Abstract: A method, including: generating a velocity model for a subsurface region of the Earth by using a full wavefield inversion process; generating an impedance model for the subsurface region of the Earth by using a full wavefield inversion process; and estimating pore pressure at a prediction site in the subsurface region by integrating the velocity model and the impedance model with a velocity-based pore pressure estimation process.

Abstract: The present disclosure provides a method for optimizing bunch distance of fractured horizontal wells of shale gas, which relates to the technical field of oil exploration. The method comprises first establishing a stress field distribution model for a single fracture; then establishing an induced stress distribution model of segmented single-bunch fracturing for a horizontal well; later establishing an induced stress distribution model of segmented multi-bunch fracturing for a horizontal well; last optimizing fracturing parameters and fracture distance according to the distribution pattern of the induced stress difference.

Abstract: A method of performing a fracture operation at a wellsite is provided. The wellsite has a fracture network therein with natural fractures.

Abstract: Described herein are various embodiments of computer-implemented methods, computing systems, and program products for analyzing a flood operation on a hydrocarbon reservoir. For example, an embodiment includes establishing a dataset of allowed well connections for at least one production well and at least one injection well of the hydrocarbon reservoir. The embodiment includes iteratively modifying the dataset of allowed well connections based on a distance category, a static features category, a dynamic features category, or any combination thereof, where the static features category uses static data of the hydrocarbon reservoir and the dynamic features category uses dynamic data of the hydrocarbon reservoir. The embodiment includes, after iteratively modifying the dataset of allowed well connections, running capacitance resistance modeling using the modified dataset of allowed well connections as an input.

Abstract: Methods for using shut-in pressures to determine uncertainties in a hydraulic fracturing process in a shale reservoir are described. Data commonly collected during multistage fracturing is used to calculate propped fracture height and induced stresses, as well as other variables, in the presence of horizontal stress anisotropy. These variables can then be incorporated into reservoir simulations for fracturing monitoring, forecasting hydrocarbon recoveries, or modifying fracturing plans.

Abstract: A computer-implemented method for updating subsurface models including: using an offset continuation approach to update the model, and at each stage defining a new objective function where a maximum offset for each stage is set, wherein the approach includes, performing a first stage iterative full wavefield inversion with near offset data, as the maximum offset, to obtain velocity and density or impedance models, performing subsequent stages of iterative full wavefield inversion, each generating updated models, relative to a previous stage, wherein the subsequent stages include incrementally expanding the maximum offset until ending at a full offset, wherein a last of the stages yields finally updated models, the subsequent stages use the updated models as starting models, and the full wavefield inversions include constraining scales of the velocity model updates at each stage of inversion as a function of velocity resolution; and using the finally updated models to prospect for hydrocarbons.

Abstract: Systems and methods for predicting an accurate in-situ stress field in a wellbore in a formation are disclosed. The in-situ stress field is calculated using an optimizing process that takes into account parameters relating to induced tensile fracture that are derived from wellbore image logs and other input data relating to the wellbore. Once values for the in-situ stress field are predicted, those values can be used to generate synthetic image logs and fracturing data which can then be compared to the original image logs and fracturing data to determine the accuracy of the results and if needed repeat the operation to obtain more accurate results.

Abstract: A method for determining a flow distribution of a wellbore during a wellbore treatment comprises disposing an optical fiber into a wellbore, performing a wellbore treatment in the wellbore with the fiber optic in place by flowing a well treatment fluid from the surface and wellbore and into the formation, taking distributed temperature measurements at a time interval with the fiber optic cable during the wellbore treatment operation, and calculating a flow distribution of the wellbore while performing the wellbore treatment.

Abstract: Techniques for determining geometries of hydraulic fractures include identifying a data structure that includes data associated with hydraulic fracture identifiers and observed fluid pressures, at least one of the hydraulic fracture identifiers representing a first hydraulic fracture formed from a monitor wellbore into a subsurface rock formation and at least another of the hydraulic fracture identifiers representing a second hydraulic fracture formed from a treatment wellbore into the subsurface rock formation, at least one of the observed fluid pressures includes a pressure change in a fluid in the first hydraulic fracture that is induced by formation of the second hydraulic fracture; performing a single- or multi-objective, non-linear constrained optimization analysis to minimize at least one objective function associated with the observed fluid pressures; and based on minimizing the at least one objective function, determining respective sets of hydraulic fracture geometries associated with at least one o

Abstract: The invention is a method for optimizing working (EXP) of a deposit of fluid traversed by a network of fractures that involves determining the transitory exchange terms between matrix blocks and fractures (FFA, FFN), for any type of available information (INFO) concerning the network of fractures, regardless of the level of knowledge of the fractured environment.

