Abstract: A method for planning and drilling a well includes receiving geomechanical and geological data for a subterranean domain, and receiving an initial well trajectory including a well path and survey points. The method includes conducting a wellbore stability analysis along the well trajectory based in part on the geomechanical and geological data. Conducting the wellbore stability analysis includes identifying a subset of the well path intervals along the well trajectory as having a risk for instability. The method includes calculating a geomechanics nudge for one or more survey points along the well trajectory. The geomechanics nudge is calculated as a derivative of the wellbore stability at the one or more survey points. The method includes modifying the one or more survey points and the one or more well path intervals connected thereto based in part on the geomechanics nudge to generate a modified well trajectory.

Abstract: System and methods for optimizing flow distribution across multiple production zones are provided. A flow distribution is assigned to a plurality of production zones along a wellbore within a formation. A temperature value is estimated for each of the production zones, based on the assigned flow distribution. The estimated temperature value is compared with an actual temperature value determined for each production zone. An error amount for the estimated temperature value is calculated based on the comparison. Based on the error amount, it is determined whether or not the flow distribution has reached a global optimum. The assigning, the estimating, the comparing, the calculating, and the determining are repeated until it is determined that the flow distribution assigned to the plurality of production zones has reached the global optimum.

Abstract: A system, computer program product, and method are provided for orchestrating a multi objective optimization of an application. A set of two or more key performance indicators (KPIs) and one or more parameters associated with the application are received. A machine learning (ML) based surrogate function learning model in combination with an acquisition function is leveraged to conduct one or more adaptive trials. Each trial consists of a specific configuration of the one or more parameters. A pareto surface of the KPIs of the application is computed based on the observations of KPI values from each adaptive trial. The pareto surface is explored and an optimal operating point is selected for the application. The application is then executed at the selected operating point.

Abstract: A method comprises obtaining temporal measurements associated with a heterogeneous material; building a numerical model of a material by assigning initial approximations to the temporal measurements; modifying the numerical model to create a modified numerical model; generating simulated temporal measurements associated with the temporal measurements using the modified numerical model; determining a reward, a penalty, or a modification based on a quality of a fit between the temporal measurements and the simulated temporal measurements; and updating the numerical model based on the reward, the penalty, or the modification.

Abstract: A system for reusing program code from a first completed application in a second under-development application based on identified patterns matching between the types of data accessed by the first and second applications. The system has an information model database, a pattern database, an API and applications which query the information model through the API, resulting in stored raw access data. The raw access data is extracted and patterns are generated based on similarity of the abstracted patterns as between the first and second applications. Application programmers access the pattern database to create new programs and implement prior computer code in the new program based on a pattern match on data accessed by a prior-developed application.

Abstract: Apparatus and methods of identifying rock properties in real-time during drilling, are provided. An apparatus includes an acoustic sensor installed in a drilling fluid circulation system of a drilling rig, the acoustic sensor coupled to one of the following: (i) a bell nipple, (ii) a gooseneck, or (iii) a standpipe. Raw acoustic sensor data generated real-time as a result of rotational contact of the drill bit with rock during drilling is received, and a plurality of acoustic characteristics are derived from the raw acoustic sensor data. The lithology type of rock undergoing drilling may be determined from the acoustic characteristics. Petrophysical properties of the rock undergoing drilling may be determined using a petrophysical properties evaluation algorithm employable to predict the petrophysical properties of rock undergoing drilling from the raw acoustic sensor data.

Abstract: A method and apparatus for hydrocarbon management including generating an image of a subsurface formation by: obtaining simultaneous-source survey data, an earth model, and a first and a second velocity model of the subsurface formation; generating synthetic survey data with at least one of the earth model, the first velocity model, and the second velocity model. The method and apparatus may include directly migrating the simultaneous-source survey data; migrating the synthetic survey data; and subtracting the migrated synthetic survey data from the migrated simultaneous-source survey data. The method and apparatus may include subtracting the synthetic survey data from the simultaneous-source survey data; and directly migrating the result of the subtraction. The method and apparatus may include generating an artifact-reduced image.

