Landmark Graphics Corporation

Halliburton Energy Services, Inc.

Vitaly Khoriakov

Andrey V Filippov

Jianxin Lu

Mohamed Yousef Soliman

Marko Maucec

Gustavo Carvajal

Yevgeniy Zagayevskiy

Egidio Marotta

Steven Patton Knabe

Xinli Jia

Andrey Flippov

Arturo Diaz

Dale McMullin

Andrey Filippov

Mohamed Y Soliman

Andrey Filppov

A system and method can be used for implementing self-adapting digital twins. The system may include operations for estimate a state matrix characterizing behavior of a hydrocarbon recovery process implemented by a hydrocarbon recovery tool. Observed values of one or more sensors for at least one process parameter may be obtained from sensors deployed throughout the drilling environment. These sensors may be physical sensors acquiring information about physical changes within the drilling environment; and processes monitoring output of system functions and/or other processes. A data assimilation tool may be applied to the estimated state matrix and the observed values to produce an updated state matrix. The updated state matrix may be used as the previous state matrix in a subsequent time step, thus implementing a self-adapting digital twin model.

Self-adapting digital twins

The disclosed embodiments include a method, apparatus, and computer program product for improving production of an oil well. For example, one disclosed embodiment includes a system that includes at least one processor and at least one memory coupled to the at least one processor and storing instructions that when executed by the at least one processor performs operations for generating a model of a wellbore in a wellbore simulator. The at least one processor further executes an algorithm that determines optimal parameters for inflow control devices (ICD) along a horizontal portion of the wellbore. The determined optimal parameters of the inflow control devices would yield a substantially uniform approach of at least one of water and gas along the horizontal portion of the wellbore.

Algorithm for optimal ICD configuration using a coupled wellbore-reservoir model

A method for identifying a flow parameter in a wellbore may comprise identifying a state vector at a moment t, performing a flow simulation using a flow model, predicting the state vector and a covariance matrix at the moment t, updating the state vector with an EnKF algorithm, correcting the state vector at the moment t, and updating the flow simulation model. A system for identifying a flow parameter in a wellbore may comprise a distributed acoustic system into a wellbore and an information handling system. The distributed acoustic system may comprise a fiber optic cable and at least one measurement device.

Application of the ensemble Kalman filter to dynamic history matching in wellbore production

Methods and systems are presented in this disclosure for performing fast economic analysis of production by fracture-stimulated wells. A class of models can be defined by combining a simulated fracture geometry comprising a stimulated reservoir volume with accounting for fluid dynamics and phase transitions in the stimulated reservoir volume for modeling production in a plurality of reservoirs. An objective function related to the production in the plurality of reservoirs can be generated based on at least one model from the class of models. Parameters related to fracture stages of a fracture network can be then determined, based on the objective function, and communicated, via a computer network to a computing device, to be used for at least one of building or operating the fracture network in the reservoir.

Method and apparatus for fast economic analysis of production of fracture-stimulated wells

A method to reduce fluid production in a well includes performing a production simulation of a reservoir model comprising a production tool with an inflow control device, and determining a parameter for the inflow control device to reduce fluid production through the inflow control device based upon the production simulation.

System and method to reduce fluid production from a well

The disclosed embodiments include a method, apparatus, and computer program product for determining optimal flow control device (FCD) properties that would yield to a prescribed shape of the injection flow rate profile. For example, in one embodiment, a computer implemented method is configured to perform the steps of: determining a reference location along a production length of the injection well; determining a reference value equal to the injection flow rate profile at the reference location along the production length of the injection well; defining a target injection profile using the reference value; determining a pressure distribution along the production length of the injection well based on the target injection profile; determining a FCD distribution profile using the target injection profile and the pressure distribution; and determining FCD properties that yields the target injection profile based on the FCD distribution profile.

Optimizing flow control device properties for a liquid injection well using a coupled wellbore-reservoir model

The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for method for determining flow control device (FCD) properties for both an injection well and a production well in coupled injector-producer liquid flooding systems that yields uniform flooding along the production well.

Optimizing flow control device properties on both producer and injector wells in coupled injector-producer liquid flooding systems

The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device (FCD) properties for an injection well that yields uniform flooding along the production well.

Optimizing flow control device properties on injector wells in liquid flooding systems

The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for method for determining flow control device (FCD) properties for a production well in coupled injector-producer liquid flooding systems that yields a uniform flooding front along the production well.

Optimizing flow control device properties on a producer well in coupled injector-producer liquid flooding systems

The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device properties for an injection well that would yield to a prescribed uniform or non-uniform accumulated injection profile along a production well.

Optimizing flow control device properties for accumulated liquid injection

Systems and methods for determining an optimal acid placement design for a production well near an aquifer are provided. An optimal acid placement that is determined accounts for the drawdown from heel to toe of the production well and reservoir heterogeneity to thereby address the issue of water breakthrough from the nearby aquifer and improve hydrocarbon recovery.

Optimized acidizing of a production well near aquifer

A computer implemented method, system, and computer program product are provided for determining flow control device (FCD) properties for a gas injection well that would yield a prescribed shape of a gas injection front according to a target gas injection profile. An FCD distribution function is adjusted based on the results of a simulation of injected gas flow distribution in the gas injection well over a period of time. The simulation and resulting adjustment of the FCD distribution function is repeated until a convergence between a shape of a displaced oil volume front obtained using the adjusted flow control device distribution function and a target gas injection profile is reached within a predetermined convergence range. The FCD properties are then determined based on the adjusted FCD distribution function.

Optimized flow control device properties for accumulated gas injection

In some embodiments, a simulation apparatus may comprise a processor and a memory to store a set of instructions, which when executed by the processor, forms a machine programmed to generate an analytical solution to simulate multiple scenarios for a total fluid flow rate in order to find one of the scenarios that meets a desired total flow rate for a fluid flow entering a portion of a screen to pass through one or more orifices in a base conduit covered by the screen. Additional apparatus, systems, and methods are described.

Inflow control apparatus, methods, and systems

Systems and methods for estimating well production performance in fractured reservoir systems using real-time down-hole temperature and stress information from advanced monitoring techniques.

Growing community of inventors

Calgary, Canada

Vitaly Khoriakov