Abstract: A method of developing a petroleum reservoir from a flow model constrained by production data and seismic data is disclosed. It is used to define a development scheme and to start or continue the reservoir development. Production data and seismic data associated with a fine grid are acquired during the development of the reservoir. Production data, as well as pressure and saturation values, are simulated in each cell of the flow model. A pressure value and a saturation value are assigned to each cell of the fine grid. A pressure equation is therefore solved locally on the fine grid and the saturations are calculated by writing the continuity of the phase flows between neighboring lithofacies, the conservation of the pore volume and the conservation of the phase volume. The maps obtained are then used to simulate seismic data.

Abstract: Disclosed is a process for characterising the evolution of a reservoir over a time lapse comprising the steps of: providing a base and a plurality of monitor surveys of the reservoir, each having a set of seismic traces at different times; deriving an optimal regularization weight-map from a combination of at least three surveys; and using the optimal regularization weights to invert and obtain an improved time lapse seismic image between pairs of seismic surveys.

Abstract: A method of developing a petroleum reservoir from a reservoir model constrained by the production data and seismic attributes. Production data and seismic data are acquired during the development of the reservoir. A first image of a seismic attribute is constructed from the seismic data. Production responses are simulated from a reservoir model using a flow simulator. An image corresponding to the seismic attribute is simulated from the reservoir model. A local dissimilarity map is constructed from the reference seismic attribute image and from the simulated seismic attribute image. The reservoir model is modified to minimize any difference between the measured production data and the corresponding production responses and to minimize local dissimilarities. This model is used to determine an optimal development scheme and the reservoir is developed according to the development scheme.

Abstract: Systems and methods for modeling wellbore trajectories using curvature bridging functions. The systems and methods use a clothoid spiral as a bridging curve in the transition zones to reduce tubular stresses/failures in the design of multilateral well paths and extended reach well paths.

Abstract: This specification describes systems, methods, and software relating to geomechanical modeling of a subterranean region (104). In some aspects, finite difference (FD) grid data (200a) and finite element (FE) mesh data (202a) are received. The FD grid data include FD grid node locations (210) and FD grid values. The FD grid values include values of a subterranean formation property for each FD grid node location. The FE mesh data include FE mesh node locations (212) and spatial domains (214) for each of the FE mesh node locations. Values of the subterranean formation property are generated for each of the FE mesh node locations. The value for a given FE mesh node location is generated based on the FD grid values for FD grid node locations within the spatial domain about the given FE mesh node location. The generated values are assigned to the FE mesh node locations of the FE mesh data (202b) for geomechanical modeling of the subterranean region.

Abstract: A method can include rendering terrain and equipment locations to a display; assigning one or more domain constraints; analyzing an objective function associated with the terrain and the equipment locations subject to at least one of the one or more domain constraints; and rendering information to the display based at least in part on the analyzing. Various other technologies, techniques, etc., are also disclosed.

Abstract: A method can include receiving a model of a network of a production system that includes information that specifies branches and pieces of equipment; processing, optionally in parallel, at least a portion of the information for at least a portion of the model of the network; and, based at least in part on the processing, assigning a flow direction to each of the branches in the at least a portion of the model of the network. Various other technologies, techniques, etc., are also disclosed.

Abstract: A method of improving a geologic model of a subsurface region. One or more sets of parameter values are selected. Each parameter represents a geologic property. A cost and a gradient of the cost are obtained for each set. A geometric approximation of a parameter space defined by one or more formations is constructed. A response surface model is generated expressing the cost and gradient associated with each formation. When a finishing condition is not satisfied, at least one additional set is selected based at least in part on the response surface model associated with previously selected sets. Parts of the method are repeated using successively selected additional sets to update the approximation and the response surface model until the finishing condition is satisfied. Sets having a predetermined level of cost to a geologic model of the subsurface region and/or their associated predicted outcomes are outputted to update the geologic model.