Abstract: Provided herein are systems and methods for modeling and simulating reservoir, wellbore, and hydraulic fracturing. The systems and methods provided herein may facilitate well life cycle simulation by integrating a three-dimensional model representative of hydraulic fracturing and fluid flow in a wellbore and reservoir. The systems and methods may couple fluid flow in the wellbore and reservoir during injection and extraction with propagation of fractures through subsurface materials during fluid injection. Integrated three-dimensional reservoir, wellbore, and hydraulic fracture simulation may be useful for the design of hydraulic fracture treatments and prediction of future reservoir production.

Abstract: Systems and methods for estimating reservoir productivity as a function of depth in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of depth in the subsurface volume of interest using visual effects; and display the representation.

Abstract: System and methods for controlling suspended particle redistribution during stimulation treatments. Fluid flow in a wellbore is simulated for a stimulation treatment to be performed along a section of the wellbore within a subterranean formation, based on a flow model associated with the wellbore. Based on the simulation, dimensionless parameters characterizing a flow of suspended particles within a treatment fluid to a fractured area of the formation via at least one perforation along the section of the wellbore are calculated. A collection efficiency of the suspended particles within the fluid is determined, based on the dimensionless parameters. The collection efficiency is used to calculate a flow rate of the suspended particles to the fractured area of the formation via the perforation. The flow rate is used to estimate an amount of the suspended particles to be injected into the wellbore during the stimulation treatment along the wellbore section.

Abstract: A method preserves shapes in a solid model when distributing material during topological optimization. A 3D geometric model of a part having a boundary shape is received. The geometric model is pre-processed to produce a variable-void mesh and to produce a frozen mesh representing the boundary shape. The geometric model is apportioned into a plurality of voxels, and a density value is adjusted for each voxel according to an optimization process. An iso-surface mesh is extracted from the voxel data, and a mesh Boolean intersection is derived between the extracted iso-surface mesh and the variable-void mesh. A mesh Boolean union between the mesh Boolean intersection and the frozen mesh.

Abstract: A method, apparatus, and program product perform microstructure analysis of a digital image of rock using a trained convolutional neural network model to generate a plurality of rock features. The rock features can represent a pore space in the microstructure of the rock including pores and throats. In many implementations, a statistical process can be applied to the rock features to generate characteristics of the pore space which can be used in classifying the rock.

Abstract: Analysis and display of source-to-sink information according to some aspects includes grouping target geochronological data and reference geochronological data into distinct population groups representing a reference population and target populations and characterizing subpopulations within the reference population and the target populations according a statistical attribute or statistical attributes. Subpopulations are compared within the reference population and the target populations based on the statistical attribute or attributes to determine correlations between the reference population and the target populations, and the results can be displayed in many different ways. As one example, results can be displayed using a present day geographic map as well as using a geodynamic plate tectonic model to show data points and their paleogeographic locations for the relevant geological time frame of investigation.

Abstract: A system and method of enhancing operation of hydraulic fracturing equipment at a hydraulic fracturing wellsite may include determining if a hydraulic fracturing stage profiles are available for use for hydraulic fracturing equipment at a wellsite. The method may include prompting an acceptance or amendment of one of the hydraulic fracturing stage profiles for a hydraulic fracturing pumping stage. The method may include, in response to an amendment of one of the hydraulic fracturing stage profiles, prompting acceptance of the amended hydraulic fracturing stage profile as the current hydraulic fracturing stage profile for use in association with the controller. The method may include, when a hydraulic fracturing stage profile is not available, prompting configuration of hydraulic fracturing pumping stage parameters for the current hydraulic fracturing stage profile.

