Abstract: An injection treatment on a subterranean zone is simulated by modeling physically separate rock blocks of the subterranean zone by separate block models. The block model for each physically separate rock block represents intra-block mechanics of the rock block by finite element method. Condensation is performed in the finite element method to reduce nodal degrees of freedom operation on by the finite element method. Interactions between adjacent pairs of the rock blocks are modeled by separate joint models. The joint model for each adjacent pair of rock blocks represents inter-block mechanics between the adjacent rock blocks. The injection treatment of the subterranean zone is simulated with the block models and the joint models.

Abstract: A method, an apparatus and a computer readable medium for generating an image of a subsurface based on seismic data corresponding to at least two different times, for a same surveyed area are provided. A cost function, which is a sum over the seismic data vintages of a norm of differences between data and model predicted multiples, is minimized subject to minimizing residual multiples that are differences of corresponding multiples belonging to different vintages among the seismic data vintages.

Abstract: A method evaluating a cuttings density while drilling a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured while drilling and may be further processed to compute a cuttings density in the annulus. Moreover, changes in the computed interval density with time while drilling may be used as an indicator of a change in cuttings density.

Abstract: Methods, systems, and apparatus, including computer programs encoded on computer storage media, for fluid blob tracking. One of the methods includes identifying, by a computer system, a connected fluid phase region in a flow simulation. The method includes tracking, by the computer system, the connected fluid phase region over a first timeframe and a second timeframe. The method also includes determining, by the computer system, movement of the connected fluid phase region from the first timeframe to the second timeframe based on the tracking.

Abstract: A technique includes receiving a first dataset that is indicative of seismic data acquired in a seismic survey of a field of wells and receiving a second dataset that is indicative of wellbore data acquired in a wellbore survey conducted in at least one of the wells. The technique includes determining a mechanical earth model for the field based at least in part on the seismic data and the wellbore data.

Abstract: A system, method, and computer program product for compressing a bounding volume hierarchy is disclosed. The method includes the steps of receiving a bounding volume hierarchy and encoding the bounding volume hierarchy to generate an encoded bounding volume hierarchy, wherein each node in the encoded bounding volume hierarchy indicates whether the node inherits zero or more values from a parent node. The bounding volume hierarchy includes a plurality of nodes, each node in the plurality of nodes is associated with a bounding volume.

Abstract: In some aspects, techniques and systems for simulating well system fluid flow are described. Multiple subsystem models each include fluid flow variables and represent well system fluid dynamics associated with a sub-region in a subterranean region. The subsystem models are connected by one or more junction models. The junction models represent interactions among the subsystem models. For each of the subsystem models, an elimination of internal variables of the subsystem model is performed to express the internal variables in terms of junction variables of the junction models. The junction variables are solved based on the junction models. The internal variables of the subsystem model are solved based on the solved junction variables.

Abstract: A system and a method for estimating a reservoir parameter are provided. The method includes calculating a plurality of priors using a Markov random field, the plurality of priors comprising probability distributions of a plurality of litho-types; calculating posterior distributions based on the priors, the posterior distribution depending upon measured geophysical data, geophysical attributes and reservoir parameters; and determining at least a portion of litho-types in the plurality of litho-types that correlate most with the measured geophysical data.

Abstract: A method for characterizing one or more properties of a geological formation including brine and a dense vapor phase includes inputting at least one first property of the geological formation including resistivity of a vapor phase into a model including an equation of state (EOS) model, the model accounting for a high temperature effect on the dense vapor where that the dense vapor has a non-infinite resistivity. At least the EOS model is solves to provide data relating to at least one second property of the geological formation. The data relating to the at least one second property is output to a display device for visual inspection.

Abstract: A method for optimizing the development of a fluid reservoir by means of an accelerated reservoir study. A geological model is constructed. A reservoir model is then constructed by upscaling the geological model. The links between cells of the geological model and a cell of the reservoir model where they are contained are determined and stored. Flow simulations are carried out by computer-implemented reservoir simulator, the reservoir model and the links. The above stages are then repeated without repeating the link determination, by modifying parameters of the reservoir study to optimize the development scheme. Finally, the reservoir is developed according to this optimized development scheme.