Abstract: Determining viable hydraulic fracture scenarios. At least some of the illustrative embodiments include: executing a fracture planning program, and determining a set of schedules from the fracture planning program, each schedule comprising a volume of fracture fluid, amount of proppant, and flow rate of the fracture fluid; providing each schedule of the set of schedules to a stress analysis program, executing the stress analysis program, and determining a set of indications from the stress analysis program, each indication indicative of whether a respect schedule exceeds engineering limits of a tubing string; and providing at least some of the schedules to a fracture simulation program, executing the fracture simulation program, and determining a set of fracture geometries from the fracture simulation program, each fracture geometry corresponding to a respective schedule.

Abstract: A method, system and computer program product is disclosed for utilizing proxy models to evaluate a subterranean reservoir. The method includes constructing a proxy model from a set of sampling points to approximate simulation outputs of a reservoir model. The set of sampling points is updated by adding at least one new sampling point that is selected from a location associated with surface non-linearities such as gradients, curvature, and bending energy. Response surface values at new sampling points and distances to existing sampling points can also be used to evaluate new sampling points. Proxy models are refined with the updated set of sampling points until the proxy model satisfies a predetermined stopping criterion, such as when a predetermined number of iterations are reached or when changes to the response surface are below a predetermined threshold.

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

Abstract: A computer-implemented method, computer program product, and computing system for obtaining an oil field modeling file. One or more values are associated with one or more variables included within the oil field modeling file. The oil field modeling file is executed to generate one or more result sets. A portion of each of the one or more result sets is compared with empirically-derived data related to the portion.

Abstract: Systems and methods which implement surrogate (e.g., approximation) models to systematically reduce the parameter space in an optimization problem are shown. In certain embodiments, rigorous (e.g., higher fidelity) models are implemented with respect to the reduced parameter space provided by use of surrogate models to efficiently and more rapidly arrive at an optimized solution. Accordingly, certain embodiments build surrogate models of an actual simulation, and systematically reduce the number of design parameters used in the actual simulation to solve optimization problems using the actual simulation. A multi-stage method that facilitates optimization of decisions related to development planning and reservoir management may be provided. Iterative processing may be implemented with respect to a multi-stage optimization method. There may be uncertainty in various parameters, such as in reservoir parameters, which is taken into account according to certain embodiments.

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

Abstract: A method of planning a drilling operation IS provided that comprises selecting a set of targeted regions based on data from a three-dimensional shared earth model and generating at least one targeted segment within each one of the set of targeted regions The method further comprises defining at least one application agent for the purpose of evaluating the at least one targeted segment within each one of the set of targeted regions based on a potential payout in terms of production of hydrocarbons The exemplary method additionally comprises identifying at least one well trajectory through the at least one targeted segment within each one of the set of targeted regions And the method comprises employing the at least one application agent to evaluate well trajectories based on the potential payout in terms of at least one of production of hydrocarbons, drilling complexity, cost or stability of well planning.

Abstract: The software application is used to rank language translations and a method to implement those ranked language translations. The language translations are for textual or vocal phrases that a user wants to convert from its original language to a preferred language. The software application will refer to a variety of translation sources in order to create a set of applicable translations for a textual or vocal phrase. The software application will then rank each applicable translation with an accuracy score, which is weighed by three factors: the commonalities between the set of translation sources, a user input process, and a linguistic mapping process. Some methods to implement the ranked language translations include using accelerometer data from a electronic communication device to operate the software application, integrating a moderator into a conversation process, using subtitles in speech bubbles for a video chat, and using location data to communicate with different contacts.

Abstract: An example system includes interconnected modeling modules that share knowledge to create a unified earth model dynamically representing a subsurface site. The system models and may simulate subsurface operations associated with, for example: hydrocarbon production and stimulation, natural gas storage, carbon capture and storage, aquifer maintenance, geothermal energy production, and in-situ leachable ore processing. The system integrates a reporting module, and also an economic module to evaluate cost versus benefit of each subsurface operation. A related example method for performing subsurface engineering includes generating a model of a subsurface site including a geological horizon, obtaining an offset relative to the geological horizon, and locating an operation based on the offset. When field data update the model in real time, positions of 3D objects and 3D surfaces are dynamically updated in the model, including the positions of the modeled operations.