Abstract: Energy Analytics Learning Machine (or EALM) system is a machine learning based, “brutally empirical” analysis system for use in optimizing the payout from one or more energy sources. EALM system optimizes exploration, production, distribution and/or consumption of an energy source while minimizing costs to the producer, transporter, refiner and/or consumer. Normalized data are processed to determine clusters of correlation in multi-dimensional space to identify a machine learned ranking of importance weights for each attribute. Predictive and prescriptive optimization on the normalized energy data is performed utilizing unique combinations of machine learning and statistical algorithm ensembles. The unstructured textual energy data are classified to correlate with optimal production to capture the dynamics of one or more energy sources of physically real or theoretically calculated systems to provide categorization results from labeled data sets to identify patterns.

Abstract: Embodiments of the invention include systems, methods, and computer-readable mediums for optimizing the placement of wells in a reservoir. Embodiments include, for example, determining for a reservoir a layer productivity index for coordinates of a reservoir using reservoir metrics and specified well spacings associated with the reservoir, determining a total dynamic productivity index for the coordinates based on the layer productivity index, and determining placement of one or more wells responsive to the total dynamic productivity index and defined spacing between the one or more wells. Embodiments further include, for example, generating a production analysis report for the reservoir that includes an assessment of well placement and generating a wells placement map using one or more total dynamic productivity index indicators.

Abstract: A computer-implemented method for updating a physical properties model of a subsurface region in an iterative inversion of seismic data using a gradient of a cost function that compares the seismic data to model-simulated data, said method comprising: obtaining a contrast model of a subsurface physical parameter that is sensitive to data dynamics and a kinematic model of a subsurface physical parameter; determining a gradient of a cost function using the contrast model and the kinematic model, wherein the cost function compares seismic data to model-simulated data; updating the kinematic model using a search direction derived from the gradient; adapting the contrast model according to an update to the kinematic model performed in the updating step; iteratively repeating the determining, updating, and adapting steps until a predetermined stopping criteria is reached, and generating a subsurface image from a finally updated kinematic model; and using the subsurface image to prospect for hydrocarbons.

Abstract: A method, system and computer program product for blinder avoidance in social networking interactions includes executing a social networking data processing system in memory of a host computing system to provide a social networking service to different users in a social network. The method also includes defining in memory of the host computing system a user interface interaction for a user interface of the social networking service, and a corresponding user interface change in connection with a presentation of a status update for a user in different streams of other users of the social networking service. In response to detecting the user interface interaction with respect to a stream of status updates presented to one of the other users, the corresponding user interface change is performed in the user interface in connection with the presentation of the status update for the user in the stream.

Abstract: An apparatus is for transferring information acoustically via a tubular. The apparatus has a signal generator, an energy source, and means for intrusion into a tubular wall at a desired location. The signal generator is arranged to generate signals with a P-wave direction substantially approximating the axial direction of said tubular at said desired location. The means for intrusion into a tubular wall are adapted for transferring acoustic signals from the apparatus into the tubular. The apparatus further has a mechanical plug comprising fastening means for anchoring into a tubular wall. The plugs fastening means constitutes the apparatus' means for intrusion into a tubular wall. A method for transferring information acoustically via a tubular is disclosed.

Abstract: An illustrative hydraulic fracturing flow simulation system includes: a data acquisition module collecting measurements from a subterranean formation; a processing module implementing a hydraulic fracturing simulation; and a visualization module that displays a time-dependent spatial distribution. The implemented method includes: modeling a connected network of fractures; assigning an orientation to each fracture in the network to locate two different flow parameter types at each junction, thereby defining an arrangement of different flow parameter types spatially staggered along each fracture; capturing the arrangement as a set of linear equations for iteratively deriving a subsequent flow state from a current flow state; simulating flow through the network of fractures by repeatedly solving the set of linear equations; and determining the time-dependent spatial distribution of at least one flow component.