Abstract: There is provided a method for modeling a hydrocarbon reservoir that includes generating a reservoir model that has a plurality of coarse grid cells. A plurality of fine grid models is generated, wherein each fine grid model corresponds to one of the plurality of coarse grid cells that surround a flux interface. The method also includes simulating the plurality of fine grid models using a training simulation to obtain a set of training parameters, including a potential at each coarse grid cell surrounding the flux interface and a flux across the flux interface. A machine learning algorithm is used to generate a constitutive relationship that provides a solution to fluid flow through the flux interface. The method also includes simulating the hydrocarbon reservoir using the constitutive relationship and generating a data representation of a physical hydrocarbon reservoir in a non-transitory, computer-readable medium based on the results of the simulation.

Abstract: Permeability prediction systems and methods using quadratic discriminant analysis are presented. At least one disclosed method embodiment includes: acquiring formation property measurements at a plurality of positions along at least one borehole in a study area; identifying clusters in a plurality of points representing the formation property measurements at the plurality of postions; and determining a system permeability value for each cluster. Quadratic Discriminant Analysis (“QDA”) is used to associate one the clusters with each position along the one or more boreholes, thereby determining a system permeability prediction for each position. The total system permeability can then be predicted by aggregating the system permeability predictions.

Abstract: A computer system and a computer-implemented method for optimizing the number of conditioning data used in multiple point statistics simulation. The method includes inputting a training image representative of subsurface geological heterogeneity; and inputting an initial conservative number of conditioning data. The method further includes selecting a geometry of a template wherein a size of the template is defined by the conservative number of conditioning data; building a search tree using the template by scanning the training image with the template and storing data patterns present in the training image in the search tree to obtain a plurality of patterns; and determining a threshold number of conditioning data smaller than the initial conservative number of conditioning data beyond which estimated facies probabilities are not significantly modified by additional number of conditioning data.

Abstract: Stress and fracture modeling using the principal of superposition is provided. A system simulates linearly independent far field stress models for a subsurface earth volume, computing stress, strain, and displacement values based on superposition of independent stress tensors. Based on the precomputed values, the system generates real-time recovery of paleostress values, or, stress, strain, and displacement parameters for any point in the subsurface volume as the user varies far field stress values. The system recovers one or more tectonic events, or a stress tensor represented by a ratio of principal magnitudes and associated orientation, using fault geometry, well bore data (fracture orientation and secondary fault plane data), GPS, InSAR, folded and faulted horizons, tiltmeters, slip and slikenlines on faults.

Abstract: A method for measuring torque measurement and generating a notifier, including searching for one or more wirelessly pairable load applying devices for applying a load to an object; displaying to a user those paired one or more load applying devices; responsive to selecting one of the displayed one or more load applying devices, receiving one or more of the group consisting of load measurements transmitted from the selected load applying device; and generating a notifier based on the proximity of the one or more of the group consisting of load measurements and torque measurements and a target value.

Abstract: A method of predictive modeling of a treatment fluid comprises: determining the value of properties of a base fluid and insoluble particulates; providing a proposed suspending agent; performing a first calculation of the suspendability of the proposed suspending agent as determined by a yield gravity function equation; evaluating if the result from the first calculation indicates a stable treatment fluid comprising the base fluid, the insoluble particulates, and the proposed suspending agent, or if the result does not indicate a stable treatment fluid, then: modifying the value of at least one of the properties of the proposed suspending agent, base fluid, and/or insoluble particulate; and performing a second calculation, wherein the same or different property values are continued to be modified and the calculation is continued to be performed until the result indicates a stable treatment fluid; and introducing the stable treatment fluid into a wellbore.

Abstract: Computerized method and system for deriving a statistical reservoir model of associations between injecting wells and producing wells. Potential injector events are interactively identified from time series measurement data of flow rates at the wells, with confirmation that some response to those injector events appears at producing wells. Gradient analysis is applied to cumulative production time series of the producing wells, to identify points in time at which the gradient of cumulative production changes by more than a threshold value. The identified potential producer events are spread in time and again thresholded. An automated association program rank orders injector-producer associations according to strength of the association. A capacitance-resistivity reservoir model is evaluated, using the flow rate measurement data, for the highest-ranked injector-producer associations.

