Abstract: Systems and methods of real-time in-situ sub-surface imaging are described herein.

Abstract: An embodiment of an apparatus for estimating and displaying formation and formation fluid properties includes a sampling device coupled to borehole fluid, the borehole fluid including hydrocarbons released from a region of the formation surrounding an interval of the borehole. The apparatus also includes an analysis unit configured to analyze the sample of the borehole fluid at each of a plurality of sample times and estimate amounts of hydrocarbons in the borehole fluid, and a processing device configured to estimate one or more ratios of an amount of at least one hydrocarbon gas to an amount of at least another hydrocarbon gas at each sample time, analyze the one or more ratios to estimate a type of hydrocarbon fluid associated with the ratio, and automatically generate a fluid log that displays an indication of the type at each of the plurality of sample times.

Abstract: A method to determine at least one formation property of a subterranean formation includes providing a downhole electromagnetic logging tool having at least one transmitter array and one receiver array to acquire measurements in the formation. The method further includes performing a first inversion in response to the measurements, assuming dip or dip azimuth is constant in an inversion zone within the formation to obtain an inverted formation model. The method includes determining an n-th order partial derivative matrix of at least one of dip or dip azimuth, wherein n is greater than or equal to 1. The method includes performing a second inversion using the determined n-th order partial derivative matrix, wherein at least one of dip and dip azimuth are allowed to vary in the inversion zone, to obtain an updated formation model. The method includes determining the formation property using the updated formation model.

Abstract: An Earth model of a subsurface is created from acquired seismic data by migrating at least one of the incident wavefields and reflected wavefields to generate angle gathers for the seismic data and identifying for the subsurface an elastic Earth model equation for the incident wavefields and the reflected wavefields in the acquired seismic data. The elastic Earth model is a function of reflection angle between the incident wavefields and reflected wavefields and elastic parameters and is fit to the generated angle gathers through perturbation in the elastic parameters. The generated perturbations are used to create the Earth model of the subsurface.

Abstract: A method to estimate water saturation in electromagnetic measurements includes making an electromagnetic measurement and performing at least one of (a) creating an analytical forward model of the EM measurement, (b) creating a numerical finite difference forward model of the EM measurement, and (c) performing an inversion. The method also includes removing at least one petrophysically-adverse alteration of EM measurements in the frequency range from 1 Hz to 100 MHz. A petrophysically-adverse alteration is due to the presence of at least one of the following: pyrite, graphitic-precursors, magnetite, and other conductive minerals.

Abstract: Embodiments include constructing a reservoir model of an earth formation. The method may also include selecting a predetermined set of fundamental parameters to describe the earth formation and assigning initial values for the predetermined set of fundamental parameters for each of the plurality of layers. The method may include using the initial values for each of the plurality of layers. The method may include computing physical-response-relevant properties as a function of space and time for each of the plurality of layers using the solutions and then computing tool responses using the physical-response-relevant properties. The method may include installing an electrode array between an insulation portion of a metal casing provided in a borehole and a physical formation and obtaining formation measurement information from the electrode array, comparing the formation measurement information to the computed tool response to obtain an error signal and modifying the initial values in an iterative process.

Abstract: Systems and methods for determining operating settings for a fluid production system that includes wells and a processing facility, the method including identifying at least one swing well and one or more non-swing wells and determining at least one target parameter equation that is a function of at least one processing facility constraint and one or more non-swing well parameters. The method further includes incorporating the target parameter equation into a fully-coupled equation set representing the production system, simulating the production system using the fully-coupled equation set to obtain one or more operating settings that meet the processing facility constraint, and presenting to a user the operating settings.

Abstract: Determining a Reservoir Management Factor™ (RMF™ or ?) for a petroleum producer provides a novel metric, selection, design, implementation and monitoring tool designed for use in implementing capital projects for increasing production and reserves of the petroleum producer. The RMF or ? can be determined according to the following equation: ?=sum of regression coefficients=sum of (reserves coefficient, production coefficient) wherein, reserves coefficient=the coefficient of the petroleum producer's reserves; and production coefficient=the coefficient of the petroleum producer's production. The producer can based on the RMF, select, design, implement and monitor one or more capital projects for increasing production and reserves of the petroleum producer. The capital projects can include drilling additional wells, stimulating existing wells, and increasing reservoir contact of existing wells.