Abstract: A system, method, and software are provided for use in modeling zonal allocation in multilayered subterranean reservoirs. Information associated with a wellbore that is in fluid communication with producing zones of a multilayered subterranean reservoir is provided. A methodology is selected to compute zonal splits for the wellbore and zonal splits for the wellbore are automatically computed using the selected methodology and the information associated with the wellbore.

Abstract: The invention IS a method for exploiting (EXP) a geological reservoir by using a reservoir model consistent with a geological model (MG). Reservoir models (MRn) are constructed by using different upscaling methods. By utilization of a connectivity study, conducted on the basis of an algorithm resolving the shortest path (DIS) applied to the meshings, the main flowpaths are identified between the wells for the geological model (MG) and for the different reservoir models (MRn). The reservoir model (MR) for which the lengths of the main flowpaths between wells are closest to those obtained for the starting geological model is then selected.

Abstract: In some aspects, sand stabilization treatments are analyzed. A computing system can determine a first predicted resource production output for a subterranean reservoir based on a sand stability model analysis for a native condition of the subterranean reservoir. The computing system can determine a second predicted resource production output for the subterranean reservoir based on a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir. The computing system can output an economic value comparison of resource production for the native condition and the stabilization-treated condition based on the first and second predicted resource production outputs.

Abstract: A method, apparatus, and program product determine an effective trap size for reservoir traps of an oil and gas reservoir. Geological data is analyzed to determine structural spill points. Based on the structural spill points and the geological data reservoir traps are identified. An effective trap size for at least some of the reservoir traps of the reservoir is determined based on the structural spill points and the geological data.

Abstract: Method and system are described for modeling one or more geophysical properties of a subsurface volume (102). The present disclosure provides method of modeling the subsurface comprising obtaining one or more subsurface volumes and performing at least two operations (104) on the subsurface volumes. A graph of operations is determined (106) based on each of the at least two operations in which the graph of operations includes a description of each of the at least two operations and a flow path for the each of the at least two operations (108). The graph of operation is stored (110). A specific operation within the graph of operations may then be identified (112). An additional operation may be created and connected to the graph of operations at a node associated with the specific operation to provide an additional branch to the graph of operations (114).

Abstract: Reservoir simulation is performed for giant reservoir models in a parallel computing platform composed of a number of processor nodes. Automatic precautionary checkpoints are made at regular time intervals when computational time exceeds a preset value. The simulator receives and reacts to signals from a real time monitoring interface tool which monitors the health of the system. Checkpoints are also made done if a system problem which may cause a simulation job to fail is projected. The simulation job is subsequently restarted to continue simulation from the last checkpoint. The monitoring and automatic recovery are done automatically without need for user intervention.

Abstract: A method for recovering oil from a subterranean, hydrocarbon-bearing formation includes at least one injection well and injecting a carrier fluid including a diverting agent into a high permeability pathway within the formation. An activating fluid is injected into the high permeability pathway within the formation, resulting in the precipitation or swelling of the diverting agent. The permeability of the high permeability pathway is decreased within the formation containing the diverting agent to a permeability less than the permeability of the adjacent areas of the formation. The carrier fluid may have a predetermined residence time within the formation prior to injecting an activating fluid; the step of injecting a carrier fluid comprising a diverting agent and injecting an activating fluid may be repeated. A mineralization fluid may be injected that is oversaturated or becomes oversaturated upon interacting with the acid gas that causes mineral precipitation to seal off high-permeability pathways.

Abstract: In some aspects, a target net treating pressure for an injection treatment of a subterranean region is determined. Fracture growth orientation in a subterranean region is modeled by a computer system. In the model, the fracture growth is a response to fluid pressure acting on the subterranean region. A target net treating pressure for fluid acting on the subterranean region during an injection treatment of the subterranean region is determined based on the modeled fracture growth orientations.

Abstract: Methods for identifying hydrocarbon plays include applying predictive models to sediment fill volume(s) to provide play-element volume(s) representing at least one play element. Each play-element volume represents at least 1) qualities of the at least one play element and 2) a probability that the at least one play element satisfies determined criteria for each of a plurality of locations within a basin. The methods further include analyzing the play-element volume(s) to define play-concept volume(s) representing hydrocarbon play(s). Each of a plurality of locations within the play-concept volume(s) is attributed with: 1) an identification of each play element associated with the location, 2) the qualities of each play element, 3) the probability for each play element that it satisfies determined criteria, and 4) a composite likelihood that the location represents a hydrocarbon play. At least one of the volumes may be used to identify hydrocarbon play(s).