Abstract: A method preserves shapes in a solid model when distributing material during topological optimization. A 3D geometric model of a part having a boundary shape is received. The geometric model is pre-processed to produce a variable-void mesh and to produce a frozen mesh representing the boundary shape. The geometric model is apportioned into a plurality of voxels, and a density value is adjusted for each voxel according to an optimization process. An iso-surface mesh is extracted from the voxel data, and a mesh Boolean intersection is derived between the extracted iso-surface mesh and the variable-void mesh. A mesh Boolean union between the mesh Boolean intersection and the frozen mesh.

Abstract: At least some of the disclosed systems and methods obtain a static earth model having a three-dimensional grid with multiple cells, each cell having petrophysical properties associated therewith. Further, at least some of the disclosed systems and methods adjust a size of at least some of the cells based on a predetermined scaling rule. Further, at least some of the disclosed systems and methods re-sample petrophysical properties for the adjusted grid cells. If the one or more attributes of the static earth model are within a threshold tolerance after the adjusting and re-sampling steps, the static earth model is used as input to a flow simulator.

Abstract: A part evaluation tool is disclosed and which may be used to assess a part-under-test for use in a system. A plurality of natural frequencies for a system operated at a first steady-state operational are identified. A vibrational response of a part-under-test is acquired, and resonance frequencies within this vibrational response are identified. Resonance frequencies of the part-under-test are compared with the identified natural frequencies for purposes of classifying the part as compliant (e.g., suitable for use in the system) or non-compliant (e.g., not suitable for use in the system).

Abstract: A vibration analysis system for predicting performance of a building system includes one or more memory devices configured to store instructions that, when executed on one or more processor, cause the one or more processors to receive vibration data from the building equipment, generate a performance prediction for the building equipment, generate a performance explanation for the performance prediction, and cause a user interface to display the performance prediction and the performance explanation.

Abstract: An illustrative fracture mapping system includes: a data acquisition unit collecting measurements deformation measurements during a fluid injection phase of a hydraulic fracturing operation; and a processing system implementing a formation mapping method. The formation mapping method includes: obtaining an initial fracture map having a location and geometry for one or more fractures activated during the fluid injection phase, the fracture map corresponding to a given time during the hydraulic fracturing operation; deriving from the initial fracture map a time series of fracture maps for times preceding the given time; and storing the time series on a nonvolatile information storage medium. The deriving may be performed in an iterative fashion to obtain each fracture map in the time series from a subsequent fracture map.

Abstract: An asset management system that includes a field asset management system; a maintenance management system; and a digital avatar associated with a specific asset. The digital avatar has an automatic Model that is customized for the associated asset. The digital avatar automatically receives information from at least one of the field asset management system or maintenance management system as information associated with the asset is entered into the at least one of the field asset management system or maintenance management system. The automatic Model automatically runs with the new information and provides a new operating parameter for use by at least the field asset management system.

Abstract: A method of visualizing drilling information in a shared visualization environment include receiving a request to initiate a shared visualization session, assigning the requesting client device as the master of the initiated session, and transmitting visualization data to the client device for rendering and display. Additional client devices may join the visualization session and may display the visualization data based on attributes controlled by the master client device. Data displayed in a visualization session may include two- and three-dimensional data representing a composite wellbore derived from actual and planned wellbore data. Generation of the two- and three-dimensional data may include projecting data corresponding to the composite wellbore onto flat and curved planes and may further include supplementing the composite wellbore data with seismic and other drilling-related data.

Abstract: A method and system for modeling a fracture geometry. The method may comprise taking one or more pressure measurements from an offset wellbore, identifying a pressure trend of the offset wellbore, and comparing the one or more pressure measurements to the pressure trend to identify a poro-elastic trend. The method may further comprise creating a poro-elastic model of a target wellbore from the poro-elastic trend, identifying the fracture geometry of a fracture in the target wellbore from at least the poro-elastic trend, and comparing the fracture geometry to a target fracture geometry. The system may comprise a pressure measurement device disposed in an offset wellbore, one or more pieces of equipment configured for a fracture operation and connected to a target wellbore, and an information handling system.