Abstract: Methods, apparatuses, and systems are disclosed that reduce seismic noise. In one embodiment, a method of processing seismic data includes accessing seismic data representative of a plurality of seismic input traces acquired by one or more seismic sensors. The method also includes stacking the plurality of seismic input traces into a stacked trace. The method also includes generating, utilizing at least one processor unit, a function of similarity between at least two of the plurality of seismic input traces. The method also includes scaling at least one of the seismic input traces or the stacked trace with the function of similarity.

Abstract: In order to determine characteristics of a gas-oil transition zone in a gas capped oil reservoir, samples of a reservoir fluid from a gas and an oil part of the reservoir are taken. To configure an equation of state of hydrocarbon mixtures, reservoir temperature and pressure are measured in places where the samples of the reservoir fluid are taken and densities and compositions of the samples are determined. Porosity, water saturation and total hydrogen content of a saturated rock are measured along the wellbore and a volume and a hydrogen content of hydrocarbon phases are determined. Using the equation of state, density and composition of the hydrocarbon phases are computed and a specific hydrogen content in gas and oil along the wellbore is determined. Gas and oil saturation distribution along the wellbore is determined from the determined specific hydrogen content, determined hydrogen content of the hydrocarbon phases and the measured porosity.

Abstract: A method is described for a method for depositional modeling dependent on geological boundary conditions including receiving a process-based depositional model of a siliciclastic formation; determining a type of boundary condition at each boundary of the process-based depositional model wherein the boundary condition on at least one boundary is one of a flux-preserving boundary condition or a discrete boundary condition and wherein the boundary condition accounts for at least one of time-varying inflow of water and sediments into the process-based depositional model, time-varying outflow of water and sediments out of the process-based depositional model, and downstream controls; modeling rates of sediment and water flow over time, dependent on the boundary condition, to create a modeled depositional system; and analyzing the modeled depositional system to identify potential hydrocarbon reservoirs. The method may be executed by a computer system.

Abstract: Example of systems and methods are provided for visualization of multi-dimensional geophysical data visualization. Combining several attributes from multi-dimensional geophysical data or seismic data using color modeling techniques provide for the interpretation of data more efficiently by a user. A color space is defined and multi-dimensional geophysical data attributes are created along with blending filters, such as asymmetric blending filters. Blended multi-dimensional geophysical data attribute cubes are created from the blending filters and the geophysical data attributes. The blended multi-dimensional geophysical data attributes or cubes are displayed using the defined multi-dimensional color space.

Abstract: A method, apparatus, and program product utilize a generalized grid cell pinchout operation to remove small cells from a reservoir simulation grid, e.g., prior to running a reservoir simulation. The generalized grid cell pinchout operation may utilize a connectivity matrix representing transmissibilities of one or more “pinch” cells to be removed as well as that of “background” cells that neighbor the pinch cells. Removal of the pinch cells includes determining a Schur complement of the connectivity matrix to generate a reduced connectivity matrix from the connectivity matrix.

Abstract: In accordance with embodiments of the present disclosure, systems and methods for downsampling DAS data in a way that enables accurate interpretation of acoustic events occurring in the data are provided. Such methods may be particularly useful when interpreting large sets of data, such as DAS VSP data collected during hydrocarbon recovery operations. The methods generally involve identifying data channels affected by noise from a DAS data set, and then interpolating from the surrounding data. This may improve the quality of the resulting downsampled data, with respect to the signal to noise ratio, compared to what would have occurred by merely decimating unwanted data channels. In addition, a priori information about channel fading, the desired downsampling rate, and the slowest expected elastic waves may be used to filter the DAS data. This may achieve a higher signal-to-noise ratio in the downsampled data.

Abstract: In a general aspect, a subterranean region is simulated using a finite element mesh and a boundary element mesh. In some aspects, a finite element mesh is generated over a domain representing a subterranean region. The finite element mesh defines elements that represent respective sub-regions of the subterranean region. The elements include a first element having a boundary defined by the finite element mesh, and at least a portion of the boundary of the first element represents a discontinuity in the subterranean region. A boundary element mesh is generated over the boundary of the first element, and the subterranean region is simulated using the finite element mesh and the boundary element mesh.

Abstract: Predicting future hydrocarbon production. At least some of the illustrative embodiments are methods including: reading data regarding hydrocarbon production from a hydrocarbon producing field; producing at least one value indicative of future hydrocarbon production based on a data model and the data regarding hydrocarbon production; displaying, on a display device of a computer system, an indication of historic data regarding hydrocarbon production; and displaying, on the display device, an indication of the at least one value indicative of future hydrocarbon production.