Abstract: A method for generating one or more geological models for oil field exploration. The method includes receiving one or more well facies logs, a vertical facies proportion curve, a lateral proportion map, a variogram model and a global target histogram. The method then includes generating a facies probability cube using a modified Sequential Gaussian Simulation (SGSIM) algorithm, the well facies logs, the vertical facies proportion curve, the lateral proportion map and the variogram model. After generating the facies probability cube, the method includes matching the facies probability cube to the global histogram and generating the geological models based on the matched facies probability cube.

Abstract: A method is disclosed of enhancing one or more attributes of a log, of a geological formation, including data generated in plural measurement channels corresponding to plural measurement devices, the method including the steps of: selecting data corresponding to a single said channel and deconvolving it; and seeking to impose one or more attributes of the resulting deconvolved data onto convolved log data of plural said channels in order to create an enhanced log.

Abstract: The method relates to the field of hydraulic fracturing of subsurface formations. A mathematical simulation model of a pressure pulse propagation inside a wellbore and inside a fracture is created. Pressure pulses are sent to the wellbore, and the response of the well to the pressure pulses is registered. Then, a bottom-hole pressure corresponding to each pulse is determined. An average fracture width is derived by using the mathematical simulation model of pressure pulse propagation inside the wellbore and inside the fracture, and a ratio between the simulated average fracture width and the determined bottom-hole pressure is determined. The said ratio is extrapolated to a zero-width point, and the closure pressure is determined as the bottom-hole pressure corresponding to the zero width.

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 ar evaluated and assigned weights indicative of the fit of the models of the segmentation t the underlying data. The segmentation models are further used to calculate a result that may be input to a process control program.

Abstract: Described is method and system of determining horizontal stress from radial profiles of dipole shear together with the far-field estimate of the Stoneley shear modulus. The system and method include selecting an optimal number of regression points on measured radial profiles for obtaining reliable estimation of maximum and minimum horizontal stress magnitudes in the presence of noisy data, where measured radial profiles of dipole shear moduli might exhibit a small amount of random fluctuations.

Abstract: Methods and systems to characterize a fluid in a reservoir to determine if the fluid is in one of equilibrium or non-equilibrium in terms of one of gravity, solvency power, entropy effect or some combination thereof. The method includes acquiring tool data at each depth for each fluid sample of at least two fluid samples wherein each fluid sample is at a different depth and communicating the tool data to a processor. Determining formation properties of each fluid sample to obtain formation property data and determining fluid properties for each fluid sample to obtain fluid property data. Selecting a mathematical model based on one of gravity, solvency power or entropy, in view of a fluid property, using one of tool data, formation property data, fluid property data, known fluid reservoir data or some combination thereof, to predict if the fluid is in an equilibrium distribution or a non-equilibrium distribution.

Abstract: Methods of designing an earth-boring tool are described, including calculating one or more performance parameters based on drilling conditions, a plurality of wear state values, and a set of values of other design variables. Methods of enhancing a performance parameter in the design of an earth-boring tool are also described, including calculating the performance parameter based at least partially on a plurality of wear state values and a first set of values of other design variables, calculating the performance parameter based at least partially on the plurality of wear state values and a second set of values of design variables different than the first set, and comparing the calculated performance parameters to determine which of the first and the second set is closer to a target range or value across a range of the plurality of wear state values. Related methods of forming an earth-boring tool are also described.

Abstract: The invention relates to a system for modeling an oilfield, which has process facilities and wellsite operatively connected, each wellsite having a wellbore penetrating a subterranean formation for extracting fluid from an underground reservoir. The system includes multiple wellsite simulators, each modeling a portion of the wellsite, at least one non-wellsite simulator, each modeling a portion of a non-wellsite region of the oilfield; and at least one coupling positioned among the wellsite simulators and the non-wellsite simulator. The coupling selectively links the wellsite simulators and the non-wellsite simulator according to a pre-defined configuration for selective communication.

