or more mass modules connected to the center load carrying pipe.

Abstract: Disclosed is a system and method for calculating a formation shear-wave slowness. The system includes a borehole sonic logging tool and an information handling system. The borehole sonic logging tool may comprise a transmitter comprising one or more elements disposed at one or more radial distances from an axis of the borehole sonic logging tool and the transmitter is configured to transmit a first mode into a borehole. The sonic logging tool may further include one or more receivers disposed at a second radial distance from the axis of the borehole sonic logging tool and are configured to detect a second mode that one or more lobes than is a higher order than the first mode. A method may comprise broadcasting the first mode into the borehole, recording the second mode from the borehole with the one or more receivers, and calculating the formation shear-wave slowness from the second mode.

Abstract: Downhole properties of a geological formation may be determined using nuclear magnetic resonance (NMR) measurements obtained by a moving tool. To do so, an interpretation of the NMR data obtained by the moving data may take into account a moving model, characterization, or calibration of the downhole NMR tool. Additionally or alternatively, a partial interpretation mask may exclude interpretation of certain areas of data (e.g., T1-T2 data points or diffusion-T2 data points) that are expected to be less likely to describe downhole materials of interest.

Abstract: The present disclosure resides in a method for monitoring an automated plant, which has a fieldbus access unit connected with a first communication network, wherein the first communication network has a plurality of field devices and network nodes, wherein a communication driver, which runs in a first frame application, which is implemented in a client computer connected with the fieldbus access unit via a second communication network, queries structure data of network nodes and field devices present in the first communication network, wherein the structure data are generated by the fieldbus access unit in the context of the query by scanning the address space of the network level and determining the network nodes and field devices present in the address space. The present disclosure further resides in a fieldbus access unit and an arrangement, comprising a client computer and a fieldbus access unit.

Abstract: Based on measurements of forces and rotational velocity experienced by a drill bit during drilling, drilling behavior is detected and identified. Measurements of forces on a drill bit including torque on bit (TOB), weight on bit (WOB), etc. and measurements of rotational velocity (rotations per minute or RPM) are acquired in real time at the drill bit. Various measurements are correlated to produce related combinations of measurements, such as WOB-RPM, TOB-RPM, and RPM-time. Based on fitting between the combinations of measurements and curves corresponding to predetermined torsional behavior trends, torsional, axial, and rotational behaviors are classified as functional or dysfunctional.

Abstract: A method comprises performing data pre-processing of initial signals to obtain pre-processed initial signals; building a first machine learning model based on the pre-processed initial signals; generating output signals using the first machine learning model; computing ranks of the output signals; computing classifications of the output signals; and building a set of stacked machine learning models based on the ranks and the classifications. The set of stacked machine learning models may be used to generate subsurface well log data, NMR data, or other data.

Abstract: Systems and methods for wireless telemetry in oil and gas wells use fluid pressure differentials to send signals from surface equipment to a downhole tool. More specifically, the methods and systems selectively apply fluid pressure to a tubing string and measure the resulting mechanical strain, or deformation, on a tubular of the downhole tool. The deformation may be an elastic deformation or it may be a plastic deformation with yielding of the tubular. One or more of such strains or deformations may be used to encode a digital signal that can command an action on the tool. The strain or deformation may be measured by a low-cost strain gauge.

Abstract: A receiver coil assembly for a geophysical survey system comprising: a first receiver coil supported by a first tubular frame that forms a first loop; a second receiver coil supported by a second tubular frame that forms a second loop; releasable connectors connecting the first tubular frame to the second tubular frame with a sensing axis of the first receiver coil having a different orientation than a sensing axis of the second receiver coil.

Abstract: The present invention relates to a system and method to be applied to multiple inflow and outflow control zones in an open-hole uncoupled completion. The invention can handle, for example, the complexities and limitations of hydraulic control found in carbonate reservoirs in the Brazilian Pre-Salt, which are characterized by high pressures and flows, large vertical extensions of the reservoir, high scaling potential, and high potential for losses during drilling and completion operations.

Abstract: A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

Abstract: A well log is scanned for one or more dimensions that describe one or more features of a well. Each dimension includes a plurality of values in a numerical format that represents each dimension. A missing value is detected in a first plurality of values of a first dimension of the well log. The first dimension of the well log is transformed, in response to the missing value, into a first image that visually depicts the first dimension including the first plurality of values and the missing value. Based on the first image and based on an image analysis algorithm a second image is created that visually depicts the first plurality of values and includes a found depiction visually depicting a found value in place of the missing value. The found depiction is converted, based on the second image, into a first value in the numerical format.