Abstract: A system may include a well device to control a flow of hydrocarbons extracted from a well and a monitoring device to receive data associated with one or more properties of the well and the well device. The monitoring device is disposed on the well device and receives pressure data and temperature data associated with the well device. The monitoring device may then determine an inflow performance relationship, a tubing performance relationship, a choke performance relationship, and a wellhead performance relationship, or any combination thereof based on the pressure data and the temperature data. The monitoring device may also generate at least one plot that illustrates the inflow performance relationship, the tubing performance relationship, the choke performance relationship, and the wellhead performance relationship, or any combination thereof. The monitoring system may then display the at least one plot on a display device disposed on the monitoring system.

Abstract: Data arrangement schemes of imagery data and filter coefficients stored in a CNN based digital IC for extracting features out of an input image are disclosed. The CNN based digital IC contains NE number of CNN processing engines connected in a loop via a clock-skew circuit for cyclic data access. Imagery data and filter coefficients are arranged in a specific scheme to fit the data access pattern that the CNN based digital IC requires to operate. The specific scheme is determined based on the number of imagery data, the number of filters and the characteristics of the CNN based digital IC. The characteristics include, but are not limited to, the number of CNN processing engines, the connection direction of clock-skew circuit and the number of the I/O data bus.

Abstract: A computer accepts dead-oil properties of a reservoir fluid sampled from a well. The dead-oil properties are the measured composition of the reservoir fluid after volatile components of the reservoir have substantially vaporized. The computer analyzes the dead-oil properties and a constraint to produce estimated live-oil properties of the reservoir fluid. The live-oil properties are the composition of the reservoir before the volatile components have substantially vaporized. The computer uses the estimated live-oil properties to make a decision regarding the well.

Abstract: A method can include building a network model that represents a production system for fluid, assigning equations to sub-networks in the network model where at least one of the sub-networks is assigned equations formulated for solving for enthalpy implicitly or temperature implicitly, providing data, transferring the data to the network model and simulating physical phenomena associated with the production system using the network model to provide simulation results. Various other technologies, techniques, etc., are also disclosed.

Abstract: Apparatus and associated methods relate to a decline curve analysis method for predicting oil and gas production from an oil well, where a prediction curve for oil and/or gas data transitions from a first characteristic function to a second characteristic function at the bubble point. In an illustrative example, the first and second characteristic functions may be of the monotonically decreasing type. A distinction between the two characteristic functions may be that the absolute value of the decline for the second characteristic function is greater than or equal to the absolute value of the decline of the first characteristic function for each value of time and/or cumulative oil/gas past the bubble point. In various embodiments, the method may give more accurate predictions for oil and/or gas production once the stimulated reservoir volume reaches the bubble point.

Abstract: The disclosure relates to an apparatus and a method for well logging as well as a data processing device thereof. Said apparatus for well logging comprises a drill collar body and an array of antennas, wherein said array of antennas comprises at least a pair of transmitting antenna and receiving antenna, said transmitting antenna and receiving antenna are configured for generating a curve of axial forward depth of investigation. By employing the method for well logging according to the present invention, not only the variation of resistivity in the axial forward formation may be measured in real time during the drilling, but also the interfacial characteristics of the axial forward formations having different resistivity may be discriminated during drilling.

Abstract: A system, method and a computer program product for to determining energy production controls for a given subterranean hydrocarbon (oil) field production and more particularly to specifying controls for sustaining optimal field production (by means of a plateau-like profile over time).

Abstract: Systems and techniques are disclosed for flexible, secure energy management that enable control of individual devices in a customer site's energy infrastructure, which can allow optimization (e.g., by minimizing energy cost or usage) across the infrastructure. A system management component may centralize optimization and control capabilities across the energy infrastructure by determining an energy model and directing consumption, storage, and energy draw activities for the totality of the energy infrastructure devices. Systems may include modular, secure terminal devices that can be attached to or paired with the devices in an energy infrastructure in order to provide input data such as power load metrics, as well as to control the operation of the devices. A dynamic, adaptive prediction of system parameters, such as future demand, cost, generation capacity, and other metrics, may be provided. Dynamic, adaptive prediction may be performed without detailed historical usage data.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for generating facies definition. One embodiment is a computer-implemented method that includes the steps of receiving well logging data indicative of one or more properties of geologic formations penetrated by one or more wellbores, wherein no assumptions are being introduced to the well logging data; determining a type well; developing an appropriate scaling of the well logging data based on the type well; creating a training set by drawing samples from the well logging data at random depths; modifying the training set to remove interfering data; performing an unsupervised classification procedure on the training set to group samples in the training set; comparing a suite of values of the well logging data in the groups to classify lithofacies of the type well; develop classification functions; and classifying unknown wells using the classification functions to generate the facies definition.

