Corning Incorporated

Landmark Graphics Corporation

Halliburton Energy Services, Inc.

Corning Cable Systems

Corning Optical Communications LLC

Andrey V Filippov

Vitaly Khoriakov

Jianxin Lu

Bruce Warren Reding

David Andrew Tucker

Pushkar Tandon

Carlton Maurice Truesdale

Liming Wang

Bulent Kocatulum

Calvin Thomas Coffey

Bradley Kent Shepard

James Henry Faler

Kathleen Elizabeth Morse

Clinton Damon Osterhout

Martin Andrew Sala

Warren Welborn McAlpine

Daniel Warren Hawtof

Steven Bruce Dawes

Rodney Maurice Burns

Robert Clark Moore

Catharina Lemckert Tedder

Chunhong Chelsie He

John Joseph Costello, Iii

Charlotte Diane Milia

Vitaly Anatolievich Khoriakov

Catharina L Tedder

Warren W Mcalpine

Dana Craig Bookbinder

Ming-Jun Li

Harold Grayson Walters

Srinath Madasu

Allan Mark Fredholm

Douglas Clippinger Allan

Mohamed Yousef Soliman

Richard Michael Fiacco

Kevin Wallace Bennett

Keshava Prasad Rangarajan

Ji Wang

John Christopher Thomas

Curtis Robert Fekety

Lewis Kirk Klingensmith

Olus Naili Boratav

Steven Joseph Gregorski

Randy Lee Rhoads

Riley Saunders Freeland

Hazel Benton Matthews, Iii

Douglas Hull Jennings

Valery A Kozlov

Yevgeniy Zagayevskiy

Avinash Wesley

Peter Joseph Ronco

Roger A Rose

Egidio Marotta

Pandurang Manohar Kulkarni

Riley S Freeland

Terry Jay Ott

Cesar Bravo

Leonard R Kent

Xinli Jia

Chunhong (Chelsie) C He

Feifei Zhang

Sergio Henrique Guerra De Sousa

Dale McMullin

Florentina Popa

Calvin T Coffey

Hazel B Iii Matthews

Steven J Gregorski

John J Iii Costello

Brent Charles Houchens

Hazel B Matthews

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

System and methods for training neural network models for real-time flow simulations are provided. Input data is acquired. The input data includes values for a plurality of input parameters associated with a multiphase fluid flow. The multiphase fluid flow is simulated using a complex fluid dynamics (CFD) model, based on the acquired input data. The CFD model represents a three-dimensional (3D) domain for the simulation. An area of interest is selected within the 3D domain represented by the CFD model. A two-dimensional (2D) mesh of the selected area of interest is generated. The 2D mesh represents results of the simulation for the selected area of interest. A neural network is then trained based on the simulation results represented by the generated 2D mesh.

Effective representation of complex three-dimensional simulation results for real-time operations

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

A system includes a processor. The processor estimates a pattern of a flow of a mixture of drilling fluid and cuttings in an annulus of a wellbore. The flow is estimated as a stationary bed flow, a dispersed flow, or a transitional flow relative to the stationary bed and dispersed flows. The processor estimates parameters based on the estimated pattern of the flow, and determines a plurality of dimensionless parameters including a first dimensionless parameter corresponding to an effect of turbulence on the flow and a second dimensionless parameter corresponding to an effect of gravity on the flow, based on the estimated parameters. The processor characterizes the pattern of the flow as the stationary bed flow, the dispersed flow, or the transitional flow, based on the dimensionless parameters, and models the flow based on the estimated pattern if it is determined that the characterized pattern matches the estimated pattern.

Method and device for hole cleaning and drilling hydraulic design

An estimated gas leak flow rate can be determined using a teaching set of concentration profiles, a regression model implemented by a machine-learning subsystem, and a subset of attributes measured within an environment. The teaching set of concentration profiles can include gas flow rates associated with relevant attributes. The regression model can be transformed into a gas leak flow regression model via the machine-learning subsystem using the teaching set. The subset of attributes measured within the environment can be applied to the gas leak flow regression model to determine other attributes absent from the subset of attributes and an estimated gas flow rate for the environment. A gas leak attenuation action can be performed in response to the estimated gas flow rate.

Determining gas leak flow rate in a wellbore environment

A self-adapting digital twin of a wellbore environment can be created. The self-adapting digital twin incorporates a standalone Ensemble Kalman Filter (EnKF) module with a constant parameter digital twin developed for a fixed environment. The standalone EnKF module receives streaming measurement data from multiple sensors and prediction data from the digital twin and executes the standalone EnKF module using the streaming measurement data and the prediction data from the digital twin. The results of executing the standalone EnKF module are input parameter corrections for the digital twin that are communicated to the digital twin. Output predictions of the digital twin are used to modify operational parameters of an oil or gas recovery process.

Constructing digital twins for oil and gas recovery using Ensemble Kalman Filter

System and methods for controlling suspended particle redistribution during stimulation treatments. Fluid flow in a wellbore is simulated for a stimulation treatment to be performed along a section of the wellbore within a subterranean formation, based on a flow model associated with the wellbore. Based on the simulation, dimensionless parameters characterizing a flow of suspended particles within a treatment fluid to a fractured area of the formation via at least one perforation along the section of the wellbore are calculated. A collection efficiency of the suspended particles within the fluid is determined, based on the dimensionless parameters. The collection efficiency is used to calculate a flow rate of the suspended particles to the fractured area of the formation via the perforation. The flow rate is used to estimate an amount of the suspended particles to be injected into the wellbore during the stimulation treatment along the wellbore section.

Controlling redistribution of suspended particles in non-Newtonian fluids during stimulation treatments

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

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Painted Post, NY, United States of America

Andrey V Filippov