Abb Research Ltd.

Abb Schweiz Ag

Hitachi Energy Ltd

Hitachi Energy Switzerland Ag

Abb Power Grids Switzerland Ag

Mats Larsson

Petr Korba

Alexandre Oudalov

Marek Zima

Christian Rehtanz

Adrian Vasile Timbus

Cherry Yuen

Bertil Berggren

Reynaldo Nuqui

Dacfey Dzung

Stefan G Thorburn

Ernst Scholtz

Christian Frei

Mani Subramanian

Martin Naef

Peter Karl Steimer

Tord Bengtsson

Vaibhav Deepak Donde

Debrup Das

Carsten Franke

Joachim Bertsch

Srinivas Ponnaluri

Lidong Zhang

Andrew D Paice

Rudolf Wieser

Jose Taborda

John Eckerle

John Dennis Finney

Yan Zhang

Johan Lindberg

Vladimir Brandwajn

Valentin Bürgler

Gordon Lin

Priscilla Owen

Michael Geiger

John Finney

Jorge Naccarino

Vaibhav Donde

Reynaldo F Nuqui

Albert Leirbukt

John D Finney

Alexander Oudalov

Stefan Thorburn

A method for determining a converter Thevenin equivalent model for a converter system, includes: receiving measurement values of a coupling point voltage and a coupling point current measured at a point of common coupling between a grid emulator system and the converter system, wherein the grid emulator system supplies the converter system with a supply voltage; and determining a converter Thevenin impedance and a converter Thevenin voltage source of the converter Thevenin equivalent model by inputting the measurement values of the coupling point voltage and of the coupling point current into a coupled system model, which includes equations modelling the converter system and the grid emulator system and from which the converter Thevenin impedance and a converter Thevenin voltage source are calculated.

Determining Thevenin equivalent model for a converter system

Methods for detecting network model data errors are disclosed. In some examples, methods for detecting network model data errors may include splitting a network model into a first plurality of portions, executing an algorithm on each of the portions, identifying a portion for which the algorithm is determined to be non-converged, splitting the identified portion into a second plurality of portions, repeating the executing, identifying and splitting the identified portion until a resulting identified portion is smaller than a predefined threshold, and examining the resulting identified portion to identify plausible data errors therein. In some examples, examining the resulting identified portion to identify plausible data errors therein may include executing a modified algorithm, which may include an augmented measurement set, on the identified portion.

Detecting state estimation network model data errors

Exemplary methods and systems visualize or contour a power distribution system state by displaying to an operator output data values interpolated at output data locations from input data including distributed input data sensor locations in three dimensions and corresponding dynamically updated input data values. The method includes defining triangles in the volume, and determining, for each triangle, closest input data locations according to a closeness criteria. The method also includes projecting each triangle onto a visualization plane, and determining, for an output data location on the visualization plane at least one triangle, the projection of which includes the output data location. The method interpolates, for the output data location, the input data values of the closest input data locations of each of the at least one determined triangle to generate an output data value corresponding to the output data location.

Visualization of three-dimensional power distribution data

An exemplary Multi-Terminal High Voltage Direct Current (MTDC) system includes at least three terminals, where each terminal including a Voltage Source Converter (VSC) controlled by a VSC controller. A method for controlling the MTDC system includes providing a converter schedule including at least one of a desired power flow value and a DC voltage; determining, by a MTDC master controller, a present state of the MTDC system including a dynamic topology of the MTDC system; determining, by the MTDC master controller, based on the present state of the MTDC system, based on the schedule and based on MTDC system constraints, VSC controller parameters including droop settings for local control by the VSC controllers; and transmitting the VSC controller parameters to the VSC controllers.

Multi terminal HVDC control

A method, resonance handling device and computer program product are disclosed for handling resonances in a power transmission system. The resonance handling device can include a resonance frequency determining unit configured to obtain measurements from measurement devices in the power transmission system, apply the measurements in at least one state space model and determine modal resonance frequencies in the system based on the application of the system measurements in the state space model, and an activity determining unit configured to determine the modal activity of at least one of the resonance frequencies.

Handling resonances in a power transmission system

Converter stations have real and reactive power set points initially determined as part of a main loadflow analysis routinely performed on the AC power system connected to the converter stations. Viable real and/or reactive power set points for the converter stations can be identified by calculating real and/or reactive power set point candidates for the converter stations before the main loadflow analysis is performed again on the AC power system. The power set point candidates are calculated based on information determined as part of a previous iteration of the main loadflow analysis on the AC power system. The power set point candidates which violate an operating constraint imposed on the AC power system are identified, and a region of valid power set points is defined for the converter stations that excludes the power set point candidates which violate an operating constraint imposed on the AC power system.

Converter station power set point analysis system and method

A method and system are provided for visualizing and displaying a state of a power transmission network to an operator, for the supervision of the network. The method and system are provided for visualizing or contouring a power transmission network state by displaying to an operator output data values interpolated at output data locations from input data including geographically distributed input data sensor locations and corresponding dynamically updated input data values. The method includes dividing a geographical area of interest into triangles, wherein a triangle vertex is defined at each input data location within the area, determining, for each triangle, closest input data locations according to a closeness criteria, and interpolating by weighting or scaling at each output data location within a triangle the input data values of a number of closest input data locations to generate output data values corresponding to the output data locations.