Abstract: The present invention relates to a method for displaying two-dimensional geological image data in log format and the displayed image products thereof. The present invention can provide a concatenated display format for two-dimensional image data captured for different planar slices of a geological sample. The present method provides an enhanced format modality for presentation of such image data of a geological sample as a continuous presentation for the slices in the sequence.

Abstract: A method, apparatus, and program product improve the computational efficiency of a multipoint geostatistics method by employing an ordered path through unassigned cells in combination with a non-symmetric search mask that excludes one or more not-yet-simulated cells from the search mask during simulation.

Abstract: There is provided a method for modeling a hydrocarbon reservoir that includes deriving a computational mesh on a fine unstructured mesh using a multilevel mixed multiscale finite volume (MMMFV) method. Deriving the computational mesh includes computing a first algebraic multilevel basis function for a pressure, constructing an interaction region, and generating a primary mesh. A second algebraic multiscale basis function for a velocity approximation is computed and the primary mesh is discretized. The hydrocarbon reservoir is simulated using the computational mesh. A data representation of a physical hydrocarbon reservoir is generated in a non-transitory, computer-readable, medium based at least in part on the results of the simulation.

Abstract: A method to parameterize the geometry of a geological, subsurface feature such as a salt body is provided. Data corresponding to a subsurface, geological formation is acquired. The acquired formation data corresponds to a subsurface body having a certain geometry and a subsurface region. At least part of the subsurface body geometry is directly inverted into an inversion domain. The direct inversion includes partitioning the inversion domain into a first partitioned region, corresponding at least in part to the subsurface body, and a second partitioned region. The inversion further uses a level set representation to parameterize the subsurface body geometry. A computing system that includes a processor, a memory, and one or more programs stored in the memory is also provided. The programs comprise instructions that, when executed by the processor, are configured to perform the provided method.

Abstract: Geologic information may be extracted from multiple offset stacks and/or angle stacks. Offset stacks and/or angle stacks may be received that represent energy that has propagated through a geologic volume of interest from energy sources to energy receivers. Attribute volumes associated with individual source-receiver offsets and/or source-receiver angles may be determined based on corresponding offset stacks and/or angle stacks. For individual offset stacks or angle stacks, corresponding sets of geologic features represented in the attribute volumes may be identified. The sets of geologic features corresponding to the different offset stacks and/or angle stacks to may be compared to determine discrepancies and/or similarities between the sets of geologic features corresponding to the different offset stacks and/or angle stacks. Stratigraphic interpretations, stratigraphic predictions, and/or other interpretations and/or predictions may be determined based on causes of the discrepancies and/or similarities.

Abstract: A method, apparatus, and program product increase the computational efficiency of a multipoint geostatistics method by parallelizing the simulation process to concurrently simulate sets of unassigned cells in a simulation grid. Values of unassigned cells in the neighborhood of the unassigned cells being simulated are predicted, and a plurality of threads are used to simulate the set of unassigned cells using the predicted values. Simulation results are used to verify predictions, and mispredicts cause ongoing simulations of other cells to be restarted using the simulation results in lieu of mispredicted values.

Abstract: A method, system and machine-readable medium encoded with machine-executable instructions for creating an ensemble of estimated upscaled reservoir models from fine-scale geological models of the subsurface region to produce coarse-scale models of the subsurface region, the method includes computing coarse-scale attributes for a plurality of realizations, numerically simulating coarse-scale properties for a subset of the plurality of realizations, generating calibration data based on the numerically simulated coarse-scale properties and corresponding coarse-scale attributes, and estimating coarse-scale properties for a plurality of realizations, wherein the estimating is done using a statistical procedure and is calibrated using the calibration data to produce coarse-scale properties of an ensemble of upscaled models.

Abstract: A method and system to render a graphic display that includes a color-coded risk indicator to facilitate the steering of a drill string during subterranean drilling. The system comprises a receiver to receive measurement data from downhole instrumentation forming part of the drill string during the drilling of a well bore in a geological formation, and an exit risk determining module to determine an exit risk value based at least in part on the measurement data. The exit risk value is indicative of a risk of exiting of the formation by the drill string. A display module is provided to render the graphic display of decision information, to assist steering of the drill string. The color-coded exit risk indicator comprises a colored area having a color indicative of the exit risk value, the color of the colored area being changeable in response to changes in the exit risk value.