Abstract: A method includes obtaining a plurality of master sensor responses with a master sensor in a set of training fluids and obtaining node sensor responses in the set of training fluids. A linear correlation between a compensated master data set and a node data set is then found for a set of training fluids and generating node sensor responses in a tool parameter space from the compensated master data set on a set of application fluids. A reverse transformation is obtained based on the node sensor responses in a complete set of calibration fluids. The reverse transformation converts each node sensor response from a tool parameter space to the synthetic parameter space, and uses transformed data as inputs of various fluid predictive models to obtain fluid characteristics. The method includes modifying operation parameters of a drilling or a well testing and sampling system according to the fluid characteristics.

Abstract: A monitoring system can include a dashboard including a graphical user interface display space. The monitoring system can also include a digital twin validation system including a processor configured to perform operations including rendering, in a graphical user interface display space, an interactive graphical object characterizing a first input value of a first digital model of a plurality of oil and gas industrial machines. The operations can also include receiving data characterizing user interaction with the interactive graphical object. The data characterizing the user interaction can be indicative of the first input value of the first digital model. The operations can further include updating the first digital model to generate updated output values representative of an operational parameter of the plurality of oil and gas industrial machines. The operations can also include rendering, in the graphical user interface display space, a visual representation of the updated output values.

Abstract: Systems and methods for determining operating settings of a fluid production system with a gathering network and a plurality of reservoirs, at least some of which include a method that includes lumping common pseudo-components into reservoir pseudo-components associated with each of the reservoirs. Each common pseudo-component is associated with the gathering network and maps to one reservoir pseudo-component of each of the reservoirs. The method further includes performing at least part of a fully-coupled simulation of the gathering network and the reservoirs using the common pseudo-components to obtain one or more operating settings that meet one or more constraints of the production system, and presenting to a user the operating settings.

Abstract: In some embodiments, a system, as well as a method and an article, may operate to generate a first matrix, based on equations that model a reservoir, that includes mass conservation and volume balance information for grid blocks in the reservoir; to generate a second matrix, based on the first matrix, that includes saturation information and pressure information of each grid block; to remove the saturation information from the second matrix to generate a third matrix that includes only pressure information; to solve the third matrix to generate a first pressure solution; to solve the second matrix based on the first pressure solution to generate a first saturation solution and a second pressure solution; and to use the first saturation solution and the second pressure solution to generate a solution of the first matrix. Additional apparatus, systems, and methods are disclosed.

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: Data from crosswell seismic surveys is processed to provide crosswell time-lapse data to map fluid changes in a reservoir where time-lapse or 4D seismic data is unavailable or unreliable, such as in onshore reservoirs. The resultant processing results provide quantitative information for history matching purposes using a probabilistic approach to take in account uncertainties in the geological model and reduce uncertainties in reservoir production forecasts.

Abstract: An example method includes receiving raw data sets containing drilling parameter and operating condition values generated during subterranean drilling operations. The raw data sets may be separated into training data sets based, at least in part, on the types of the subterranean drilling operations. At least one predictive model may be generated based, at least in part, on at least one training data set. The at least one predictive model may determine a rate of penetration (ROP) for a drilling operation of the same type to which the at least one training data set corresponds.

Abstract: Methods for simulating hydrocarbon (HC) migration and accumulation in a subsurface formation are provided. The methods include determining a plurality of HC mass associated with a plurality of grid cells representing the subsurface formation. The methods also include determining a plurality of HC mass outflow magnitudes for one or more grid cells in the plurality of grid cells, the HC mass outflow magnitude for each of the one or more grid cells having an upper bound value based on the HC mass in that grid cell. The methods update the HC mass of the plurality of grid cells based on the plurality of HC mass outflow magnitudes. The methods also determine that a set of grid cells in the plurality of grid cells contain an excess mass of HC, and perform an accumulation process to model filling of a trap associated with the set of grid cells.

Abstract: A method is provided including calculating a first property vector indicative of physical properties derived from a digital image of a first rock sample; determining a set of one or more similar rock samples by calculating a value indicating a similarity between the first rock sample and second rock samples based on the first property vector and second property vectors associated with the second rock samples; selecting a list of fluid additives based on existing enhanced fluid recovery efficiency values associated with the similar rock samples; performing, for each of the fluid additives, a simulation of a flow of fluid through a digital model of the first rock to determine a simulated enhanced fluid recovery efficiency value for the respective fluid additives; and outputting an optimal fluid additive for the first rock sample based at least in part on the calculated similarity values and simulated enhanced fluid recovery efficiency values.

