Abstract: A technique facilitates selection of optimum flow control valve settings to improve a desired objective function in a multizone well having zonal isolation. A network of flow control valves is provided in a completion network disposed along isolated well zones of at least one lateral bore of the multizone well. Data is acquired from downhole in the multizone well and processed on processor system modules which may be used in selected combinations. Examples of such modules comprise completion network modules, deconvolution modules, optimization modules, and/or inflow-outflow modules. The modules are designed to process the collected data in a manner which facilitates adjustment of the flow control valve settings in the network of flow control valves to improve the desired objective function.

Abstract: A technique facilitates selection of optimum flow control valve settings to improve a desired objective function in a multizone well having zonal isolation. A network of flow control valves is provided in a completion network disposed along isolated well zones of at least one lateral bore of the multizone well. Data is acquired from downhole in the multizone well and processed on processor system modules which may be used in selected combinations. Examples of such modules comprise completion network modules, deconvolution modules, optimization modules, and/or inflow-outflow modules. The modules are designed to process the collected data in a manner which facilitates adjustment of the flow control valve settings in the network of flow control valves to improve the desired objective function.

Abstract: A system for automatically optimizing a Field Development Plan (FDP) for an oil or gas field uses a fast analytic reservoir simulator to dynamically model oil or gas production from the entire reservoir over time in an accurate and rapid manner. An objective function defining a Figure of Merit (FoM) for candidate FDPs is maximized, using an optimization algorithm, to determine an optimized FDP in light of physical, engineering, operational, legal and engineering constraints. The objective function for the Figure of Merit, e.g., net present value (NPV) or total production for a given period of time, relies on a production forecast from the fast analytic reservoir simulator for the entire FDP.

Abstract: A method, apparatus and program product utilize an analytical reservoir simulator to perform inflow simulation for a node during nodal analysis in a multi-well petroleum production system. By doing so, time-lapse nodal analysis may be performed of a transient production system in a multi-well context, often taking into account production history and the transient behavior of a reservoir system. Moreover, in some instances, an interference effect from different wells in a multi-well production system may be considered, and in some instances nodal analysis may be performed simultaneously for multiple wells. Multi-layer nodal analysis may also be performed in some instances to account for the pressure loss in a wellbore between multiple layers.

Abstract: A method of upscaling for reservoir simulation is disclosed, comprising: inverting a set of deep reading measurements constrained by upscaled multi-well data, and, in response to the inverting step, upscaling for reservoir simulation.

Abstract: A method is disclosed for building a predictive or forward model adapted for predicting the future evolution of a reservoir, comprising: integrating together a plurality of measurements thereby generating an integrated set of deep reading measurements, the integrated set of deep reading measurements being sufficiently deep to be able to probe the reservoir and being self-sufficient in order to enable the building of a reservoir model and its associated parameters; generating a reservoir model and associated parameters in response to the set of deep reading measurements; and receiving, by a reservoir simulator, the reservoir model and, responsive thereto, generating, by the reservoir simulator, the predictive or forward model.

Abstract: A system and method for controlling an advancing water front in a reservoir toward a wellbore is provided. The system has a production control unit. The production control unit has a reservoir unit for producing a reservoir model and a production path unit for producing a production path model that determines at least one pressure parameter about the wellbore during a life of the wellbore. The production control unit has a production optimizer unit for producing a well plan that optimizes a function of the wellsite. The production control unit may be for controlling an advancing fluid front in the reservoir with at least one control device, and wherein a production path is constructed based on the well plan.

Abstract: A system and method for performing an adaptive drilling operation is provided. The method involves obtaining data prior to drilling, constructing a base model with a base model unit from data obtained prior to drilling, constructing an overburden posterior model with an overburden model unit using the base model and data obtained from overburden drilling, constructing a reservoir posterior model with a reservoir model unit using the overburden posterior model and the data obtained from reservoir drilling and updating drilling operation based on the models.

Abstract: A method of upscaling for reservoir simulation is disclosed, comprising: inverting a set of deep reading measurements constrained by upscaled multi-well data, and, in response to the inverting step, upscaling for reservoir simulation.

Abstract: The invention relates to a method of performing an oilfield operation of an oilfield having at least one wellsite, each wellsite having a wellbore penetrating a subterranean formation for extracting fluid from an underground reservoir therein. The method steps include obtaining a plurality of real-time parameters from a plurality of sensors disposed about the oilfield, wherein the plurality of real-time parameters comprise at least one selected from a group consisting of real-time flow rate data and real-time pressure data of the wellbore, configuring a gridless analytical simulator for simulating the underground reservoir based on the plurality of real-time parameters, generating real-time simulation results of the underground reservoir and the at least one wellsite in real-time using the gridless analytical simulator, and performing the oilfield operation based on the real-time simulation results.