Abstract: The present invention enables the use of a global optimization method for performing joint-inversion of multiple petrophysical data sets, using forward models based on first principle of physics, to generate a 3D rock representation of a subsurface rock structure. The resulting 3D rock representation captures the internal structure, and honors the measured petrophysical properties, of the subsurface rock structure. The 3D rock representation can then be used to predict additional properties not considered in the inversion, to further characterize the subsurface rock structure.

Abstract: A method is disclosed for operating an oil pool based on a reservoir model gradually deformed by means of cosimulations. A map of a property of the pool is obtained by a stochastic simulation of a first random function. A correlation coefficient is chosen between the first random function and a second random function with an identical mean and covariance. The map is modified by a cosimulation of the two random functions by using the correlation coefficient. The correlation coefficient is modified and the cosimulation step is reiterated to deform the map and minimize a matching objective function. Finally, the pool is operated by implementing an operating scheme accounting for the deformed map.

Abstract: Apparatus and method of conducting a drilling operation are provided. One embodiment of the method includes drilling a borehole, predicting a value of a first parameter relating to the drilling of the borehole using a geomechanical model, estimating a value of a second parameter from measurements taken by a sensor, updating the geomechanical model based at least in part on the estimated value of the second parameter, predicting a second value of the first parameter using the updated geomechanical model, and altering a drilling parameter for drilling the borehole based on the predicted second value of the first parameter.

Abstract: A disclosed method of downhole tool system development comprises: receiving specifications of a downhole tool system that comprises multiple strings, each string having one or more components; and checking for interference between the multiple strings in an initial position. A disclosed system comprises: a memory that stores software; and a processor coupled to the memory to execute the software. The software causes the processor to provide a graphical user interface that enables a user to specify a downhole tool system having multiple strings, and to test the strings for diametrical overlap attributable to relative motion of the strings.

Abstract: A method of forming a geologic model of a subsurface region is disclosed. Data related to the subsurface region is obtained. A framework is constructed to represent the subsurface region. A template is selected from a plurality of templates. The selected template provides at least one property that is characteristic of the subsurface region. The selected template is inserted into the framework, to form the geologic model. The geologic model is then outputted.

Abstract: Systems, methods, and computer-readable media are provided for a near-well unstructured grid model builder for generating a full-field unstructured grid for reservoir simulation. As described further below, the near-well unstructured grid model builder may include a workflow interface and a parallel unstructured grid model builder. The inputs to the near-well unstructured grid model builder may include existing well trajectory and completion data, future well data, a geological model, a structured grid simulation model, or any combination thereof. The near-well unstructured grid model builder may output a near-well unstructured grid having a specified grid resolution in regions of interest that include a well.

Abstract: A computer-implemented reservoir prediction system, method, and software are provided for modeling the behavior of non-Newtonian fluids in subterranean reservoirs while accounting for shear-rate dependent viscosity and permeability reduction with a skin zone characterized by a traditional skin factor and an apparent skin factor. A non-Newtonian fluid injection pressure or a non-Newtonian fluid injection rate is computed at steady-state responsive to reservoir data associated with a subterranean reservoir, injection data for a non-Newtonian fluid, and fluid data for the non-Newtonian fluid. The shear-rate dependent viscosity can further be applied to a well model in numerical reservoir simulation to improve the well model.

Abstract: A method is disclosed for partitioning a grid representing a hydrocarbon reservoir. The grid is composed of a plurality of cells. A connectivity graph of nodes and edges is created. Each of the plurality of cells is represented by a node. Edges connect neighboring nodes. An edge that should not be cut by a partitioning algorithm is designated. Nodes connected by the designated edge are merged into a supernode. A first edge connecting a merged node and a non-merged node is replaced with a second edge connecting the non-merged node with the supernode. The connectivity graph is used with the supernode and the replaced edges to partition the grid. Nodes merged into supernodes are maintained in a single subdomain during partitioning.

