Abstract: Embodiments of a method of pore type classification for petrophysical rock typing are disclosed herein. In general, embodiments of the method utilize parameterization of MICP data and/or other petrophysical data for pore type classification. Furthermore, embodiments of the method involve extrapolating, predicting, or propagating the pore type classification to the well log domain. The methods described here are unique in that: they describe the process from sample selection through log-scale prediction; PTGs are defined independently of the original depositional geology; parameters which describe the whole MICP curve shape can be utilized; and objective clustering can be used to remove subjective decisions. In addition, the method exploits the link between MICP data and the petrophysical characteristics of rock samples to derive self-consistent predictions of PTG, porosity, permeability and water saturation.

Abstract: A system and method inserts fracture networks into an existing Earth Model that exists as a structured grid and physical property values. The fracture network is in the form of a surface mesh (manifold or non-manifold) in a three-dimensional (“3D”) space. The structured grid of the Earth Model is then anisotropically refined to resolve the fractures and to provide appropriate cell grading in the near-fracture region. The generated Earth Model may be utilized in a variety of applications, including for example, a reservoir simulation.

Abstract: A method can include receiving a model of a fluid production network where the model includes a plurality of sub-models; synchronizing simulation of the plurality of sub-models with respect to time; and outputting values for fluid flow variables of the model.

Abstract: A method for quantitatively evaluating multiple computer-based plate tectonic models for application in a geographic region of interest, in some embodiments, comprises: selecting a plurality of computer-based plate tectonic models; using multiple computer-based plate tectonic models to generate one or more predictions for one or more geological parameters; obtaining observational data for each of said one or more geological parameters; for each of said one or more geological parameters, quantitatively comparing the predictions and the observational data to determine model rankings; and displaying said model rankings on a computer display.

Abstract: The invention is a method for exploitation of a sedimentary basin containing hydrocarbons using basin simulation. Based on a reconstitution of the formation of the first of the layers of the basin, a conjoint basin simulations of at least one of the layers underlying the first layer. A conjoint geomechanical simulation of the first layer and the at least one underlying layer is then carried out. If the deviation between some of at least some parameters from the geomechanical simulation and those from the basin simulation is above a predefined threshold, the previous steps are repeated applying a correction to the basin simulation. The basin is then exploited as a function of the results of the basin simulation. The invention applied to exploration and exploitation of the basin.

Abstract: Present embodiments are directed to a method that includes receiving inputs indicative of a property of a fracture present within a dynamic fracture network, assigning an orientation to each of the plurality of fractures, and receiving variables representative of the endpoints of the fracture between a first junction and a second junction of the plurality of junctions. The method also includes determining a linear system representing fluid flow within the fracture based on Navier-Stokes equations, as a function of the variables at the first junction and the second junction. The method further includes displaying a simulation representative of a fluid flow through the fracture based on the junction conditions via a display coupled to the processing component.

Abstract: Reservoir simulation for simulation models which include a large edge aquifer region is provided with a speed up in processing reducing computer processing time. Connected aquifer grid cells in a vertical column are amalgamated to reduce the total number of active cells in the solution phase. The fine grid property data is maintained for computing distributed 3D graph, and connection factors (transmissibilities), as well as pore volume and compressibility calculation of coarsened aquifer cells during nonlinear solution phase. Since the work load in the solution phase is proportional to the total number of active cells, a significant speedup in simulation time is provided. The aquifer fine grid pressures are computed using vertical equilibrium treatment of hydraulic potential inside an amalgamated aquifer coarse cell.

Abstract: A computer implemented method, system, and computer program product are provided for determining flow control device (FCD) properties for a gas injection well that would yield a prescribed shape of a gas injection front according to a target gas injection profile. An FCD distribution function is adjusted based on the results of a simulation of injected gas flow distribution in the gas injection well over a period of time. The simulation and resulting adjustment of the FCD distribution function is repeated until a convergence between a shape of a displaced oil volume front obtained using the adjusted flow control device distribution function and a target gas injection profile is reached within a predetermined convergence range. The FCD properties are then determined based on the adjusted FCD distribution function.

