Wei Ren1012 Woodfield Dr, Schenectady, NY 12309

8392031, Mar 5, 2013

Feb 28, 2011

13/036828

Michael Joseph Krok - Clifton Park NY, US
Yan Pan - Niskayuna NY, US
Wei Ren - Niskayuna NY, US

General Electric Company - Niskayuna NY

G05D 3/12
G05D 5/00
G05D 9/00
G05D 11/00
G05D 17/00
G06Q 10/00
G06Q 30/00

700291, 700286, 700295, 705 729, 705 731

A method of load forecasting for a present day includes obtaining past observed load values of at least three earlier days and identifying a relationship between the present day's load forecast and the past observed load values including unknown weights associated with the past observed load values. The values of unknown weights are determined by comparing at least one previous day's load forecast with the observed load value of the at least one previous day. The determined weight values are then used in the relationship between the present day's load forecast and the past observed load values to forecast the present day's load.

8648499, Feb 11, 2014

Jan 27, 2011

13/014779

Michael Joseph Krok - Niskayuna NY, US
Wei Ren - Niskayuna NY, US

General Electric Company - Niskayuna NY

H02J 1/00

307103

Certain embodiments of the invention may include systems and methods for accelerating volt/VAR load flow optimization. According to an example embodiment of the invention, a method is provided for accelerating load flow for integrated volt/var control (IVVC) optimization. The method can include evaluating load flow on lines of an electrical network, identifying combinable network lines, combining the identified combinable network nodes to reduce network complexity, and determining load flow optimization for IVVC based at least in part on the reduced complexity network.

2012013, May 31, 2012

Nov 30, 2010

12/956124

Kathleen Ann O'Brien - Niskayuna NY, US
Wei Ren - Niskayuna NY, US

GENERAL ELECTRIC COMPANY - Schenectady NY

H02J 4/00

307 72

A distribution management system (DMS) includes an integrated volt/var controller (IVVC) that is configured to control operation of at least one corresponding renewable energy source or energy storage device power converter in response to IVVC commands generated via algorithmic optimization software integrated within the IVVC. At least one renewable energy source or energy storage device is controlled to operate alone or in coordination with one or more discrete step size reactive power (VAR) compensation devices to generate continuously varying reactive power required by a corresponding power distribution system.

2012019, Aug 2, 2012

May 3, 2011

13/100015

Michael Joseph Krok - Niskayuna NY, US
Wei Ren - Niskayuna NY, US
Sahika Genc - Niskayuna NY, US

GENERAL ELECTRIC COMPANY - Schenectady NY

H02J 4/00

307 31

Certain embodiments of the invention may include systems, methods, and apparatus for controlling voltage and reactive power in a distribution network. One method includes estimating at least one present state associated with a distribution network; allocating one or more load zones in the distribution network; predicting load profiles of each zone for a predetermined time period; determining capacitor bank switching schedules for a predetermined time period based at least in part on the at least one present state and the predicted load profiles; and switching capacitor banks according to the capacitor bank switching schedules.

2012019, Aug 2, 2012

Apr 27, 2011

13/095263

Michael Joseph Krok - Niskayuna NY, US
Wei Ren - Niskayuna NY, US
Sahika Genc - Niskayuna NY, US

General Electric Company - Schenectady NY

G05F 5/00

700291

Certain embodiments of the invention may include systems, methods, and apparatus for providing coordinated volt/volt-amps-reactive (VAR) control in power distribution networks. According to an example embodiment of the invention, a method is provided for coordinating voltage and volt-amps-reactive (VAR) control (VVC) in power distribution networks. The method can include receiving one or more VVC objective functions from a distribution management system (DMS); determining at least one microgrid conservation voltage reduction factor (CVRF); forecasting microgrid load profile for a predetermined period of time; controlling microgrid VVC resources based at least on the one or more received VVC objective functions; and communicating the at least one microgrid CVRF and the forecasted load profile to the DMS.

2013010, May 2, 2013

Oct 31, 2011

13/285886

Yan Pan - Niskayna NY, US
Wei Ren - Niskayuna NY, US
Swakshar Ray - Guilderland NY, US
Michael Reichard - Schenectady NY, US
Amol Rajaram Kolwalkar - Bangalore, IN
Reigh Allen Walling - Clifton Park NY, US

H02H 3/00

361 87

An electric distribution system includes at least one feeder and a protection and control system. The feeder includes at least one segment including a first end and an opposing second end. The protection and control system includes a protective device and an electric current measuring device coupled to the segment proximate each end. The system further includes at least one processor coupled in communication with the electric current measuring devices. The at least one processor is programmed to determine a difference between a synchronized first electric current measured proximate the first end and a synchronized second electric current measured proximate the opposing second end and determine a switching condition of the protective devices as a function of the difference between the synchronized first and second electric currents.

2013013, May 30, 2013

Nov 30, 2011

13/307740

Pan Yan - Niskayuna NY, US
Reigh Allen Walling - Clifton Park NY, US
Amol Rajaram Kolwalkar - Bangalore, IN
Michael Lewis Reichard - Schenectady NY, US
Wei Ren - Niskayuna NY, US
Swakshar Ray - Guilderland NY, US

G01R 19/00
G01R 31/00

702 58

A system for distributing electrical current to a plurality of loads includes a first sensor coupled to an input of a protection zone for measuring a first current entering the protection zone, wherein the protection zone includes at least a portion of an electrical distribution feeder. The system also includes a second sensor coupled to an output of the protection zone for measuring a second current exiting the protection zone, and a processor coupled to the first sensor and to the second sensor. The processor is programmed to receive measurements representative of the first current and the second current, and calculate a reactive current differential of the protection zone based on the first current and the second current. The processor is also programmed to compare the reactive current differential with a fault threshold, and generate an error notification if the reactive current differential is greater than the fault threshold.

2013016, Jun 27, 2013

Dec 22, 2011

13/334383

Wei Ren - Niskayuna NY, US
Robert William Delmerico - Clifton Park NY, US
Kathleen Ann O'Brien - Niskayuna NY, US
Yan Pan - Niskayuna NY, US

General Electric Company - Schenectady NY

G06F 19/00
H02M 7/44

700297

A power delivery system includes at least one conductor having a first end and a second end and a phasor measurement unit (PMU) coupled to the first end of the conductor. The PMU is configured to obtain phasor data at the first end and generate a phasor signal that includes the phasor data. The power delivery system also includes a power generation system coupled to the second end of the conductor and configured to provide power to the conductor. The power generation system includes a power source, a power converter, and a controller. The controller is communicatively coupled to the PMU and is configured to receive the phasor signal and control the power converter based at least partially on the phasor data.