Abstract: A convergent solution is provided for a coupled system where oil flow from a subsurface reservoir formation enters a number of pipes of a multi-branch well in the formation. An iterative linear system solver computer implemented methodology is developed, capable of handling a large number of unknowns which are present when modeling a multi-branch well. A systematic approach which defines proper boundary conditions at the reservoir level and at the wellhead is provided and utilized.

Abstract: Method for optimizing the development of a fluid deposit using a fracture network grid constructed from a Voronoi diagram. Based on observations of the deposit a discrete fracture network is constructed in which each fracture is represented by an isotropic polygonal finite plane in terms of its dynamic properties, a plane comprising segments of intersection with other network fractures. A Voronoi diagram is constructed on each fracture plane by positioning Voronoi cell centers on the segments of intersection, and the transmissivities are calculated between centers of neighboring cells from the ratio between the surface area of the neighboring cells and the distance between the neighboring cells. The cells and transmissivities can then be used to construct an image of the fluid deposit. Finally, this image and a flow simulator are used to optimize the development of the fluid deposit.

Abstract: Methods and apparatus for planning and dynamically updating sampling operations while drilling in a subterranean formation are described. An example method of planning a sampling while drilling operation for a subterranean formation includes identifying a plurality of processes and related parameters, the processes including drilling and sampling processes and the related parameters including drilling and sampling parameters. The example method also involves processing the parameters for each of the processes via a simulation engine to generate predictions associated with sampling the formation, the simulation engine including at least one of a wellbore hydraulics simulator, a mudcake simulator, a formation flow simulator, or a tool response simulator.

Abstract: Systems and methods for optimal positioning of drilling pads for horizontal well field development considering the location and spacing of each horizontal well, boundaries and surface/subsurface hazards.

Abstract: Systems and methods for dynamically developing a wellbore plan with a reservoir simulator. The systems and methods develop a plan for multiple wellbores with a reservoir simulator based on actual and potential reservoir performance.

Abstract: Methods for creating and using discretized physics-based models of subsurface regions, which may contain a hydrocarbon reservoir or other subsurface feature(s). The methods may include selecting a pre-solved model, applying a mesh to the pre-solved model, defining the shape of the subsurface region to be modeled, and transforming the pre-solved model, to which the mesh has been applied, to the shape of the subsurface region. In some methods, the pre-solved model is an idealized model. In some methods, the mesh is applied to a solution of potential field lines associated with the pre-solved model, and in some methods, the solution of potential field lines is a composite solution of a plurality of solutions of potential field lines. In some methods, one or more supershapes are used to define the shape of the subsurface region. In some methods, a hyperelastic strain deformation calculation is utilized for the transforming.

Abstract: A method of determining an optimal value for a control of a drilling operation is provided. Drilling data from a drilling operation is received. The drilling data includes a plurality of values measured for each of a plurality of drilling control variables during the drilling operation. An objective function model is determined using the received drilling data. The objective function model maximizes a rate of penetration for the drilling operation. Measured drilling data is received that includes current drilling data values for a different drilling operation. An optimal value for a control of the different drilling operation is determined by executing the determined objective function model with the measured drilling data that includes the current drilling data values for the different drilling operation as an input. The determined optimal value for the control of the different drilling operation is output.

Abstract: A system and method having application notably towards predicting fluid flow characteristics within fractured subsurface reservoirs. The system and method include steps of reservoir characterization, gridding, discretization, and simulation of geologically realistic models describing the fractured subsurface reservoirs. A stochastic fracture representation that explicitly represents a network of fractures within a subsurface reservoir is constructed and used to build a fine-scale geological model. The model is then gridded such that the network of fractures is represented by interfaces between the fine-scale cells. The model is the discretized and simulated. Simulation can be on a fine-scale or on an upscaled coarse-scale to produce efficient and reliable prediction of fluid flow characteristics within the subsurface reservoir.