Abstract: The invention is a method for exploring and exploiting a fluid in a subterranean formation comprising a network of fractures. On the basis of measurements of properties relating to the formation, a meshed representation of the formation, and statistical parameters relating to the network of fractures, each mesh of the meshed representation is broken down into at least one unfractured matrix block and an equivalent permeability tensor of the network of fractures in the mesh concerned is determined. A matrix block characteristic dimension is then determined according to a relation that is a function at least of the eigenvalues of the equivalent permeability tensor. Based on the meshed representation, the characteristic dimension and a flow simulator, there is defined an optimum exploitation scheme for the fluid of the formation and said fluid is exploited as a function of the optimum exploitation scheme.

Abstract: An exemplary method of analyzing a well log includes imaging a well log to form a well log image, performing pattern recognition on the well log image to determine pattern data, and determining stratigraphic structure data based on the pattern data. Another exemplary method of improving production from a stratigraphic structure includes performing pattern recognition on a well log image stored in an image format to determine pattern data, determining stratigraphic structure data using a computer-based structure analyzer based on the pattern data, and projecting well parameters based on the stratigraphic structure data. An exemplary system includes a scanner to scan a raster image of a printed well log and a computational system in communication with the scanner to receive the raster image. The computational system includes a pattern recognition analyzer to determine pattern data from the raster image and a structure analyzer to determine stratigraphic structure based on the pattern data.

Abstract: Computerized method, apparatus, and systems for management of a slurry injection well and the associated surface facility include a network for connectivity of facility equipment, sensor equipment, and control software operated on a computer system. The method utilizes real time and historical data of injection and slurry parameters in conjunction with computer simulations performed on a computer-modelled reservoir to predict well behavior during an injection event. The system determines optimized injection operation schedules and can recommend and implement changes to an injection operation while it is in process, including through automated equipment control.

Abstract: To measure the phase behavior of a fluid in a porous medium such as a tight gas shale, one illustrative method involves: (a) loading the fluid into a sample cell containing the porous medium; (b) setting a pressure and a temperature for the fluid in the sample cell; (c) applying an RF pulse sequence to the fluid in the sample cell to acquire an NMR signal; (d) deriving from the NMR signal an NMR parameter distribution that depends on the pressure and the temperature; (e) determining whether a fluid phase is present based on the NMR parameter distribution; (f) repeating operations (c) through (f) to determine the presence or absence of the fluid phase at multiple points along a pressure-temperature path that crosses a phase boundary; and (g) providing an estimated location of the phase boundary based on the presence or absence of the fluid phase at said points.

Abstract: The disclosure relates generally to a parallel computing framework designed to accelerate intensive kernel operations and address the complex physics in numerical reservoir simulations by effectively using the ‘many-core’ computing platform. Specifically, this Many-core Advanced Parallel Simulation (MAPS) uses heuristics to decide the optimal hardware configurations and optimal software components for a given problem's characteristics to efficiently design a model.

Abstract: The present invention relates to a visualized supercritical carbon dioxide fracturing physical simulation test method, comprising: preparing a rock sample, preparing a prefabricated fracture; curing the rock sample; fixing the cured rock sample in a confining pressure chamber, and applying a preset three-way confining pressure and pore pressure to the rock sample; turning on a high-speed camera, injecting supercritical carbon dioxide fracturing fluid to the central hole, and continuously recording a fluid injection pressure and test surface image information of the rock sample until the test is ended; observing a hydraulic fracture inside. Through this method, it is possible to obtain images in the whole process of initiation and extension of the artificial fracture during supercritical carbon dioxide fracturing, and distribution rules of parameters, such as stress, strain and pore pressure on the surfaces of the rock sample.

Abstract: The invention provides a method for predicting a reservoir reform volume after vertical well volume fracturing of a low-permeability oil/gas reservoir. The method sequentially includes the following steps: (1) calculating an induced stress produced by a hydraulic fracture in a three-dimensional space; (2) calculating a stratum pore pressure obtained after leak-off of fracturing fluid; (3) calculating a stratum pore elastic stress obtained after the leak-off of the fracturing fluid; (4) overlapping the stress fields obtained in the step (1), (2) and (3) with an original crustal stress field to obtain a new crustal stress field, and calculating the magnitude and direction of the overlapped three-direction effective principal stress in the reservoir space; (5) calculating an open fracturing determination coefficient M of a natural fracture in the reservoir space and a shear fracturing area determination coefficient S of the natural fracture.