Abstract: Embodiments for controlling flow rates within a well system are disclosed herein. In one embodiment, a first flow control configuration is determined including determining flow profiles for a plurality of zones each including at least one flow control device. Contaminant intake classifications associated with one or more of the zones are generated based on the first flow control configuration and a first contaminant level detected for a combined flow comprising inflow from the zones. A second flow control configuration for the zones is generated based on the contaminant intake classifications.

Abstract: Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

Abstract: A load cell system for measuring rod load in a pumpjack. The system includes a tension load cell operatively coupled to a bridle between first and second bridle cables at a location longitudinally spaced between a horsehead and a bridle plate of the pumpjack. The bridle plate is coupled to the first bridle cable at a first connection point and the tension load cell is coupled to the first bridle cable at a second connection point longitudinally spaced between the bridle plate and the horsehead. The load cell system defines a third connection point longitudinally spaced between the second connection point and the horsehead. The load cell system is configured to maintain substantially constant longitudinal distances between the second connection point and each of the first and third connection points during operation of the horsehead.

Abstract: A system for data driven diagnostics of a machine including a machine learning model instantiated in a computer, the machine learning model being configured to: receive operational data of the machine; and process the operational data to determine machine diagnostics information. The machine learning model is trained using simulated defect information received from a simulation environment.

Abstract: Systems, devices, and techniques for determining downhole fluid contamination are disclosed. In one or more embodiments, phase-related properties are measured for a reservoir fluid having a determined composition. An equation-of-state (EOS) is selected and/or tuned based, at least in part, on the measured phase-related properties and the tuned EOS is applied to estimate fluid property values for a reference fluid over specified ranges of at least two thermodynamic properties. Contaminant reference data are generated that correlate the estimated fluid property values for the reference fluid with respective contaminant levels. Within a wellbore, a fluid sample is analyzed to determine a fluid property value. A contaminant level is identified that corresponds within the contaminant reference data to the determined fluid property value of the fluid sample.

Abstract: The present application provides a method, a device, and a system of vibration reduction control on the installation of a deepwater drilling riser. The method includes: determining a lateral vibration displacement of each position of the riser at different times in an installation process according to a mechanical model of the deepwater drilling riser in the installation process, determining a stress generated by a lateral vibration of the riser in the installation process, determining a vibration reduction control speed applied to a bottom of the riser in the installation process according to the stress and the lateral vibration displacement of each position of the riser at different times in the installation process, and performing a vibration reduction control on the bottom of the riser based on the vibration reduction control speed.

Abstract: The disclosure provides an acoustic logging device comprising a first tubular member comprising a plurality of grooves disposed on an exterior of the first tubular member. The acoustic logging device further comprises a ring transmitter module disposed around an exterior of the first tubular member, which comprises a piezoelectric (PZT) ring transmitter, a transmitter sleeve, wherein the PZT ring transmitter is disposed within the transmitter sleeve, and a cage, wherein the transmitter sleeve is disposed between the cage and the exterior of the first tubular member, wherein the transmitter sleeve is disposed over the plurality of grooves. The acoustic logging device further comprises a plurality of dual bender transmitters, wherein there is a gap disposed the plurality of dual bender transmitters in the exterior of the first tubular member, wherein there is an array of holes connecting each of the gaps together and providing fluid communication between the gaps.

Abstract: Methods for determining a volume of stored gas within a rock sample includes loading a rock sample into an overburden cell. A hydrocarbon gas at a gas pressure is applied to the rock sample and a confining fluid at a confining pressure is applied to the overburden cell. The confining pressure and the gas pressure are increased until a first pressure and temperature condition is met. With the rock sample maintained at the first temperature and pressure condition, a nuclear magnetic resonance spectrometer is used to scan the rock sample and measure a hydrocarbon gas volume within the rock sample. This measured hydrocarbon gas volume is then corrected using a Real Gas Index to determine the volume of stored gas within the rock sample.

Abstract: Methods, systems, and computer-readable medium to perform operations for identifying fracture barriers in a well. The operations include converting rebound hardness values of a rock specimen from the well to unconfined compressive strength (UCS) values, where each of the rebound hardness values corresponds to a respective coordinate of a measurement grid imposed on the specimen. The operations further include, for each column of the grid, plotting the UCS values versus depth. Further, the operations include mapping, based on a maximum UCS value and a minimum UCS value, a relative strength contour plot for the specimen. Yet further, the operations include mapping, based on a fixed strength range, an absolute strength contour plot for the specimen. In addition, the operations include determining, based on the relative strength contour, the absolute strength contour, and mineralogy of the rock specimen, that the rock specimen is indicative of a fracture barrier in the well.