Abstract: A method for efficient inversion of measured geophysical data from a subsurface region to prospect for hydrocarbons. Gathers of measured data (40) are encoded (60) using a set of non-equivalent encoding functions (30). Then all data records in each encoded gather that correspond to a single receiver are summed (60), repeating for each receiver to generate a simultaneous encoded gather (80). The method employs iterative, local optimization of a cost function to invert the encoded gathers of simultaneous source data. An adjoint method is used to calculate the gradients of the cost function needed for the local optimization process (100). The inverted data yields a physical properties model (110) of the subsurface region that, after iterative updating, can indicate presence of accumulations of hydrocarbons.

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

Abstract: A quantitative calculation method for oil (gas) saturation of fractured reservoir during petroleum exploitation is provided. The method comprises: obtaining the fracture porosity and calculating resistivity index at different depth of fractured reservoir with known full diameter core data and imaging logging data; establishing the percolation network model of matrix and fracture combination with known pore structure feature; calibrating the numerical simulation results obtained from percolation network model based on the data of core experiment and sealed coring analysis results, then obtaining the relationship between the resistivity index (I) and water saturation (Sw) at different fracture porosity; calculating the oil (gas) saturation of fractured reservoir through selecting an interpolation function. The oil (gas) saturation calculated with said method is 0.67, however 0.49 with common method in some fractured reservoir. The accuracy is improved by more than 0.18 in the studied fractured reservoir.

Abstract: A method, system and apparatus are disclosed for coupling independent reservoir and surface facility network simulators. A reservoir simulator is configured to simulate fluid flow in subterranean reservoirs and a surface facility network simulator is configured to simulate fluid flow in production equipment. Simulation of fluid flow in a subterranean reservoir is initiated using the reservoir simulator. Simulation of fluid flow in production equipment is initiated using the surface facility network simulator. The simulated fluid flow in the production equipment includes fluids produced from the subterranean reservoir. The simulation of fluid flow in the subterranean reservoir is coupled with the simulation of fluid flow in the production equipment using a sub-domain inflow performance relationship.

Abstract: A computer-implemented reservoir prediction system, method, and software are provided for quantifying uncertainty and evaluating production performance of a subterranean reservoir. A reservoir simulation model representing a subterranean reservoir and an associated distribution of input variables are provided. A plurality of polynomial chaos expansions is generated. Each polynomial chaos expansion is used to approximate a simulation output of the reservoir simulation model for the distribution of input variables. Deterministic coefficients of the polynomial chaos expansions are calculated using a sampling process, such as a quasi-Monte Carlo method using a low discrepancy sequence. An output variable, such as cumulative oil production, and associated output variable uncertainty are forecasted using the polynomial chaos expansions and the deterministic coefficients such that production performance of the subterranean reservoir can be evaluated.

Abstract: Computer-implemented systems and methods are provided for generating corrected performance data of water flooding of an oil reservoir system based on application of a statistical correction factor methodology (SCF). For example, data related to properties of the oil reservoir system and data related to a water flooding scenario are received. Water flooding performance data is generated based on application of an analytical water flooding performance computation methodology. Based on application of the SCF methodology to the generated water flooding performance data, corrected water flooding performance data is determined, representative of oil recovery by the water flooding of the oil reservoir system. The SCF methodology can also be used to evaluate water production based on parameters such as water-oil ratio and water cut, identify possible analog reservoirs that have similar water production performance, and calculate a Gross Injection Factor to account for water loss in the reservoir.

Abstract: In an embodiment, creation of a continuous three dimensional array of data from digital information obtained from a wellbore, and representation in a seismic data formatted dataset. In an embodiment, providing the capability to export stratigraphic interpretations made while working within the 3D-log data volume back to any wellbore that is encompassed within the areal extent of the 3D-log data volume. In one embodiment, a 2D well grid creation process comprises the steps of (a) selecting an initial grid spacing, (b) assigning wells from a dataset of well data to closest nodes in the grid, (c) if a plurality of wells are assigned to a single node after completing step (b), narrowing the grid spacing and repeating step (b) until no more than one well is assigned to any node. In an embodiment the non-well nodes are populated by extrapolating from adjacent single well nodes.

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.