Abstract: Systems and methods for positioning horizontal wells within a limited-pre-defined boundary. The systems and methods include an automated process for creating jointed target pairs or horizontal laterals to be utilized for planning horizontal wells in order to position the horizontal laterals within limited pre-defined boundary(ies).

Abstract: A method and computer system for performing simulation of a field having a subterranean formation. The method includes obtaining measured core sample data of a core sample retrieved from the formation, the core sample data measured by injecting fluid into the core sample, obtaining a digital rock model of the core sample describing a physical pore structure in the core sample, and obtaining a fluid model describing a physical property of the fluid. A digital core analysis (DCA) of the core sample is performed to generate a DCA simulation result and the DCA is tuned using the measured core sample data to reduce a difference between the DCA simulation result and the measured core sample data. The tuning is performed by adjusting, in response to the difference exceeding a pre-determined limit, a parameter of the DCA to generate an adjusted parameter and further performing the DCA to reduce the difference.

Abstract: Examples of techniques for integrated hydrocarbon fluid distribution modeling are disclosed. In one example implementation according to aspects of the present disclosure, a computer-implemented method may include: generating, by a processing device, a structural model of a hydrocarbon reservoir; generating, by the processing device, a fluid distribution model based on the structural model and well data; responsive to receiving updated well data, updating, by the processing device, the fluid distribution model iteratively; determining, by the processing device, a trajectory to drill the hydrocarbon reservoir based on the fluid distribution model; and drilling a well into the hydrocarbon reservoir based on the trajectory.

Abstract: In reservoir hydrocarbon exploration, fracture characteristics of subsurface reservoir formations are analyzed based on measures obtained about the subsurface formations and rock. Models of subsurface reservoirs are developed with predictions of natural fracture networks within the subject subsurface reservoirs. The mechanical properties of the formation rock in the reservoirs serve as a main controller to model the natural fractures distribution and their properties. The models so formed are important in the location and completion of wells for hydrocarbon exploration and production.

Abstract: Actual distributed temperature sensing (DTS) data and pressure data are received in response to a stimulation treatment applied to a hydrocarbon field. A pre-stimulation model is built that includes reservoir parameters, which generates simulated DTS and pressure data as a function of the reservoir parameters that include a permeability parameter and a skin parameter. In response to determining that a thermal match between the actual DTS and pressure data and the simulated DTS and pressure data is not obtained, the reservoir parameters are updated. In response to determining that the updated reservoir parameters do not match a performed pressure transient analysis (PTA), the reservoir parameters and the pre-stimulation model are updated, and the simulated DTS and pressure data are re-generated based on the updated pre-stimulation model.

Abstract: The disclosure pertains to the determining the efficiency of stimulation operations in a hydrocarbon well. Stimulation is performed in a hydrocarbon well and various data is obtained therefrom. The data is used to develop a simulation of fluid flow in the well and the simulation is used to model a synthetic tracer log, which corresponds to a modeled level of efficiency. Numerous synthetic tracer logs may be generated in this way so that tracer logs are available for a variety of different stimulation efficiencies. In order to determine the efficiency of an actual stimulation, the real tracer log of the stimulated well may be compared to the synthetic tracer logs in search of a match. When the real tracer log matches a synthetic tracer log the modeled efficiency of the synthetic log may be used as the actual or true efficiency of the real well stimulation.

Abstract: A parallel-processing hydrocarbon (HC) migration and accumulation methodology is applied to basin data to determine migration pathways and traps for high-resolution petroleum system modeling. HC is determined in parallel to have been expelled in source rocks associated with a plurality of grid cells divided into one or more subdomains. Potential trap peaks are identified within the plurality of grid cells. An invasion percolation (IP) process is performed until the HC stops migrating upon arrival to the plurality of trap peaks. A determination is made as to whether the grid cells containing HC contains an excess volume of HC. An accumulation process is performed to model the filling of the HC at a trap associated with the identified potential trap peaks. The trap boundary cell list is updated in parallel together with an HC potential value. Trap filling terminates when excess HC is depleted or a spill point is reached.

Abstract: Systems and methods for generating a custom reservoir from multiple compartments representing one or more geological structures by performing custom reservoir generation on each compartment to generate one or more combined compartments.