Abstract: A method, system and processor readable medium containing computer readable software instructions for selecting representative models from a large ensemble of models is disclosed. An ensemble of reservoir models that define an input uncertainty space is provided. A target number of representative models and one or more target percentiles of output variables that the representative models are to approximate are input. The representative models from the ensemble of reservoir models that match the one or more target percentiles of output variables are selected while maximizing the spread between the selected representative models in the input uncertainty space.

Abstract: A subterranean reservoir where the pore space of media or formation rock is multimodal, and the media may have imbedded multiple scales of fracture networks, is simulated. The modes of the pore system and the scale of fracture networks are each represented as a separate, but interactive continuum with the other. A matrix solution with arrangement of the reservoir data adapted for parallel computation is utilized. The simulation allows multiple continua to be co-located and multi-interacting, in that each continuum may have current and counter-current multiple multiphase exchanges with other continua.

Abstract: In visualizing flow in subsurface reservoirs, a system partitions flow information according to source-sink pairs and streamlines in a reservoir. The system displays dynamic streamline flow indicators and flow animations, such as 3D pie charts, to dynamically show flow contributions and properties at each well. A pie chart displayed at a producer well may have pie wedges that dynamically update to show the percentage of fluid being received via streamlines from each of multiple injectors. Highlighting the chart highlights all wells contributing to the output. Radial sections of each pie wedge may be further mapped to show the flow rate of components, such as oil, water, and gas phases in a streamline. Each chart may show many other properties and may be stacked across time steps. The system also displays streamline properties with animations, which demonstrate flow velocity and model properties, such as phase components, rates, volumes, etc., through color and size codes.

Abstract: A dense volumetric grid coming from an oil/gas reservoir simulation output is translated into a compact representation that supports desired features such as interactive visualization, geometric continuity, color mapping and quad representation. A set of four control curves per layer results from processing the grid data, and a complete set of these 3-dimensional surfaces represents the complete volume data and can map reservoir properties of interest to analysts. The processing results yield a representation of reservoir simulation results which has reduced data storage requirements and permits quick performance interaction between reservoir analysts and the simulation data. The degree of reservoir grid compression can be selected according to the quality required, by adjusting for different thresholds, such as approximation error and level of detail.

Abstract: A method of solving a optimization problem is described. The method includes creating an initial model having a plurality of wells, each well being associated with a parameter and dividing the well field into first and second regions, the first region including a first subset of the plurality of wells and the second region including a second subset of the plurality of wells. The method also includes solving for the parameters associated with the wells in the first subset to get a first set of values while holding constant the parameters associated with the wells in the second subset, setting the parameters associated with the wells in the first subset to the first set of values, and solving for the parameters associated with the wells in the second subset to get a second set of values while holding constant the parameters associated with the wells in the first subset.

Abstract: A method can include receiving information that defines a three-dimensional subterranean structure; splitting the three-dimensional subterranean structure into portions; generating convex hulls for the portions; and generating a discrete fracture network based at least in part on the convex hulls.

Abstract: A method of computational fluid dynamic modelling of a subterranean region comprises: defining a computational domain by generating a geometrical model of a subterranean region comprising a wellbore and a surrounding formation; associating knowledge of a physical property of the subterranean region with a computational parameter; and inputting the computational parameter into the computational domain. In one embodiment knowledge of permeability within the subterranean region is defined as a viscous resistance within the computational domain.

Abstract: Methods for creating and using space-time surrogate models of subsurface regions, such as subsurface regions containing at least one hydrocarbon formation. The created surrogate models are explicit models that may be created from implicit models, such as computationally intensive full-physics models. The space-time surrogate models are parametric with respect to preselected variables, such as space, state, and/or design variables, while also indicating responsiveness of the preselected variables with respect to time. In some embodiments, the space-time surrogate model may be parametric with respect to preselected variables as well as to time. Methods for updating and evolving models of subsurface regions are also disclosed.

