General Electric Company

General Electric Technology Gmbh

Savant Technologies LLC

Naresh Acharya

Chaitanya Ashok Baone

Nilanjan Ray Chaudhuri

Kathleen Ann O'Brien

Yan Pan

Reza Ghaemi

Jovan Z Bebic

Harjeet Johal

Herman Wiegman

Masoud Abbaszadeh

Deepak Aravind

Alfredo Sebastian Achilles

Sreedhar Desabhatla

Ara Panosyan

Sahika Genc

Scott William Szepek

Luca Parolini

Xinhui Wu

Miaolei Shao

Adolfo Anta Martinez

Krishna Kumar Anaparthi

Khaled Yehia Bahei-Eldin

Xing Wang

Yingying Wang

Viswanath Kunapuli

John Douglas McDonald

Hongbiao Song

Paul Joseph Datka

Johal Harjeet

Herman Lucas Norbert Wiegman

The example embodiments are directed to a system and method for forecasting load flexibility of a power grid. In one example, the method includes receiving temperature values associated with temperature set points of a plurality of loads that are included on a power grid, forecasting a flexibility of the plurality of loads using a polynomial-time mixed-integer non-linear programming (MINLP) optimization based on the received temperature values for the plurality of loads, and outputting information about the forecasted flexibility for display to a display device. The MINLP optimization performs the forecasting of the load flexibility on a fine-grained basis in comparison to conventional methods and is still fast enough that it can be computed in real-time.

Power system load flexibility forecasting

Systems and methods for improved anomaly detection for rotating machines. An example method may include determining that power generation is to be performed based on a voltage instead of a power factor; receiving a command voltage; receiving a measured voltage value from a first location in a power generation network; determining that the measured voltage value from the first location is less than the command voltage value; determining that a current value associated with a transmission line at the third location is less than a threshold current value; determining that a reactive power of a power generation component at a third location is less than a maximum reactive power of the component; and increasing, based on the determination that the reactive power of the component at the third location is less than a maximum reactive power of the component, the reactive power of the component.

Dynamic voltage and reactive power controller for non-synchronous power generation plants

An electric power system includes a generating unit, which includes a controller for controlling an operational mode of the generating unit. The electric power system also includes an event estimator communicatively coupled to the controller of the generating unit and a network estimator communicatively coupled to the event estimator. The network estimator includes a processor configured to receive status information associated with the electric power system, determine, based upon the status information, at least one characteristic of the electric power system, and transmit the at least one characteristic to the event estimator.

Systems and methods for high rate-of-change-of-frequency ride-through in electric power systems

An optimization-based method and system is disclosed to enable heterogeneous loads and distributed energy resources (DERs) to participate in grid ancillary services, such as spinning and non-spinning reserves, and ramping reserves. The method includes receiving inputs for decision parameters for optimizing an objective for obtaining flexible reserve power, solving the objective for obtaining flexible reserve power, determining a reserve power schedule for a prediction horizon for providing flexible reserve power based on the objective, generating a service bid based on the reserve power schedule for the power grid; and when the service bid is accepted, providing flexible reserve power to the power grid based on the service bid.

Method and system for providing flexible reserve power for power grid

The technology described herein is generally directed towards a distributed optimization technology for the control of aggregation of distributed flexibility resource nodes that operates iteratively until a commanded power profile is produced by aggregated loads. The technology uses a distributed iterative solution in which each node solves a local optimization problem with local constraints and states, while using a global Lagrange multiplier that is based upon information from each other node. The global Lagrange multiplier is determined at an aggregation level using load-specific information that is obtained in a condensed form (e.g., a scalar) from each node at each iteration. The global Lagrange multiplier is broadcasted to the nodes for each new iteration. The technology provides an iterative, distributed solution to the network optimization problem of power tracking of aggregated loads.

