1071results about "Geomodelling" patented technology

The present invention, in one embodiment, is directed to a method and system for accelerating and improving the history matching of a well bore and/or reservoir simulation model using a neural network. The neural network provides a correlation between the calculated history match error and a selected set of parameters that characterize the well bore and/or the reservoir. The neural network iteratively varies a selection and/or the value of the parameters to provide at least one set of history match parameters having a value that provides a minimum for the calculated history matching error.

A reservoir production control system includes a plurality of wells for producing a reservoir linked to a central computer over a downhole communication network and a surface communication network. Both the downhole and the surface communication networks are wireless communications paths for transmitting downhole data and surface data to the central computer. Both networks include a series of interconnected tubing or pipe that allows transmission of data over electrically isolated portions of the pipe and tubing. After integrating and analyzing all relevant data and comparing the data with a reservoir model, the central computer initiates changes in a plurality of downhole control devices associated with the wells, thereby optimizing the production of the reservoir.

The invention relates to an object-oriented method for simulating a property of at least one fluid in a fluid-containing physical system in which the physical system is represented by a multiplicity of volumetric cells and a multiplicity of connections between cells. The method uses cell-group objects and connection-group objects in the simulation. The invention can optionally comprise additional objects such as an object containing the entire model of the simulation and another object containing a portion of the entire model.

Method for well re-stimulation treatment using instantaneous shut-in pressure (ISIP) to guide the design and execution of refracturing stages. Pore pressure and optional cluster stresses are determined at a start of the treatment. Goal ISIPs for the refracturing correspond to undepleted regions of the formation, and target ISIPs versus treatment progression/stage range from about a lowest pore pressure corresponding to depleted regions of the formation up to within the goal range ISIPs. Diversion and proppant pumping schedules are designed, and the refracturing treatment is initiated in accordance with the design. ISIP is measured at stage end, and if it varies from the target ISIP, subsequent stages are modified from the design as needed to more closely match the ISIP schedule.

The present disclosure relates to dynamically incorporating and economically validating drilling decisions. A computer system having a memory and central processing unit is provided and a knowledge store residing in the computer system is populated with data. The data may include surface drilling parameter data, bottomhole assembly data, bit records, measurement-while-chilling data, logging-while-drilling data, drilling event data, and lessons learned data. The data may be correlated data from one or more offset wells. One or more computerized static or dynamic contextual earth models are provided and used to dynamically incorporate and economically validate the drilling decisions. The one or more earth models can be updated in real-time.

Methods of predicting earth stresses in response to pore pressure changes in a hydrocarbon-bearing reservoir within a geomechanical system, include establishing physical boundaries for the geomechanical system and acquiring reservoir characteristics. Geomechanical simulations simulate the effects of changes in reservoir characteristics on stress in rock formations within the physical boundaries to determine the rock formation strength at selected nodes in the reservoir. The strength of the rock formations at the nodes is represented by an effective strain (ε_eff), which includes a compaction strain (ε_c) and out-of-plane shear strains (γ1-3, Y2-3) at a nodal point. The methods further include determining an effective strain criteria (ε_eff^cr) from a history of well failures in the physical boundaries. The effective strain (ε_eff^cr) at a selected nodal point is compared with the effective strain criteria (ε_eff^cr) to determine if the effective strain (ε_eff) exceeds the effective strain criteria (ε_eff^cr).

A system and method of modeling a geological body in a contemporary formation is presented that includes constructing a geological object based on an original depositional paleo-space associated with the contemporary formation, and copying the geological object, transforming the copy of the geological object based on a deformation model of the contemporary formation using acquired data, the transforming allowing modeling of the deformed formation geological body and a lateral extent spanning a plurality of fault blocks.

A method of generating a hybrid grid of a heterogeneous formation crossed by one or more geometric discontinuities such as, for example, an underground formation where one or more wells have been drilled, or a fractured formation, by combining structured grids and non-structured grids in order to carry out simulations in accordance with a defined numerical pattern is disclosed. Hybrid gridding is performed by associating a first structured grid (G1) for gridding of the heterogeneous medium considering discontinuities thereof with second structured, radial type grids (G2) for gridding of a zone around each pipe or well, which allows better consideration of constraints linked with flows in the zone. In order to connect the first grid of the medium and the second well grids, non-structured transition grids (G3) are interposed there between. A power diagram technique is used, which is particularly advantageous in that it allows appropriate connection of non-regular structured grids. An application is hydrocarbon reservoir simulation.

The method according to the invention allows the formation of oil and the retention phenomenon in the mother rock to be modelled. Organic matter characterization experiments are used to establish the molecular model (MM) of the initial sample (E). The thermal cracking reaction of this molecular model is reproduced by dynamic molecular simulation computations with a reactive force field (RMD) and validated by comparison with experimental data. The reaction mechanism obtained (SR) allows to carry out a kinetic study (C) by variation of the temperature parameter. The phase equilibria (PES) of the reaction medium are determined at any time from dynamic simulation. The successive phase equilibrium assessments at various progress stages of the cracking reaction allow following the physicochemical evolution (PC) of the thermal maturation of the organic sample studied. The free hydrocarbons (liquid and gaseous) that are not retained in the solid residue can be quantified throughout numerical modelling of the sample maturation; representing, in the sedimentary basins, the hydrocarbons that are not retained in the organic matrix of the mother rock (Q). This quantity can be used as an indicator or an input value for the retention threshold in basin models.