Abstract: A technique includes processing seismic data indicative of samples of at least one measured seismic signal in a processor-based machine to, in an iterative process, determine basis functions, which represent a constructed seismic signal. The technique includes in each iteration of the iterative process, selecting another basis function of the plurality of basis functions. The selecting includes based at least in part on the samples and a current version of the constructed seismic signal, determining a cost function; and interpreting the cost function based at least in part on a predicted energy distribution of the constructed seismic signal to select the basis function.

Abstract: A system and method is taught to substantially automate forecasting for a hydrocarbon producing reservoir through integration of modeling module workflows. A control management module automatically generates static and dynamic offspring models, with static and dynamic modeling software, until a performance objective associated with the forecasting of the reservoir is satisfied. The performance objective can include an experimental design table to determine a sensitivity of a particular parameter or can be directed towards reservoir optimization, i.e., ultimate hydrocarbon recovery, net present value, reservoir percentage yield, reservoir fluid flow rate, or history matching error.

Abstract: A method of calculating a 3-D geologic model in real time using, as input, 2-D geologic data. The 3-D is used for conducting further drilling operations. The model may be updated in real time using additional measurements obtained during drilling operations.

Abstract: A method for predicting a path of a borehole that will be drilled in a rock formation by a bottomhole assembly (BHA) having a drill bit includes: constructing a model of the BHA; calculating confined compressive strength of the rock formation using an axial motion drill bit model that receives drilling parameter, drill bit design and lithology information; calculating lateral motion of the drill bit using a lateral motion drill bit model; calculating a ratio of lateral motion to axial motion using the lateral motion drill bit model; calculating an inclination angle and an azimuthal direction of the BHA using a BHA steering model that receives the ratio; and iterating the above steps by updating the BHA model to include extending the borehole an incremental distance in the direction of the inclination angle and the azimuthal direction and displacing the BHA the incremental distance in the extended borehole.

Abstract: A method can include receiving fluid saturation data for fluid saturation parameters associated with permeabilities of a multidimensional spatial model of a geologic environment; adjusting at least a portion of the fluid saturation data to provide adjusted fluid saturation data by optimizing a quadratic function subject to linear constraints; and simulating flow of fluid using the adjusted fluid saturation data for fluid saturation parameters associated with permeabilities and the multidimensional spatial model of the geologic environment.

Abstract: In some embodiments, systems, methods, and articles may operate to compute, in parallel, to determine values of unknowns in network equations associated with a network of sub-surface wells and at least one surface facility, for intra-well subdivisions of the network, and then for inter-well subdivisions of the network, wherein the computing is based on default values of the unknowns, or prior determined values of the unknowns. Additional activities may include constructing a distributed Jacobian matrix having portions comprising coefficients of the unknowns distributed among a number of processors, wherein each of the portions is distributed to a particular one of the processors previously assigned to corresponding ones of the subdivisions. The Jacobian matrix may be factored to provide factors and eliminate some of the unknowns. Back-solving is used to determine remaining unsolved ones of the unknowns, using the factors. Additional apparatus, systems, and methods are described.

Abstract: Systems and methods for subsurface secondary and/or tertiary oil recovery optimization based on either a short term, medium term or long term optimization analysis of selected zones, wells, patterns/clusters and/or fields.

Abstract: A method of optimizing production of wells using choke control includes generating, for each well, an intermediate solution to optimize the production of each well. The generating includes using an offline model that includes a mixed-integer nonlinear program solver and includes using production curves based on a choke state and a given wellhead pressure. The method further includes calculating, using a network model and the intermediate solution of each well, a current online wellhead pressure for each well. The method further includes setting the intermediate solution as a final solution based on determining that a difference between the current online wellhead pressure of each well and a prior online wellhead pressure of each well is less than a tolerance amount. The method further includes adjusting, using the final solution of each well, at least one operating parameter of the wells.

Abstract: A method of modelling a hydrocarbon-containing reservoir which is representative of such reservoir in at least one physical characteristic such as reservoir porosity or permeability. Data, such as reservoir porosity is firstly determined. Such data is then transformed into printing instructions for a 3D printer. The 3D printer is used to print a reduced-scale model which is representative of the reservoir in respect of the at least one physical characteristic, such as reservoir porosity. A method of comparative testing of different hydrocarbon recovery techniques on a single hydrocarbon-containing reservoir is also disclosed and claimed.