Abstract: A process for the exploitation of a deposit of hydrocarbons by injection of an aqueous solution with polymer includes calibration of the constants involved in an analytical expression of a model for displacement of the polymer which is a function of at least the concentration and of another parameter, such as the salinity, the shear rate and the temperature.

Abstract: One aspect includes a method for determining a drilling plan for new wells in a reservoir. The method includes categorizing the new wells into at least a first new well and a second new well, such that a drilling location for at least the first new well must be determined imminently, but a drilling location for at least the second new well can be determined at a later time. The method further includes determining potential drilling locations for the second new well, determining the drilling location for the first new well based at least in part on the determined potential drilling locations for the second new well, and outputting the drilling plan comprising the determined drilling location for the first new well and the determined potential drilling locations for the second new well.

Abstract: Methods, network nodes and wireless devices for determining a virtual cell index field length. According to one aspect, a method of determining a length of a virtual cell index field to be transmitted with downlink control information, DCI, is performed where the virtual cell index field length for transmitting a virtual cell index to a wireless device is dynamically settable. The method includes determining a number of configured virtual cell identities, ID. The method includes transmitting the configured virtual cell identities to the wireless device. When a number of configured virtual cell IDs is greater than one, the method includes selecting a virtual cell index corresponding to a particular one of the virtual cell IDs and setting the virtual cell index field length based on the number of virtual cell IDs. The method includes transmitting the selected virtual cell index in the virtual cell index field to the wireless device.

Abstract: Systems and methods for damping torsional oscillations of downhole systems are described. The systems include a damping system configured on the downhole system. The damping system includes a first element and a second element in frictional contact with the first element. The second element moves relative to the first element with a velocity that is a sum of a periodic velocity fluctuation having an amplitude and a mean velocity, wherein the mean velocity is lower than the amplitude of the periodic velocity fluctuation.

Abstract: A method may include obtaining a plurality of historical drilling signals for a plurality of wells. At least one historical drilling signal among the plurality of historical drilling signals describes a drilling surface parameter that is measured during a respective drilling operation. The method may further include generating a first drilling signal while drilling a wellbore through a formation. The method may further include determining a first drilling correlation between the first drilling signal and the plurality of historical drilling signals. The method may further include determining a drilling hazard condition within a well path of the wellbore using the first drilling correlation. The method may further include adjusting, based on the drilling hazard condition, the well path of the wellbore.

Abstract: A method for detecting wellbore inflows can include detecting a plurality of temperature values within a wellbore, wherein each temperature value corresponds to a different depth within the wellbore and the temperature values are detected with a distributed temperature measuring technique. The method can also include calculating a plurality of proxy temperatures, wherein each proxy temperature corresponds to one of the temperature values and a reference temperature value. The method can also include calculating a continuous wavelet transform based on the plurality of proxy temperatures. Additionally, the method can include identifying a wellbore inflow based on a combination of the continuous wavelet transform and a wellbore schematic, and generating an alert indicating a location of the wellbore inflow within the wellbore.

Abstract: A data processing system is provided which determines the migration of oil and gas by a basin simulation section and predicts future reservoir performance from current reservoir production measures. The data processing system provides more accurate reservoir rock and fluid property distribution in reservoir locations between well locations where such attributes cannot be measured. The data processing system operates based on physical realities captured from migration by the basin simulation section. The data processing system differs from conventional methods, which use measurements obtained at the wells and interpolate between for regions between the wells using statistical techniques. Results from the data processing system shed more light into reservoir discontinuities among the wells, and yield better distribution of hydrogen sulfide, tar zones (Heavy Oil) within the reservoir.

Abstract: Contact angles of multi-phase mixtures in a porous medium are determined by comparing images generated by flow simulations with a measured image of a fluid flow in the porous medium. A measured image can be compared image element by image element with corresponding locations in the flow simulations. A plurality of flow simulations associated with a corresponding plurality of contact angles is used for the comparison, and a contact angle associated with the greatest number of matches between the measured image and the flow simulation is selected.