Abstract: A method, apparatus, and program product use graph partitioning to distribute wells to a plurality of solve processors in a parallel reservoir simulation environment to optimize performance of well solve operations during reservoir simulations. Wells may be distributed to assign wells to partitions and associated solve processors and/or other processing resources in a manner that optimizes communication costs and/or costs associated with performing well solve operations.

Abstract: A method of online real-time estimation of production performance properties includes receiving real-time field data taken by downhole sensors, and estimating formation properties and production performance properties by applying the field data to a two or three-dimensional numerical transient thermal multiphase reservoir flow model, and automatically calibrating the model.

Abstract: An integrated solver may be used for both a fluid phase and a solid phase. The integrated solver may use constitutive equations for the fluid phase and the solid phase, and calculate the stress in the fluid and solid using the same integration point. The integrated solver may also calculate other state variables using the same integration point.

Abstract: One drilling method embodiment includes: obtaining a set of drilling parameters, possibly from a drilling plan; applying the set of drilling parameters to a physics-based model to obtain an estimated log of a downhole parameter such as temperature; and refining the estimated log using a data-driven model with a set of exogenous parameters. Temperature cycling and cumulative fatigue (or other measures of failure probability or remaining tool life) may be derived to predict tool failures, identify root causes of poor drilling performance, and determine corrective actions.

Abstract: A method for computing a production rate of hydrocarbons from an earth formation includes: obtaining information about a discrete fraction network relating to locations, orientations and apertures of fractures; computing an average distance of the fractures to a wellbore penetrating the formation and a standard deviation of the distances; computing an average velocity of fluid from each of the fractures to the wellbore and a standard deviation of the velocities; computing a characteristic time representing a time for fluid to flow from each fracture to the wellbore and a standard deviation of the characteristic times; computing a range of hydrocarbon production rates using the characteristic time and the standard deviation of the characteristic times to provide the range of hydrocarbon production rates as a function of standard deviation values; and providing a graph of the range of hydrocarbon production rates as a function of standard deviation values.

Abstract: The invention relates to a characterization method for characterizing the performance of wells in a stockpile or deposit of compressible fluid, the method comprising the steps of: obtaining a plurality of operating points (400); defining a family of operating models (IPa, IPb); for each model of a family, enumerating (410) those points of the plurality of points that are reproduced by said model; and for managing said stockpile or deposit, selecting (420) at least one model (M) from the family of models on the basis of at least the result of the enumeration step.

Abstract: A method for accelerating the decision making process for reservoir risk management is described. In particular, an ensemble based decisions and filter are used to quickly compare different information scenarios to determine the best strategy for developing a hydrocarbon-containing reservoir.

Abstract: A downhole drilling tool that has a deep-reading logging tool, a near-bit resistivity tool, and a gamma ray detector. Formation information logged using the deep-reading logging tool is used to build a preliminary stratigraphic model with a relatively low resolution. The preliminary stratigraphic model is further refined using data logged using the near-bit resistivity tool and/or the gamma ray detector to obtain a refined stratigraphic model with a higher resolution. The model is used to guide geosteering to achieve better well placement and trajectory control.

Abstract: Systems, methods, and software for presenting predefined parameter subsets for industrial automation devices and equipment are provided herein. In one example, a non-transitory computer readable medium having stored thereon program instructions executable by a computing device is presented. When executed by the computing device, the program instructions direct the computing device to present a graphical user interface with at least one predetermined subset of parameters, receive a user selection for one of the at least one predetermined subset of operating parameters for an industrial automation device, identify parameters associated with the selected subset, and display the identified subset of parameters.

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: The invention is related to the field of control apparatus, and in particular, to control apparatus configured to allow a user to control the processing of data. In particular, this invention relates to controlling the processing of industrial plant data by controlling selection of a geographical area. The selection of a geographical area may be implemented by controlling a display using a user interface controller.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for approximating multiphase flow in reservoir simulation. For example, one disclosed embodiment includes a system that includes at least one processor and memory coupled to the at least one processor, the memory storing instructions that when executed by the at least one processor performs operations that includes generating a set of pseudo-phase production relative permeability curves; receiving production rate history data; receiving simulation configuration parameters; performing flow simulation using the set of pseudo-phase production relative permeability curves; and determining an optimal matching pseudo-phase production simulation result that best matches the production rate history data in the absence of relative permeability measurements derived from the subsurface porous medium.