Power transmission network state visualization

A method is provided for detecting islanding conditions in an electric power network which includes a plurality of sub-networks. The sub-networks include at least one power electrical unit and are separable from each other and a main grid supplying the network by switching devices. The method includes determining topological information of at least one sub-network of interest, detecting islanding conditions in at least one sub-network of interest on the basis of the topological information by using separate detecting devices for each sub-network of interest, and sending, on the basis of the islanding conditions detected by using the detecting devices, a disconnect signal to at least one power electrical unit in at least one sub-network of interest.

Detecting islanding conditions in power networks

A method and system are provided for determining a length quantity of a power transmission line, which connects a first location with a second location. A first signal having a first carrier frequency is provided at the first location. The first signal is transmitted from the first location to the second location via the power transmission line. A second signal having a second frequency is provided at the second location. A first phase difference between the first signal and the second signal is measured at the second location, and the length quantity is calculated from the measured phase difference. In the system, a second receiver at the second location is configured to receive the first signal having the first carrier frequency from the first location. A frequency generator creates the second signal having the second frequency at the second location. The receiver includes a phase detection device configured to detect a first phase difference between the second frequency and the first carrier frequency at the second location.

Method and system for powerline length measurement

A system and method of controlling an electricity generating system that includes at least one intermittent energy source generating plant are disclosed. An exemplary method includes calculating actual operating parameters of the at least one intermittent energy source generating plant; calculating forecast operating parameters of the at least one intermittent energy source generating plant; generating intermittent energy source contingency definitions from such actual operating parameters and forecast operating parameters; analysing the intermittent energy source contingency definitions to provide contingency analyses; and controlling the electricity generating system in dependence upon such contingency analyses.

Energy generating system and control thereof

The present disclosure is concerned with controlling distributing of electrical power in a power distribution region. To effectively control the distribution of power in the distribution region, the substation of the region is provided with a distribution controller or Intelligent Substation Control System (ISCS). The distribution controller is connected to various process devices, which in turn are connected to primary devices of the region. The process devices send data corresponding to the primary devices to the distribution controller, and the distribution controller includes a processor which proposes a set of actions based on the received data. Further, the distribution controller includes a coordinating device which selects the final action from the set of proposed actions. The final action is implemented on the primary devices of the distribution region.

Controlling distribution of electrical power

A method and system are provided for controlling a distribution of electrical power in a power distribution network having a first power distribution region and a second power distribution region. The first power distribution region can include first primary devices that interact with first process devices, and the second power distribution region can include second primary devices that interact with second process devices a distribution controller including a standardized description of the first region. A first distribution controller can be connected to the first process devices, can control a distribution of electrical power in the first power distribution region, and can identify, following a network reconfiguration, an orphan network section that is disconnected from the first region and connected to the second region. The first distribution controller can transmit a standardized description of the identified orphan network section to a second distribution controller connected to the second process devices.

System and method for controlling a distribution of electrical power

The present disclosure relates to power system sensitivities as computed from power flow parameters and control parameters of a Power Flow Control Device (PFC). To this end, control parameter variations are applied to or generated by a PFC, and comprise variations in a control input u, a control effort e (injected series voltage, inserted series reactance), or a control effect q (power flow, active power transfer, phase-shift, current). A power flow response measuring unit measures a variation of a power flow response such as current, active or apparent power, in a way sufficiently synchronized with the control parameter variation to allow establishing an unambiguous causal relationship or correspondence in the form of a power system sensitivity. The latter may be on-line adapted to continuously reflect an updated aspect of the power system behavior, and thus enable an improved, fast and reliable power flow control in power systems comprising a meshed power network with two parallel flow paths or corridors connecting two areas or sub-systems.

Determination and use of power system sensitivities

Exemplary embodiments of the present disclosure provide a method and controller for damping multimode electromagnetic oscillations in electric power systems which interconnect a plurality of generators and consumers. The controller for damping such oscillations includes a phasor measurement unit (PMU) and a power oscillation damper (POD) controller. Each oscillating mode signal is damped and then superposed to derive a control signal. A feedback controller is used to feedback the control signal to a power flow control device in the power system.

Damping electromagnetic oscillations in power systems

The present disclosure is concerned with the combined voltage or power flow control and damping of electromechanical oscillations in an electric power system by Flexible AC Transmission System (FACTS) devices or High Voltage DC (HVDC) transmission devices. To this end, information about a state or operating point of the power system is generated from suitable second system signals (y) and a control parameter (cp) of a FACTS controller is derived therefrom. The control parameter and a first system signal (y) are used in the calculation of a control command (u) defining the settings of the FACTS device. Following a change in the state of the power system such as a change in the topology of a transmission network, poorly damped or even unstable oscillations are avoided by appropriate re-tuning of the control parameter of the damping or stabilizing equipment.

Damping electromechanical oscillations in power systems

Growing community of inventors

Baden-Dättwil, Switzerland

Mats Larsson