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 creating virtual production logging tool profiles for improved history matching and proactive control of smart wells.

Abstract: Disclosed is a system and a method of estimating a well inflow profile along a section of a wellbore of a well passing through a formation.

Abstract: Present embodiments are directed to a method that includes receiving inputs indicative of a property of a fracture within a dynamic fracture network, assigning an orientation to each of the plurality of fractures, and assigning a plurality of fracture nodes and fracture cells encompassing each fracture node along the fracture. The method also includes receiving variables representative of apertures at a first fracture node and a second fracture node and determining fluid flow within the fracture cell based on Navier-Stokes equations with proppant transport, as a function of the conditions at the first fracture node and the second fracture node. The method further includes displaying a simulation representative of a flow of proppant through the fracture based on the junction conditions via a display coupled to the processing component.

Abstract: A method of performing a fracture operation is provided at a wellsite. The wellsite is positioned about a subterranean formation having a wellbore therethrough and a complex fracture network therein. The complex fracture network includes natural fractures, and the wellsite stimulated by injection of an injection fluid with proppant into the complex fracture network. The method involves generating wellsite data comprising measurements of microseismic events of the subterranean formation, modeling a hydraulic fracture network and a discrete fracture network of the complex fracture network based on the wellsite data, and performing a seismic moment operation. The method involves determining an actual seismic moment density based on the wellsite data and a predicted seismic moment density based on shear and tensile components of the simulated hydraulic fracture network, and calibrating the discrete fracture network based on a comparison of the predicted moment density and the actual moment density.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for improving well production using a regression relationship approach. For example, one disclosed embodiment includes 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 analyzing a first set of data from at least one previously drilled well to predict fracture orientation for determining a drilling angle to optimize drilling of a new well by increasing fracture density along the new wellbore.

Abstract: A method for estimating a permeability of an earth formation includes: receiving a discrete fracture network (DFN) of the earth formation; representing the DFN as one or more volume sections, each volume section having a plurality of boundaries; identifying fractures that are connected to each other and lead from a first boundary in the plurality of boundaries to a second boundary in the plurality of boundaries to provide one or more flow paths for each volume section; applying Oda's method to the connected fractures making up the one or more flow paths to estimate the permeability of the earth formation along the one or more flow paths for each volume section to provide a permeability value for each volume section; and performing an action related to the earth formation using the permeability value for each volume section and an apparatus related to the action.

Abstract: Systems and methods for determining the optimum number of platforms to be used in a hydrocarbon field development and their position. The systems and methods determine the least valuable platform(s) and eliminate them from use in the hydrocarbon field development.

Abstract: Examples of techniques for determining robustness of a discrete fracture network (DFN) permeability estimate are disclosed. In one example implementation according to aspects of the present disclosure, a method may include: receiving a DFN of an earth formation of interest, the DFN comprising a plurality of connected fractures; determining a directional equivalent permeability of the plurality of connected fractures of the DFN using a numerical upscaling method; and determining the robustness of the directional equivalent permeability.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for performing gridless simulation of a fluvio-deltaic environment. For example, one disclosed embodiment includes 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 that include generating a set of channel centerlines corresponding to a set of channels that are indicative of flow units in a fluvio-deltaic environment; and generating channel widths for each of the channel centerlines. In one embodiment, the operations for generating the set of channel centerlines of the reservoir include selecting a seed point for each channel, assigning each seed point a direction of propagation, and iteratively generating each channel.

Abstract: Techniques for modelling a production forecast for a well are described. In one embodiment, a method includes calibrating a geological reservoir model by analyzing pressure transient well tests, fitting the geological reservoir model to pressure data to estimate model parameters, and building a simulated history of bottom hole pressure based on the model and measured transient flow data. The calibrating may further include fitting the model to flow rate data, using measured and simulated pressure data as input, to estimate model parameters, and then building a simulated history of downhole flow rate based on the model and change in measured pressure data. The calibrated model can be used to forecast future well production. Additional methods, systems, and devices are also disclosed.

Abstract: Systems and methods facilitate and automate well abandonment procedures. In an embodiment, well field data for a plurality of wells is categorized into well types. An inspection set of wells, including wells of each type, is determined from the entire plurality of wells. Inspection data is collected for each well type, including environmental, regulatory, and well condition data. The inspection data is extrapolated onto wells with similar types for the entire filed and analyzed. The analysis may include determining an optimal sequence of well abandonment activities, and an estimate of costs for abandoning each well, all wells of each type, and the entire well field. In an embodiment, a risk assessment analysis is performed and may include an analysis of factors that may change the cost of abandoning the well field or a sequence of well abandonment activities.

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: An information processing apparatus includes a database configured to store a plurality of physical quantities in time-series, a processor, and a memory storing a program causing the processor to execute acquiring the plurality of physical quantities, selecting first explanatory variates, selecting second explanatory variates, generating past case data by acquiring the physical quantities corresponding to the objective variates and an input variate group of the first explanatory variates and the second explanatory variates, searching for predetermined pieces of past case data in the sequence from the shortest of the inter-vector distances, building up the second model from the input variate group in the predetermined pieces of searched past case data and from the objective variates, and predicting values of objective variates from the second model.

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 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 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: 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: 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: 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: 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: 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: 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.