An interactive system and method of operating the system to define and evaluate a model of a hydrocarbon reservoir. The reservoir model is defined from extrinsic information such as seismic surveys, well logs, and the like, and is based on elements of formation regions, connections among the regions, wells, and perforations. A boundary-element method is used to determine pressure interference responses, corresponding to the pressure at a perforation in response to a single perforation producing fluid at a unit flow rate. These pressure interference responses are then convolved with measured well flow rates obtained during production to arrive at estimates of the wellbore pressure at one or more wells of interest. The estimated wellbore pressure can be compared with downhole pressure measurements to validate the reservoir model, or to provoke the user into modifying the model and repeating the evaluation of the model.

The disclosed methods, systems, and software are described to optimize fracture characteristics and simulate fluid flow rates in a well model. The well model, which includes at least one fracture intersecting a production well, is generated with static and dynamic data. Fluid flow in the well model is simulated to obtain simulated fluid flow rates between fractures and the well. Fracture properties, such as length, height and aperture, are then updated responsive to measured and simulated fluid flow rates. Multiple simulation runs and updating of the fracture properties can be performed until the simulated fluid flow rates converge with the measured fluid flow rates. Pressure data can be used to determine gridblock permeability, which in turn helps constrain the model, thus providing more reliable fracture properties. Uncertainty ranges of the fracture properties can also be calculated.

A system and method may model physical geological structures. Seismic and geologic data may be accepted. A three-dimensional (3D) transformation may be generated between a 3D present day model having points representing present locations of the physical geological structures and a 3D past depositional model having points representing locations where the physical geological structures were originally deposited. An indication may be accepted to locally change the 3D transformation for a subset of sampling points in a first model of the models. The 3D transformation may be locally changed to fit the updated subset of sampling points. A locally altered or updated version of the first model and, e.g., second model, may be displayed where local changes to the first model are defined by the locally changed 3D transformation. The transformation may also be used to extract geobodies in the past depositional model.

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

A method for modeling a dynamic system (e.g., geological system) comprises: constructing an input parameter space for a model of the geological system, the input parameter space including more than three dimensions, and the model associated with response data, representing the input parameter space visually with three or fewer dimensions, reducing the input parameter space by conditioning the parameter space using at least a subset of the response data, and updating the representation of the input parameter space to visually represent the reduction of the parameter space.

The present invention relates generally to methods for designing and optimizing the number, placement, and size of fractures in a subterranean formation and more particularly to methods that account for stress interference from other fractures when designing and optimizing the number, placement, and size of fractures in the subterranean formation. The present invention optimizes the number, placement and size of fractures in a subterranean formation. The present invention determinines one or more geomechanical stresses induced by each fracture based on the dimensions and location of each fracture. The present invention determinines a maximum number of fractures and a predicted stress field based on the geomechanical stresses induced by each of the fractures

A method for modeling deformation in subsurface strata, including defining physical boundaries for a geomechanical system. The method also includes acquiring one or more mechanical properties of the subsurface strata within the physical boundaries, and acquiring one or more thermal properties of the subsurface strata within the physical boundaries. The method also includes creating a computer-implemented finite element analysis program representing the geomechanical system and defining a plurality of nodes representing points in space, with each node being populated with at least one of each of the mechanical properties and the thermal properties. The program solves for in situ stress at selected nodes within the mesh.

Systems and methods of performing oilfield operations for an oilfield are provided. The oilfield has a subterranean formation with geological structures and reservoirs therein. A plurality of oilfield modules are positioned in an application. Each of the oilfield modules models at least a portion or attribute of the oilfield. The oilfield modules are selectively connected via a connection. The connections may be integrated connections providing cooperation for integrated modeling therebetween and/or dynamic connections providing knowledge sharing for unified modeling therebetween whereby at least one oilfield model is generated. At least one internal database may be positioned in the application for collecting oilfield data and operatively connected to the of oilfield modules. At least one oilfield model is generated using the oilfield data and the oilfield modules.

Systems and methods for updating posterior geological models by integrating various reservoir data to support dynamic-quantitative data-inversion, stochastic-uncertainty-management and smart reservoir-management.

A method for computing or estimating fractional, multi-phase/multi-component flow through a porous medium employing a 3D digital representation of a porous medium and a computational fluid dynamics method to calculate flow rates, pressures, saturations, internal velocity vectors and other flow parameters is described. The method employs a unique method of introducing non-wetting and wetting fluids into the pores at the inlet face of the 3D digital representation of a porous medium and a novel process control application to achieve quasi-steady state flow at low inlet concentrations of non-wetting fluid. In addition, the method of the present invention reduces the time required to simulate to complete the fluid dynamic calculations. The resulting values of flow of non-wetting fluid, wetting fluid, saturation, and other parameters are used to generate plots of relative permeability imbibition and drainage curves. Computerized systems and programs for performing the method are also provided.