Abstract: The invention discloses a method for simulating the discontinuity of the hydraulic fracture wall in fractured reservoirs, comprising the following steps: establish a physical model of the natural fracture; establish a hydraulic fracture propagation calculation equation; establish a natural fracture failure model, calculate the natural fracture aperture, and then calculate the natural fracture permeability, and finally convert the natural fracture permeability into the permeability of the porous medium; couple the hydraulic fracture propagation calculation equation with the permeability of the porous medium through the fracture propagation criterion and the fluid loss to obtain a pore elastic model of the coupled natural fracture considering the influence of the natural fracture; work out the stress and displacement distribution of the hydraulic fracture wall with the pore elastic model of the coupled natural fracture, and analyze the offset and discontinuity of the hydraulic fracture wall according to the dis

Abstract: A method including: defining a model space within which all subsurface models are in general local isostatic equilibrium; generating a representative set of trial models which span the model space, wherein a requirement that all of the trial models be in isostatic equilibrium provides a constraint that narrows a range of solutions that fit observed gravity data, wherein the trial models provide scenarios of Earth's crustal geometry, and crust and mantle rock properties; and determining, within an inversion process, a model solution based on minimizing a misfit between the observed gravity data and synthetic gravity data generated from at least one of the trial models.

Abstract: A method is described for estimating hydrocarbon reservoir attributes including obtaining a geophysical dataset and a geological dataset; obtaining a parameter model, the parameter model having been conditioned by training an initial parameter model using training data, wherein the geological data includes well data and the training data includes the well data; picking a surface in the geophysical dataset; assigning stratigraphic meaning to the at least one surface based on the geological dataset; identifying at least one region of interest on the at least one surface; generating statistical seismic attributes for the at least one region; identifying critical attributes among the statistical seismic attributes by applying the parameter model to generate response variable maps for the at least one region; and generating uncertainty maps for each of the critical attributes and for the response variables. The method may be executed by a computer system.

Abstract: The present disclosure is directed to systems and methods for estimating rotational velocity and/or torque of a drill bit during certain drilling operations using torque and rotational velocity measured at a top drive system of the drilling operations. In certain embodiments, a drilling control system may estimate the rotational velocity and/or the torque of the drill bit using torque and rotational velocity detected at the top drive system, in conjunction with the governing equations of the drill string, the top drive, and the bottom hole assembly (including the drill bit itself), which may be transferred into the Laplace domain. In other embodiments, the drilling control system may estimate the rotational velocity and/or the torque of the drill bit using the torque and rotational velocity detected at the top drive system, in conjunction with a finite dimensional model approximation of the drill string based on an assumed mode shape of the drill string or a finite element model of the drill string.

Abstract: Earth models of stress conditions in subsurface reservoirs are formed reflecting rock mechanical properties, stress regime and also wellbore stability. A number of variables related to the rock mechanical properties and stress conditions are parameterized. The variability of minimum horizontal stress magnitudes as a product of the relative contributions of the various rock properties and input parameters or variables used to form the model is analyzed. Differences between predicted minimum horizontal stress magnitudes in the formation and an actual measurement obtained from the formation (for example, fracture closure pressure) are determined. The determined differences are the minimized through an optimization methodology to find a best set of parameters suitable to match the minimum horizontal stress to actual formation measurement.

Abstract: A system and method of evaluating a subterranean earth formation using a statistical distribution of formation data. The system comprises a logging tool and a processor in communication with the logging tool. The logging tool comprises a sensor operable to measure formation data and is locatable in a wellbore intersecting the subterranean earth formation. The processor is operable to calculate inversion solutions to the formation data, wherein each inversion solution comprises values for a parameter of the formation, and generate a statistical distribution of the parameter along one or more depths in the subterranean earth formation using the inversion solutions. The processor is also operable to identify peaks within the statistical distribution and select the inversion solutions corresponding to the identified peaks, generate a formation model using the selected inversion solutions; and evaluate the formation using the formation model to identify formation layers for producing a formation fluid.