Abstract: A method in accordance with some embodiments comprises receiving input parameters specifying fracturing requirements, electronically accessing formation data associated with a target formation, and using a computer processor to dynamically generate a fracturing plan for at least one of a plurality of boreholes in the target formation. The plan includes potential fracture locations and lengths that account for existing or planned fracture locations along others of the plurality of boreholes and that further account for the received input parameters and the accessed formation data. The method also comprises fracturing the target formation along the plurality of boreholes in accordance with the fracturing plan.

Abstract: A method and system are described for characterizing fractures in subsurface regions, using the fracture characterizations in subsurface models, and using the subsurface models in hydrocarbon operations. In the methods and systems, one or more zones are identified in a subsurface model for fracture characterization; a multi-layer model is created for the selected zone; and macromechanical geological loads are applied and simulated to generate fractures for the zone.

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 performing reservoir characterization to generate a mechanical earth model based on integrated petrophysical, geomechanical and geophysical data. The method also involves generating a stimulation plan by performing well planning, a staging design, a stimulation design and a production prediction based on the mechanical earth model. The stimulation design is optimized by repeating the well planning, staging design, stimulation design, and production prediction in a feedback loop until an optimized stimulation plan is generated.

Abstract: A method for managing oilfield water. Oilfield water data is grouped into discrete and non-overlapping groups. Outliers are removed from the data. Features of the remaining data are analyzed to identify most discriminative feature. The data is separated into training data and testing data, and the training data is fit into a model that shows the best precision, accuracy and recall. The model is confirmed using the testing data. Upon confirmation of the accuracy of the model, the model is applied to data for a new proposed oilfield well, and a new proposed project is implemented or disapproved based on a result of the identified model that predicts water production of the new proposed oilfield well.

Abstract: Methods of managing aggregate inventory. The methods include utilizing a dynamic protocol for an oilfield operation with aggregate from chambers of a multi-silo system wherein each chamber accommodates a single aggregate type throughout operations. However, the chambers also have a dynamic classification as either active, idle or reserved depending on the stage of operations. Once more, even though each silo may accommodate multiple chambers, unique techniques may be utilized to obtain real-time inventory information for each chamber via weight measurement of entire silos.

Abstract: The invention relates to a method for history matching a facies geostatistical model using the ensemble Kalman filter (EnKF) technique. The EnKF is not normally appropriate for discontinuous facies models such as multiple point simulation (MPS). In the method of the invention, an ensemble of realizations are generated and then uniform vectors on which those realizations are based are transformed to Gaussian vectors before applying the EnKF to the Gaussian vectors directly. The updated Gaussian vectors are then transformed back to uniform vectors which are used to update the realizations. The uniform vectors may be vectors on which the realizations are based directly; alternatively each realization may be based on a plurality of uniform vectors linearly combined with combination coefficients. In this case each realization is associated with a uniform vector made up from the combination coefficients, and the combination coefficient vector is then transformed to Gaussian and updated using EnKF.

Abstract: Methods of performing a fracture operation at a wellsite with a fracture network are provided. The methods involve obtaining wellsite data and a mechanical earth model, and generating a hydraulic fracture growth pattern for the fracture network over time. The generating involves extending hydraulic fractures from a wellbore and into the fracture network of a subterranean formation to form a hydraulic fracture network, determining hydraulic fracture parameters after the extending, determining transport parameters for proppant passing through the hydraulic fracture network, and determining fracture dimensions of the hydraulic fractures from the hydraulic fracture parameters, the transport parameters and the mechanical earth model. The methods also involve performing stress shadowing on the hydraulic fractures to determine stress interference between fractures and repeating the generating based on the determined stress interference. The methods may also involve determining crossing behavior.

Abstract: The present invention relates to a production method for hydrocarbons contained in an underground formation penetrated by at least one well. The method is based on the determination of at least one productivity index IP dependent on the temperature and pressure.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for modifying a three-dimensional geocellular model. 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. The memory stores instructions that when executed by the at least one processor performs operations that includes loading into memory a three-dimensional geocellular model that corresponds to a two-dimensional geological model. The operations include determining a portion of the three-dimensional geocellular model affected by a change to the two-dimensional geological model and performing a local update to the portion of the three-dimensional geocellular model affected by the change.

Abstract: A method of optimization ICD design that includes consideration of reservoir characteristics, well configuration and type of enhanced oil recovery technique, as well as needed performance characteristics. Thus, the ICD is optimized for particular wells, reservoirs and/or enhanced oil recovery uses.