Abstract: A method, apparatus and program product utilize an analytical reservoir simulator to perform inflow simulation for a node during nodal analysis in a multi-well petroleum production system. By doing so, time-lapse nodal analysis may be performed of a transient production system in a multi-well context, often taking into account production history and the transient behavior of a reservoir system. Moreover, in some instances, an interference effect from different wells in a multi-well production system may be considered, and in some instances nodal analysis may be performed simultaneously for multiple wells. Multi-layer nodal analysis may also be performed in some instances to account for the pressure loss in a wellbore between multiple layers.

Abstract: A Gas Reservoir Evaluation and Assessment Tool utilizes an Analytical Engine to produce predictions of pressure values and other production data at any point in space and at any point in time in a reservoir. A computer system, such as a workstation, stores a Gas Reservoir Evaluation and Assessment software which includes the Analytical Engine and responds to input data (which includes a reservoir description and fluid properties) by generating an output record which represents a prediction of the pressure values and other data at ‘any point in space’ and at ‘any point in time’ in a reservoir.

Abstract: A reservoir pressure in an underground formation surrounding a well is analyzed based on a direct measurement of the pressure at the wall of the well using the permeability of mud cake on the wall of the well in the region in which the pressure measurement is made; determining the thickness of mud cake on the well of the well; determining the hydrostatic pressure in the well in the region in which the pressure measurement is made; calculating a pressure decay index from the mud cake permeability and thickness, the hydrostatic pressure and the measured pressure; and using the pressure decay index to analyze the measured pressure to derive the reservoir pressure.

Abstract: A method of upscaling for reservoir simulation is disclosed, comprising: inverting a set of deep reading measurements constrained by upscaled multi-well data, and, in response to the inverting step, upscaling for reservoir simulation.

Abstract: A system and method for controlling an advancing water front in a reservoir toward a wellbore is provided. The system has a production control unit. The production control unit has a reservoir unit for producing a reservoir model and a production path unit for producing a production path model that determines at least one pressure parameter about the wellbore during a life of the wellbore. The production control unit has a production optimizer unit for producing a well plan that optimizes a function of the wellsite. The production control unit may be for controlling an advancing fluid front in the reservoir with at least one control device, and wherein a production path is constructed based on the well plan.

Abstract: A method is disclosed for modeling a first reservoir while drilling a wellbore into a corresponding second reservoir, the first reservoir having a plurality of stations, comprising: determining a plurality of values of net present value corresponding, respectively, to the plurality of stations of the first reservoir; and drilling the wellbore into the corresponding second reservoir in accordance with the plurality of values of net present value.

Abstract: A technique includes receiving, during a hydraulic fracturing operation in a subterranean structure, pressure data and fluid injection rate data. One or more properties of the subterranean structure are determined in real-time using the received pressure data and fluid injection rate data.

Abstract: A system for automatically optimizing a Field Development Plan (FDP) for an oil or gas field uses a fast analytic reservoir simulator to dynamically model oil or gas production from the entire reservoir over time in an accurate and rapid manner. An objective function defining a Figure of Merit (FoM) for candidate FDPs is maximized, using an optimization algorithm, to determine an optimized FDP in light of physical, engineering, operational, legal and engineering constraints. The objective function for the Figure of Merit, e.g., net present value (NPV) or total production for a given period of time, relies on a production forecast from the fast analytic reservoir simulator for the entire FDP. The position, orientation and dimensions of analytical model elements for the subsurface oil or gas field, as well as the physical properties associated with these elements, correlate to connected flow volume data from a Shared Earth Model (SEM). Uncertainty in the SEM is considered via stochastic sampling.

Abstract: A system and method for performing an adaptive drilling operation is provided. The method involves obtaining data prior to drilling, constructing a base model with a base model unit from data obtained prior to drilling, constructing an overburden posterior model with an overburden model unit using the base model and data obtained from overburden drilling, constructing a reservoir posterior model with a reservoir model unit using the overburden posterior model and the data obtained from reservoir drilling and updating drilling operation based on the models.

Abstract: A method for performing an oilfield operation on a reservoir, including: obtaining a user objective identifying the oilfield operation; obtaining a set of input data; selecting a workflow in response to the user objective, where the workflow comprises a build model module and a tune model module; generating a 1D model of the reservoir using the build module, where the 1D model includes multiple per unit of depth properties; generating a 3D model of the reservoir by distributing the plurality of per unit of depth properties in 3D; calibrating the 3D model using the tune model module, modular dynamic tester transient test data, and a historical response of the reservoir; forecasting a response of the reservoir to the set of input data by applying the first set of input data to the 3D model; and using the response to perform the oilfield operation.