Abstract: The method of monitoring carbon dioxide leakage in carbon capture and storage reservoirs estimates porosity and water saturation in a porous medium, such as brine-saturated shale, as is common in carbon capture and storage reservoirs, based upon measured electrical conductivity and seismic P-wave velocity. The estimated porosity and water saturation may be used for monitoring carbon dioxide leakage from a carbon dioxide reservoir to the overlying cap rock of the region. Measured electrical conductivity and seismic P-wave velocity data are used by the present method to estimate the porosity and water saturation in the cap rock. If a decrease in water saturation in the cap rock is found, this indicates that carbon dioxide may be leaking up from the carbon dioxide reservoir. An alert signal is then generated to indicate that there may be a carbon dioxide leak.

Abstract: System and methods of simulating fluid production in a multi-reservoir system with a common surface network are presented. An equation of state (EOS) characterization of fluids is matched with a delumped EOS model representing different components of the fluids for each reservoir within the multi-reservoir system. Fluid production in the multi-reservoir system is simulated for at least one simulation point in the common surface network, based in part on the delumped EOS model for each reservoir. If the fluids produced during the simulation at the simulation point are mixed fluids from different reservoirs, one or more interpolation tables representing the mixed fluids are generated and properties of the mixed fluids are calculated based on the generated interpolation tables. Otherwise, the properties of the fluids are calculated using the delumped EOS model corresponding to the reservoir from which the fluids are produced.

Abstract: A flush lever comprises a handle and a skirt, or escutcheon plate, both disposed to the exterior of a toilet tank. Within the tank is a flush lever subassembly, the subassembly taking one of two different embodiments and each embodiment comprising means for mechanically linking the flush lever with the subassembly. One portion of the flush lever can be variably adjustable within 360° of rotation and by adjustments every 15° for optimal placement of the flush lever as desired or required. Another portion of the flush lever can be variably adjustable within 180° of rotation as well and by adjustments also every 15°.

Abstract: Determining a True Value Index™ (TVI™) for a petroleum production capital project provides a novel indicator and metric that is designed to quickly assess the economics of undertaking the petroleum production capital project. The TVI™ can be determined according to the following equation: TVI=NPV+(?*Reserves) where, NPV=Net present value of a project; ?=Reservoir Management Factor (RMF™)=absolute value (sum of Coefficient of Reserves and Coefficient of Production) derived from multivariable correlation=to reflect the market value premium on increased reserves if the producer was public; and Reserves=Barrels of proven reserves to be created by the project.

Abstract: There is provided a method for modelling a hydrocarbon reservoir that includes generating a reservoir model that has a plurality of sub regions. A solution surrogate is obtained for a sub region by searching a database of existing solution surrogates to obtain an approximate solution surrogate based on a comparison of physical, geometrical, or numerical parameters of the sub region with physical, geometrical, or numerical parameters associated with the existing surrogate solutions in the database. If an approximate solution surrogate does not exist in the database, the sub region is simulated using a training simulation to obtain a set of training parameters comprising state variables and boundary conditions of the sub region. A machine learning algorithm is used to obtain a new solution surrogate based on the set of training parameters. The hydrocarbon reservoir can be simulated using the solution surrogate obtained for the at least one sub region.

Abstract: A kinetic penetrator for multistatic geophysical sensing includes a tubular body having a first end and a second end, a nose coupled to the first end of the tubular body, and a sensing element coupled to at least one of the tubular body and the nose. The nose is configured to penetrate a ground surface and subsurface materials of a subterranean ground volume. The sensing element is configured to interface with an external geophysical sensing system.

Abstract: A method of processing geological log data to construct missing information from destroyed or occluded parts using cues from observed data comprises the steps of: a. in respect of one or more data dimensions associated with missing values in a log data set, decomposing the signal into a plurality of morphological components; and b. morphologically reconstructing the signal such that missing values are estimated.

Abstract: A hydrocarbon exploration method for determining subsurface properties from geophysical survey data. Rock physics trends are identified and for each trend a rock physics model is determined that relates the subsurface property to geophysical properties (103). The uncertainty in the rock physics trends is also estimated (104). A geophysical forward model is selected (105), and its uncertainty is estimated (106). These quantities are used in an optimization process (107) resulting in an estimate of the subsurface property and its uncertainty.

