Massachusetts Institute of Technology

Carnegie Mellon University

Other

Robert Boschgmbh

Marija Dragoljub Ilic

Rupamathi Jaddivada

Andrew Hsu

Jeffrey Hastings Lang

Robert K Mohr

Badri Raghunathan

Diego Benitez

Burton Warren Andrews

Bruce Fardanesh

Sarantos K Aivaliotis

Zenon Stelmak

Xia Miao

Georgios K Stefopoulos

Sanja Cvijic

Xiaojun Liu

Jeffrey W Chapman

Mark R Graham

Liana Menemenlis-Hopkins

Jhi Young Joo

Felix Maus

Jennifer Mayadas-Dering

Embodiments of the disclosure relate to methods and systems for modeling, controlling and computer-platform implementation of a Synthetic Reserve Provisioning System (SRPS) needed to aggregate and integrate small devices closer to consumers, referred to as Distributed Energy Resources (DERs). This know-how is based on data-driven physics-based modeling and it supports the dispatch and scheduling of DERs so that they can participate in system level provision of electricity service. An SRPS generally comprises multiple levels of consumer aggregators (Synthetic Reserve Provisioning (SRP) modules) which interact by exchanging well-defined information about provable consumer characteristics and their own loading and pricing conditions. Three different SRPS designs are described. They differ with respect to implementation requirements for communications, control, technical and economic risks assumed by different SRP modules. Depending on the control and available communication architecture, it is ultimately possible to ensure DER integration at value, even with a limited number of participating devices.

Methods and systems for secure scheduling and dispatching synthetic regulation reserve from distributed energy resources

A method for determining an amount of electricity to purchase includes determining electrical power consumption characteristics of an electrical load at an end user of the electricity. A preference of the end user for an output of the electrical load is ascertained. The output varies with a rate of electrical power consumption by the load. A mathematical model is created of an amount of electrical power to be consumed by the load as a function of time and of monetary cost of the electricity. The model is dependent upon the electrical power consumption characteristics of the electrical load and the preference of the end user for an output of the electrical load. An amount of electricity is purchased based on the mathematical model of an amount of electrical power to be consumed by the load, and based on the monetary cost of the electricity.

Adaptive load management: a system for incorporating customer electrical demand information for demand and supply side energy management

Described are concepts, systems and methods for operating microgrid systems both during normal operation conditions and during sudden, unexpected occurrences of a fault which results in a source becoming disconnected from a primary supply. This is achieved through control systems and method based upon multi-layered modeling of system controllable components and their interactions. This approach results in controllable components capable of operation in a 'plug-and-play' manner.

Plug-and-play reconfigurable electric power microgrids

Autonomous, self-adjusting, and distributed line flow processing for a network having nodes with branches coupling adjacent ones of the nodes and components coupled to the nodes. Systems, methods, and software made in accordance with this disclosure can be used to identify where power flows can exceed the maximum transfer limit in each line and to enable automated adjustments in order to avoid such conditions. These can be useful tools for both system operators of large electrical networks and for implementing automated schemes to ensure network feasibility in micro-grids or other networks with many smart components embedded with communications and/or computation capabilities.

Autonomous methods, systems, and software for self-adjusting generation, demand, and/or line flows/reactances to ensure feasible AC power flow

A new approach in contingency analysis is presented based on a modular method for power flow calculation. The proposed method exploits reuse of power flow data for modules not affected by an outage. The method minimizes the number of necessary computations and matrix inversions in contingency analysis; this is achieved by recalculating only the modules affected by the change and reusing data from the original system for all other modules.

Contingency screening in multi-control area electrical power systems using coordinated DC power flow

The present disclosure relates to distributed line flow processing for a network having nodes with branches coupling adjacent ones of the nodes and components coupled to the nodes. In one embodiment, the disclosed process includes receiving an objective function having component variables, nodal output variables and branch flow variables for the network. Next, the component variables, nodal output variables and branch flow variables are initialized with initial values, and then values for the branch flow variables are calculated using a distributed Newton method. Finally, values for the component variables and the nodal output variables are calculated using values calculated for the branch flow variables until the values of the component variables, the nodal output variables, and the branch flow variables converge within a predetermined threshold range.

General method for distributed line flow computing with local communications in meshed electric networks

A system for monitoring a power transmission line includes at least one monitoring device located along the power transmission line configured to provide power transmission line data. A wide area situational awareness module is configured to receive the power transmission line data and an adaptation module is configured to receive output from the wide area situational awareness module and further configured to calculate control actions for the power transmission line based on the power transmission line data.

System and method for power grid management

A method and apparatus for directly controlling the net power flow on tie lines between different areas of a large electric power system, which provides automatic dynamic control to maintain the stability of the system. Utilizing a sensitivity matrix and simple measurements of real power output from each of the generators in a given area, it is possible to dynamically control the entire system in a way which accounts for loading changes in any area. The control can be implemented using a Flexible AC Transmission Systems (FACTS) technology controller which utilizes the measurements and sensitivity matrix from a given area to determine a derived net power flow from the first area to the remainder of the system, and for comparing the derived net power flow to a set point to provide an error signal which approaches zero as the controller adjusts, for example, a phase angle difference across the tie line to adjust the net power flow thereon. Alternatively, the derived net power flow can be used for scheduling the generation of power in a given area and/or to control a local controller at the generator level.

Method and apparatus for direct control of the inter-area dynamics in

A power utility system includes a generator driven by a prime mover in response to a mechanical input power and an excitation to provide an electrical output power. The excitation of the generator is controlled in response to an estimated equilibrium rotor angle. The estimation of the rotor angle is based on purely local measurements. This estimated rotor angle is used in conjunction with a feedback linearizing controller to provide field excitation control of the generator. The rotor angle reference signal is also used to provide a rotor angle error signal to a power system stabilizer which is modified to operate on the basis of an angle error rather than a speed or frequency error.

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Sudbury, MA, United States of America

Marija Dragoljub Ilic