Abstract: Systems and methods for estimating reservoir productivity as a function of position in a subsurface volume of interest are disclosed. Exemplary implementations may: obtain subsurface data and well data corresponding to a subsurface volume of interest; obtain a parameter model; use the subsurface data and the well data to generate multiple production parameter maps; apply the parameter model to the multiple production parameter maps to generate refined production parameter values; generate multiple refined production parameter graphs; display the multiple refined production parameter graphs; generate one or more user input options; receive a defined well design and the one or more user input options selected by a user to generate limited production parameter values; generate a representation of estimated reservoir productivity as a function of position in the subsurface volume of interest using the defined well design and visual effects; and display the representation.

Abstract: A system and method are provided for correlating well log data and seismic data corresponding to subterranean formations to generate a seismic well tie that preserves blocking schemes associated with the well log data and constraints corresponding to each block of samples. The seismic well tie may be generated by correlating samples of the well log data with the seismic data by shifting at least some of the samples and using the constraint on changes to the sample values to prevent the sample values of each of the one or more blocks of the samples from changing beyond the constraint. In some aspects, the constraints may relate to a constant velocity or a linearly changing velocity within various blocks of the well log data.

Abstract: Presented is a computerized method for management of a slurry injection well and the associated surface facility. The method utilizes real time and historical data of injection and slurry parameters in conjunction with computer simulations on a computer-modelled reservoir to predict well behavior during one or a series of injection events. The system determines optimized injection operation schedules, recommends and implements changes to an injection operation, including while in process such as through automated equipment control.

Abstract: Embodiments of the present disclosure aim to provide advanced log scale permeability estimation systems and methods. In an embodiment, a computer system is provided and configured to perform petrographic thin section image permeability analysis and then generate log scale permeability estimations for a well using machine learning methods and techniques. In an embodiment, the advanced log scale permeability estimation systems and methods are configured with a computer system or a micro-computer system, that can be configured with a computer circuit board comprising a processor, memory, networking capability, and software. In another embodiment the log scale permeability estimations for a well are input into a reservoir simulation model to determine hydrocarbon resources and to make portfolio predictions for a well.

Abstract: A method for identifying a location of a distributed acoustic system channel in a distributed acoustic system. The method may comprise generating a two or three dimensional layer model interface with an information handling system, preparing a P-wave first arrival pick time table, estimating an initial model layer properties, estimating a location of the distributed acoustic system channels, preparing an overburden file of layer properties, running an anisotropic ray tracing, defining an upper and a lower limits for model parameters, specifying parameters for the inversion, running an inversion, selecting a solution based at least in part on stored error predictions, and calculating a mean and a standard deviation of an inverted model parameter.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for models the accumulation and migration of hydrocarbons. One computer-implemented method includes: identifying one of grid cells neighboring an accumulation as a recent back-filled grid cell; setting an oil phase potential of identified grid cell as an accumulation potential of the accumulation; comparing oil phase potentials of grid cells neighboring the recent back-filled grid cell with the accumulation potential of the accumulation, where the oil phase potential of each of the grid cells neighboring the recent back-filled grid cell is stored as a key in the node corresponding to the respective grid cell; selecting one of the grid cells neighboring the accumulation as a next back-filled grid cell; and updating the accumulation potential of the accumulation based on the oil phase potential of the selected grid cell.

Abstract: Electric Grid Analytics Learning Machine, EGALM, is a machine learning based, “brutally empirical” analysis system for use in all energy operations. EGALM is applicable to all aspects of the electricity operations from power plants to homes and businesses. EGALM is a data-centric, computational learning and predictive analysis system that uses open source algorithms and unique techniques applicable to all electricity operations in the United States and other foreign countries.