Abstract: The invention is a method for optimizing the development of a fluid reservoir using a fractured medium mesh generated from a first-order balanced octree technique is disclosed. A mesh of a discrete fracture network generated by defining a set of cells for each fracture and then a mesh of the matrix medium is generated by dividing each cell by an octree technique, wherein a cell is divided into eight cells. The transmissivities between the cells of the fracture mesh, transmissivities between the cells of the matrix medium mesh and transmissivities between cells of the fracture mesh and cells of the matrix medium mesh are then determined. Finally, the cells and the transmissivities are used for generating an image of the fluid reservoir from which the development of the fluid reservoir is optimized.

Abstract: Systems and methods to initiate a verification test within a flow meter via a flow computer are disclosed. An example method includes communicating, via a flow computer, a request to a flow meter to initiate a verification test of the flow meter. The example method also includes retrieving diagnostic data from the flow meter. The example method further includes logging a result of the verification test in a log of the flow computer, the result based on the diagnostic data.

Abstract: Systems and methods to initiate a verification test within a flow meter via a flow computer are disclosed. An example method includes communicating, via a flow computer, a request to a flow meter to initiate a verification test of the flow meter. The example method also includes retrieving diagnostic data from the flow meter. The example method further includes logging a result of the verification test in a log of the flow computer, the result based on the diagnostic data.

Abstract: Various examples are provided for wavefield extrapolation in anisotropic media. In one example, among others, a method includes determining an effective isotropic velocity model and extrapolating an equivalent propagation of an anisotropic, poroelastic or viscoelastic wavefield. The effective isotropic velocity model can be based upon a kinematic geometrical representation of an anisotropic, poroelastic or viscoelastic wavefield. Extrapolating the equivalent propagation can use isotopic, acoustic or elastic operators based upon the determined effective isotropic velocity model. In another example, non-transitory computer readable medium stores an application that, when executed by processing circuitry, causes the processing circuitry to determine the effective isotropic velocity model and extrapolate the equivalent propagation of an anisotropic, poroelastic or viscoelastic wavefield.

Abstract: A method of increasing near-wellbore rock strength so as to mitigate or remediate lost circulation events through increased hoop stress in the near-wellbore in a subsurface formation comprises a) cooling a near-wellbore region of the formation, b) allowing a lost circulation material to enter the cooled near-wellbore region; and c) heating the near-wellbore region.

Abstract: Methods and apparatuses for processing seismic data to generate images or determine properties of an interior section of the Earth. The seismic data is processed to filter coherent noise such as ground roll noise from seismic survey data. The noise is attenuated using 3D and/or 2D fan filters, which may have combined low-pass and band-pass filters derived from signal decomposition. The filters are designed with selected operator length, velocity bands of signals and noises and frequency range for a primary trace and adjacent traces within the operator length. The data is decomposed with the filters into signals and noises, and the noises are then filtered from the decomposed data. The process may be repeated for various frequencies and traces within the seismic data. The methods may be used for surveys that have either regular or irregular seismic receiver or seismic source positions.

Abstract: A filter coefficient group computation device is configured from a means for performing inverse Fourier transform on a frequency characteristic inputted through an input means; a means for performing short-term Fourier transform on a numerical string obtained by the inverse Fourier transform; a means for performing windowing on a frequency domain signal, obtained by the short-term Fourier transform, using a function of which a window length shortens as frequency increases; a means for performing short-term inverse Fourier transform on the frequency domain signal after the windowing; a means for performing overlap addition on a numerical string obtained by the short-term inverse Fourier transform; and a means for determining a numerical string after the overlap addition as a filter coefficient group which forms a filter having the frequency characteristic inputted through the input means.

Abstract: The invention is a method of developing a sedimentary basin from a stratigraphic simulation of multilithologic filling accounting for fine sediment transport. The sedimentary basin is divided into geologic layers with each geologic layer being subdivided into a series of climatic layers. Each climatic layer is associated with at least one constant climatic parameter. A stratigraphic simulation is performed within each climatic layer using a stratigraphic model. The sediment transport in the continental domain and sediment bottom layer transport in the marine and lacustrine domains are modelled using nonlinear diffusion equations under maximum erosion rate constraint. Suspended sediment transport in the marine and lacustrine domain is modeled using an advection-diffusion equation accounting for a particle fall rate and of a marine and lacustrine current velocity.