Scalable flexibility control of distributed loads in a power grid

A microgrid system includes one or more power generators configured to provide electrical energy. The microgrid system also includes a localized distribution network coupled to the one or more power generators, coupled to the one or more loads, and coupled to an external grid. The microgrid system further includes a microgrid controller configured to predict microgrid demand for the one or more loads for a predetermined period of time. The microgrid controller is also configured to receive demand information for the external grid for the predetermined period of time. The microgrid controller is further configured to determine an operation plan for the one or more power generators based on the predicted microgrid demand and the received demand information. Moreover, the microgrid controller is configured to determine a schedule to transmit electrical energy to the external grid based on the operation plan.

Systems and methods for regulating a microgrid

The embodiments described herein provide for a system including a processor. The processor is configured to select at least one grid system contingency from a plurality of grid system contingencies. The processor is further configured to derive one or more eigen-sensitivity values based on the at least on grid system contingency. The processor is also configured to derive one or more control actions at least partially based on the eigen-sensitivity values. The processor is additionally configured to apply the one or more control actions for generation re-dispatch of a grid system.

Systems and methods for improved stability of power systems

A computer-based method for contingency analysis of oscillatory stability in an electrical power transmission system is provided. The method uses at least one processor. The method includes receiving, by the at least one processor, a plurality of component inputs from a plurality of system components within the electrical power transmission system. The method also includes generating a nominal matrix for the electrical power transmission system. The nominal matrix includes a set of equations at least partially modeling the electrical power transmission system. The method further includes calculating eigenvalues and eigenvectors of the nominal matrix. The method also includes identifying a contingency representing a postulated disturbance of the electrical power transmission system. The method further includes estimating a contingency eigenvalue for the contingency using the eigenvalues and eigenvectors of the nominal matrix.

System and method for analyzing oscillatory stability in electrical power transmission systems

An electrical power system includes an electrical power distribution network and a control device configured to regulate at least one attribute of said electrical power system. The electrical power system further includes a processor coupled to the control device configured to identify an out-of-bound condition on said electrical power distribution network at a first time. The out-of-bound condition is associated with the at least one attribute. The processor is also configured to determine a trend for the at least one attribute at a second time that is later than the first time after a predetermined delay time elapses. The trend indicates a direction away from at least one of a predetermined range and a predetermined value. The processor is also configured to transmit a control action to said control device based at least in part on the trend.

System and method for controlling a power distribution network

A stability analysis system (SAS) for non-invasive estimation of damping torque associated with a power generator in an electric power network includes a processor in communication with a PMU associated with the generator. The processor is configured to receive a first data sample set from the PMU. The first data set is substantially representative of at least one measurement of the generator. The processor is also configured to determine an estimated torque of the generator based at least in part on the first data set. The processor is further configured to determine an estimated average torque and one or more estimated torque components based at least in part on the estimated torque. The processor is also configured to output the estimated average torque and the one or more estimated torque components to an operator for use in stability analysis of one or more of the generator and the network.

System and method for non-invasive generator damping torque estimation

A system for accelerated assessment of operational uncertainties in an electrical power distribution system includes a plurality of utility assets, and a distribution analysis ('DA') system. DA system includes a preparation module configured to identify a first network model and a reduced network model for the electrical power distribution system. DA system also includes an input module configured to identify a plurality of scenarios, and a reduced-model-analysis module configured to analyze the reduced network model using the plurality of scenarios, generating a first set of results, and to select a subset of scenarios based on the first set of results. DA system further includes a full-model-analysis module configured to analyze the first network model using the subset of scenarios, generating a second set of results. DA system also includes a command module configured to dispatch configuration commands to utility assets based on the second set of results.

System and method for accelerated assessment of operational uncertainties in electrical power distribution systems

A method for regulating a power line voltage includes determining a slow voltage variation by filtering an actual voltage at terminals of the voltage regulation apparatus. A fast active power variation is determined by filtering a measured active power of the DG system; wherein a first frequency of the slow voltage variation is smaller than a second frequency of the fast active power variation. The voltage regulation apparatus settings are controlled based on the slow voltage variation and a reactive power output of the DG system is controlled based on fast active power variation.

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Niskayuna, NY, United States of America

Naresh Acharya