Abstract: An illustrative domain-adaptive simulator includes: a data acquisition module, a simulator module, and a visualization module. The data acquisition module acquires measurements of a physical system. The simulator module provides a series of states for the physical system, the series including at least a current state and a subsequent state, wherein as part of said providing, the simulator module implements a method that includes: (a) constructing a modeled domain for the system; (b) determining a domain of influence within the modeled domain; (c) generating a linear set of equations to derive the subsequent state from the current state, the linear set of equations excluding a region of the modeled domain outside the domain of influence; and (d) deriving the subsequent state from the linear set of equations. The visualization module displays the series of states.

Abstract: The invention relates to a method for determining a maximum allowable volume of water that can be removed over time from an underground water source, the volume of water being removed at a removal point and the hydrogeological state of the underground water source being qualified by piezometric measurements on a reference piezometer, the method being characterized in that it includes, in particular, a continuous measurement by a first piezometric level sensor on the removal point, the sensor having a first log of available data over a predetermined period that has passed; and another continuous measurement by a second piezometric level sensor on the reference piezometer, the second sensor having a second log of available data over the predetermined period that has passed; the method also comprising subsequent steps implemented by a calculation machine.

Abstract: A real-time monitoring apparatus for seafloor deformation during hydrate exploitation, includes a main frame, a detecting device, and a sensing and wireless data transmitting device. The detecting device includes at least two detecting straight rods in different directions; the detecting straight rods are connected to the main frame through the movable sleeves; and at least two fixing supports are configured below each detecting straight rod, perpendicular to and uniformly distributed along the detecting straight rod. A movable lever is configured above each detecting straight rod, the movable lever is connected to the main frame through the lever-fixing rod, and a stretchable and compressible spring is configured at an upper end of the movable lever. The sensing and wireless data transmitting device includes at least two tension and compression force sensors in different directions, a gyroscope sensor, a wireless data transmitter, and a power source, all mounted in the main frame.

Abstract: Described herein are various embodiments of computer-implemented methods, computing systems, and program products for analyzing a flood operation on a hydrocarbon reservoir. For example, an embodiment of a computer implemented method of analyzing at least a first flood operation and a second flood operation. The embodiment includes, for each flood operation: receiving production data and injection data, running capacitance resistance modeling, using the generated response times, the generated interwell connectivities, the received production data, the received injection data, or any combination thereof to generate a proxy of pore volume swept per well pair, and aggregating the generated proxies to generate an estimate of pore volume swept at a well level, at a reservoir level, or both for the flood operation. The embodiment also includes comparing the generated estimate of pore volume swept to determine a change in sweep efficiency at the well level, at the reservoir level, or both.

Abstract: Systems and methods for real-time optimization of stimulation treatments in a hydrocarbon reservoir by controlling a simulated stimulation treatment schedule for a main fracture stimulation treatment stage using a predicted net pressure in a cluster of fractures representing a dominant fracture for the main fracture stimulation treatment stage.

Abstract: A method and system are described for creating and using a subsurface model. In this method, selected subregion are morphed to adjacent subregions to create a morphed surface and solid elements are created based on the selected subregion and the morphed surfaces. The resulting subsurface model may be used in simulations and hydrocarbon operations.

Abstract: Certain aspects and features relate to a system that projects an optimized foam-fluid-application scenario for to stimulate production from a hydrocarbon well. The optimized scenario can include a recommended chemical make-up for the foam entity as well as application parameters such those related to timing and duration. A hybrid discrete fracture network and multi-porosity (DFN-MP) model for fluid interaction with the formation where the well is located can be produced by a processing device. The hybrid DFN-MP model can be optimized using field simulation data for the formation. The optimized hybrid DFN-MP model can be used by the processing device to produce an optimized foam-fluid-application scenario, which can be communicated to at least one well and can be utilized to stimulate the well for increased production.