Abstract: Disclosed is a device for capturing digital images of a rock specimen in a region of interest.

Abstract: Computer processing time and results are improved in fully-coupled fully-implicit well-reservoir simulation system using Jacobian matrix methodology. Approximate inverse preconditioners are provided which treat a well influence matrix at comparable accuracy and robustness to those for the grid-to-grid flow terms of system matrix. The methodology is highly parallelizable and the data processing can be performed faster, as fewer solver iterations are required to converge to the same acceptable tolerances.

Abstract: A system and method for displaying a wellbore. A well profile is generated in a computing system. The wellbore is associated with the well profile. Information associated with the wellbore is received including at least components. The wellbore is displayed in three dimensions for review by one or more users.

Abstract: Disclosed is a method of monitoring the behavior of a subsurface volume. The method comprises transforming a single discrete parameter or an ensemble of discrete parameters describing an attribute of the subsurface volume, each discrete parameter having N possible discrete values with N?2, into N indicator parameters each having 2 possible discrete values; for each of the two value classes of each indicator parameter, determining the anisotropic distance to a value transition interface; transforming each of the indicator parameters into a corresponding continuous parameter using the determined anisotropic distance to the value transition interface; and using the continuous parameters in a history matching process.

Abstract: There is provided a method for modeling a hydrocarbon reservoir that includes generating a reservoir model comprising a plurality of sub regions. At least one of the sub regions is simulated using a training simulation to obtain a set of training parameters comprising state variables and boundary conditions of the at least one sub region. A machine learning algorithm is used to approximate, based on the set of training parameters, an inverse operator of a matrix equation that provides a solution to fluid flow through a porous media. The hydrocarbon reservoir can be simulated using the inverse operator approximated for the at least one sub region. The method also includes generating a data representation of a physical hydrocarbon reservoir can be generated in a non-transitory, computer-readable, medium based, at least in part, on the results of the simulation.

Abstract: The invention relates to a method for exploiting (EXP) a subsurface deposit comprising at least one outcrop, the exploitation (EXP) of the deposit is based on a geological model (MOD) formed from a photogrammetry. The method reconstructs the geological outcrops in three dimensions (R3D) from photographs (PHO), and interprets the geological elements thereof, such as the sedimentary surfaces, the geological facies, the fault lines and the fractures, the inclination of the beds, etc. to construct a geological model of the deposit (MOD).

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for improving water break-though time predictions. One computer-implemented method includes obtaining, by a hardware data processing apparatus, a plurality of initial relative permeability data; determining, by the hardware data processing apparatus, viscosity data; determining, by the hardware data processing apparatus, a flood-front saturation point based on the viscosity data and the initial relative permeability data; and generating, by the hardware data processing apparatus, a plurality of corrected relative permeability data based on the plurality of initial relative permeability data and the critical fractional flow point, wherein the plurality of the corrected relative permeability data are used to simulate water break-through time.

Abstract: Embodiments of systems, non-transitory computer-readable medium having one or more computer programs stored therein, and computer-implemented methods are provided to enhance hydrocarbon reservoir simulation for a plurality of hydrocarbon reservoirs. According to embodiments, a plurality of fluid flow simulation runs in each of a plurality of hydrocarbon reservoirs are initiated. Then, each of a first set of one or more of the plurality of simulation runs are terminated while each of a second set of one or more of the plurality of simulation runs continue. Terminating each of the first set of simulation runs can increase processing availability within a collective limited and predetermined combined computing capacity of one or more processors to another one or more of the plurality of simulation runs being run. Consequently, terminating each of the first set of simulation runs can thereby reduce total hydrocarbon reservoir simulation run time.