Abstract: A system determines a volumetric fraction of oil in a formation penetrated by a borehole, the formation comprising an unconventional reservoir. The system includes a carrier configured to be conveyed through the borehole and a geochemical tool disposed at the carrier and configured to determine a mineral makeup of the formation and excess carbon not apportioned to any mineral of the mineral makeup, the excess carbon being associated with kerogen and oil in the formation. An NMR tool disposed at the carrier determines porosity of fluid in the formation, the fluid excluding the kerogen in the formation. A density tool disposed at the carrier determines bulk density of the formation, and a processor determines the volumetric fraction of oil in the formation based on the excess carbon, the porosity of the fluid in the formation, and the bulk density of formation.

Abstract: Picking a fault in seismic data samples is described. In one example, a minimum spanning tree is used. In another example, input seismic attribute data is determined based on the seismic data samples. Seeds are selected that represent locations in the seismic volume using the attribute data. A principle grid is generated using the seeds. A fault is picked in the seismic volume by applying a least costs process, for example a minimum spanning tree, to the principle grid. The fault is then interpolated to generate a fault surface of the seismic volume.

Abstract: A method, system, and apparatus, including a program encoded on computer-readable medium, for detecting duplicate data files to be stored in a well job data archive includes identifying a well job data file for storage in a well job data archive and performing an initial duplicate check and a secondary duplicate check to determine if the well job data file is a duplicate of a data file stored in the well job data archive, as well as a quality assurance test of the file data. At least one of the well job data file or one or more of the data files stored in the well job data archive is identified as a duplicate data file based on the initial and secondary duplicate checks, and the well job data file is stored in the well job data archive in accordance with the initial and secondary duplicate checks and the identification of a duplicate data file.

Abstract: Methods for the determination of the Total Gas in Place (TGiP) in gas-bearing formations are provided. Aspects of the subject disclosure also relate to the determination of the TGiP from nuclear magnetic resonance (NMR) logs alone or in combination other well logs.

Abstract: Method for correcting OBC or deep-towed seismic streamer data for surface-related multiple reflections. The measured pressure data, preferably after conditioning (71), are simulated using a forward model that includes a water propagation operator between source locations and receiver locations and a term representing primary impulse responses (72). Other terms include direct arrivals and source wavelets. Iterative optimization of an objective function is used to minimize the difference between measured and simulated data, updating the primary impulse response term and optionally the source wavelets term each iteration cycle (73). The converged primary impulses (74) are used to construct simulated multiples and direct arrivals (75), which can be subtracted from the measured data. Optionally the measured data might be blended during the forward simulation (72), to save computational costs in the forward simulation (72) and in the inversion (73).

Abstract: Systems, methods, and computer-readable media are provided for modeling a fractured medium. The method includes generating, using a processor, a grid for the fractured medium, the fractured medium defining a first fracture and a second fracture, with the first fracture and the second fracture each represented by fracture cells in the grid. The method also includes determining a location where the first and second fractures intersect, the location being at least partially represented by an intersection cell of the fracture cells of the grid. The method further includes redistributing areas of the intersection cell and at least one other fracture cell, such that a size of the intersection cell is increased.

Abstract: An example method comprises collecting formation temperature data along a wellbore extending into a subterranean formation, determining test operating parameter values, performing a wellbore hydraulic simulation of the response of wellbore fluid conditions to the test operating parameter values and the formation temperature data, determining whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem, and initiating a test based on the determination whether the response of wellbore fluid conditions is indicative of one of a well control and a well stability problem.

Abstract: Systems, methods, and software can be used to determine a confidence value for a fracture plane. In some aspects, a subset of microseismic events associated with a fracture treatment of a subterranean zone are selected. Confidence in associating the selected subset of microseismic events with a common fracture plane is determined. The confidence can be determined, for example, based on the number of microseismic events in the subset, a location uncertainty for each microseismic event in the subset, a moment magnitude for each microseismic event in the subset, a distance between each microseismic event and a fracture plane fitted to the microseismic events, an orientation of the fracture plane fitted to the microseismic events, or a combination of these and other factors.

Abstract: Systems, methods, and computer programs for monitoring a drilling operation in a subterranean formation include receiving, from a first sensor array, one or more signals caused, at least in part, by the fracturing operation in the subterranean formation; receiving, from the first sensor array, one or more electromagnetic signals generated by an electroseismic or seismoelectric conversion of the seismic signals caused, at least in part, by the fracturing operation in the subterranean formation; and determining a property of one or more of a fracture or the subterranean formation based, at least in part, at least in part, on the signals received from the first sensor array. The first sensor array is arranged to monitor the fracturing operation.