Abstract: A method and computer program product for managing hydrocarbon field production, e.g., petro-chemical reservoir production. The hydrocarbon field is modeled using the finite volume method (FVM) model and the finite element method (FEM). Centroids are located in each FVM cell and each FEM element and overlapping cells are identified. After determining the distance between centroids for overlapping cells, fluid characteristics are mapped to the FEM element centroids, weighted inversely for distance between the respective centroids. A permeability/conductivity weighted average is determined for pore pressure and temperature of sub-volumes clustered around each FEM element node. Field production may be adjusted in response to FEM element node characteristics.

Abstract: Disclosed are methods, systems, and computer readable media useful in determining pore pressure in a reservoir. Specifically disclosed are methods, systems, and computer readable media for determining mudstone permeability in mudstone bounding a reservoir.

Abstract: A method operates a set of heating, ventilation and air-conditioning (HVAC) units by optimizing jointly operations of the set of HVAC units subject to constraints to determine times of switching each HVAC unit ON and OFF and by controlling each HVAC unit according to the corresponding times of switching. The operation of each HVAC unit is represented by a continuous function. The constraints include a complementarity constraint for each HVAC unit, such that the complementarity constraint for the HVAC unit defines a discontinuity of the operation of the HVAC unit at corresponding times of switching.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for monitoring underbalanced drilling operations. For example, one disclosed embodiment is a system that includes at least one processor and at least one memory coupled to the at least one processor and storing instructions that when executed by the at least one processor performs operations for generating a three dimensional tunnel view of an operating envelope of a well as the well is being drilled.

Abstract: Systems and methods may include sending, to a downhole tool emulator, at least one input signal that represents one or more conditions in a simulated well system. The downhole tool emulator may include one or more electronic components to be placed in a downhole tool. The at least one input signal may be generated based at least partially on a reservoir model of the simulated well system. The method may include receiving at least one output signal that represents a response of the downhole tool emulator to the one or more conditions. The method may also include sending, to the downhole tool emulator, at least one command that represents an operation of the downhole tool emulator. The at least one command may represent a change in the operation of the downhole tool emulator based at least partially on the one or more conditions and the response.

Abstract: A subsurface hydrocarbon reservoir with wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures. The solution is performed on a matrix of the transmissibilities of the adjacent reservoir cells to the well cells at the perforated well intervals; and a vector of unknown reservoir potentials for the adjacent reservoir cells.

Abstract: At least some of the disclosed systems and methods obtain a static earth model having multiple layers. Further, at least some of the disclosed systems and methods test a permeability associated with at least part of the static earth model. Further, at least some of the disclosed systems and methods calibrate the static earth model by adjusting a distribution or proportion of geological features in at least one of the multiple layers based on the testing. Further, at least some of the disclosed systems and methods use the calibrated static earth model to predict fluid flow in a formation.

Abstract: Systems and methods for creating platform positioning maps representing surface pad location feasibility for visually validating a current surface pad location and/or determining the suitability of another surface pad location.

Abstract: A subsurface hydrocarbon reservoir with wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures. The solution is on a steady state volume balance relationship of the layer completion rates, formation pressures and transmissibilities to determine completion rates for the layers of the well for the full reservoir model, and determine total rate for the well from the determined completion rates for the layers of the well.

Abstract: A subsurface hydrocarbon reservoir with horizontal or multiple vertical wells is simulated by sequential solution of reservoir and well equations to simulate fluid flow inside the reservoir and well production rates. Sequential solution of reservoir and well equations treats wells as specified bottom hole pressure wells. This avoids solving large matrices resulting from the simultaneous solution of the reservoir and well equations which can be computationally very expensive for large number of unknowns and require special sparse matrix solvers. Such sequential solution involves regular reservoir system solvers complemented by a small matrix for the numerical solution of the well bottom hole pressures.

Abstract: Depth-averaged flow simulation systems and methods provided herein employ parameterized templates for dynamical depth profiling for at least one step of a simulation.

Abstract: A changepoint detector for modeling data received from at least one sensor in a process in the hydrocarbon industry. The data is segmented into a plurality of segments and for each segment a model is assigned and the data corresponding to the segment fit to that model. A plurality of segmentations are thus provided and these segmentations are evaluated and assigned weights indicative of the fit of the models of the segmentation to the underlying data. The segmentation models are further used to calculate a result that may be input to a process control program.

Abstract: A method and system for inducing secondary orthogonal fractures in an underground formation by introducing a proppant carrying fluid into a hydraulic fracture in an underground formation at high pressure is provided. The pressure of the proppant carrying fluid is lowered at a rate allowing the fluid to exit the formation while the proppant remains in place within the fractures. The pressure of the fluid is then rapidly reduced, creating fractures orthogonal to the surface of existing fractures by pushing remained proppant against hydraulic fractures walls. The orthogonal fractures can be opened with high pressure fluid and propped. In this way, the portion of the formation in fluid flow communication with the wellbore is increased.

Abstract: The present invention relates to a method for determining a karstic region modified by karstification phenomena. This method comprises, from a geological model, determining a seed cell and a target cell in that model. If a distance between the seed cell and the target cell is above a given distance, it is possible to update the seed cell with a bifurcation cell based at least on the coordinates of the seed cell, the coordinates of the target cell, a distance distribution, an angular distribution, and to re-iterate the test. Based on that bifurcation cells, trajectory is computed and cells of that trajectory is updated with new cell characteristics.

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: Systems and methods for 2D domain decomposition during parallel reservoir simulation to balance the active cells in a reservoir model.

Abstract: A method for enhanced hydrocarbon recovery from a subsurface formation includes drilling and completing a plurality of laterally spaced apart wells through the formation so as to enable interference between adjacent ones of the plurality of wellbores. Fluid comprising surfactant is injected into the formation through at least one of the wellbores after an end of primary recovery from selected ones of the plurality of wellbores to initiate secondary recovery of hydrocarbons from the formation.

Abstract: There is provided a method for modeling 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: Disclosed is a method and system for identifying simulated basin results and associated input parameter values for simulation of geographic basins by a stratigraphic forward model simulation program that are most likely to represent the actual basin by treating inputs and outputs of the stratigraphic forward model simulation program in a unified manner. An embodiment may calculate probability distributions for input parameters and validation data, and calculate likelihoods of simulated basins as a combination of the combination of the probabilities of the input parameters used to create the simulated basin and of the combination of the probabilities simulation validation results of the simulated basin. An embodiment may then select most likely simulation model result basins based on the results having a higher calculated likelihood. The most likely simulated basins may be used for analysis of exploration and/or production decisions without the need for additional, expensive testing on the actual basin.

Abstract: A system and method for performing stimulation operations at a wellsite having a subterranean formation with of a reservoir therein is provided. The method involves generating a plurality of quality indicators from a plurality of logs, and combining the plurality of quality indicators to form a composite quality indicator. The plurality of stress blocks may then be merged using diversion criterion. The composite quality indicator may be combined with the merged stress blocks to form a combined stress and composite quality indicator, the combined stress and composite quality indicator comprising a plurality of blocks with boundaries therebetween. The method may further comprise defining stages along the combined stress and composite quality indicator based on the diverter-assisted stage classifications; and selectively positioning perforations in select stages based on the diverter-assisted stage classifications thereon.

Abstract: Methods of analyzing fluid flow in a formation include defining physical boundaries of a porous geological formation reservoir and parameters related to a process of injection of fluid over a period of time, and configuring a reservoir simulator that characterizes transport of the fluid as solute within the physical boundaries of the reservoir in accordance with the fluid injection process. The reservoir simulator utilizes at least one upscaled equation describing advective transport for the solute. Output of the simulator may be viewed. The parameters related to the injection process including one or more of an injection rate, a location of injection, and a time length of injection can be optimized.

Abstract: The present disclosure provides methods and systems for managing power in a processor having multiple cores. In one implementation, a microarchitecture of a core within a general-purpose processor may include configurable lanes (horizontal slices through the pipeline) which can be powered on and off independently from each other within the core. An online optimization algorithm may determine within a reasonably small fraction of a time slice a combination of lanes within different cores of the processor to be powered on that optimizes performance under a power constraint budget for the workload running on the general-purpose processor. The online optimization algorithm may use an objective function based on response surface models constructed to fit to a set of sampled data obtained by running the workload on the general-purpose processor with multiple cores, without running the full workload. In other implementations, the power supply to lanes can be gated.