Systems and methods for power system management

• US 10,296,030 B2
• Filed: 10/07/2016
• Issued: 05/21/2019
• Est. Priority Date: 10/07/2015
• Status: Active Grant

• Current Assignee: University of Utah Research Foundation (State of Utah), Arizona Board of Regents (University of Arizona)
• Original Assignee: University of Utah Research Foundation (State of Utah), Arizona Board of Regents (University of Arizona)
• Inventors: Parvania, Masood, Scaglione, Anna
• Primary Examiner(s): Everett, Christopher E.
• Application Number:
  US15/289,121
• Publication Number:
  US 20170102725A1
• Time in Patent Office: 956 Days
• CPC Class Codes: G05F 1/66 Regulating electric power
• CPC Class Codes: H02J 2203/20 Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
• CPC Class Codes: H02J 3/00 Circuit arrangements for ac mains or ac distribution networks
• CPC Class Codes: H02J 3/003 Load forecast, e.g. methods or systems for forecasting future load demand
• CPC Class Codes: Y02E 60/00 Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
• CPC Class Codes: Y04S 10/50 Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications
• CPC Class Codes: Y04S 40/20 Information technology specific aspects, e.g. CAD, simulation, modelling, system security

Abstract

An operating configuration for a power system during a particular time period may be derived from a net load forecast for the power system during the particular time period. The operating configuration may be based on characteristics of power generation units (PGUs) available within the power system (e.g., power generators). The characteristics of a PGU may include a generation trajectory for the PGU that defines, inter alia, power generated by the PGU as the PGU ramps up power production within the power system. The generation trajectory of PGUs may be evaluated in view of the net load forecast to ensure that adequate power resources are available within the power system and avoid ramping scarcity conditions.

Claims

1. A non-transitory, computer-readable storage medium comprising instructions configured to cause a computing device to perform operations for power system management, the operations comprising:

determining a net load forecast for a power system, the net load forecast corresponding to a sequence of net load samples, each net load sample defining a linear net load on the power system during a respective time interval within an operating period of the power system, wherein determining the net load forecast comprises utilizing a unit commitment model that models a non-linear variance of the linear net load on the power system within one or more time intervals of the net load samples by constructing continuos-time generation and ramping trajectories for the power system, the continuous-time generation and ramping trajectories being included as a part of the net load forecast;

using the continuous-time generation and ramping trajectories provided by the unit commitment model to configure one or more power generation units to satisfy the determined net load forecast for the power system, including the non-linear variance of the net load modeled within the one or more time intervals by the unit commitment model; and

configuring the one or more power generator units to generate power in accordance with the continuous-time generation and ramping trajectories during the operating period.

2. The non-transitory computer-readable storage medium of claim 1, further comprising configuring transmission infrastructure of the power system to accept power generated by the one or more power generators during the operating period.

3. The non-transitory computer-readable storage medium of claim 1, wherein an optimal solution to the unit commitment model corresponds to an optimization criterion that includes minimizing a total continuos-time generation cost of power generated during the operating period by the power system.

4. The non-transitory computer-readable storage medium of claim 1, wherein modeling the non-linear variance of the net load comprises projecting the net load samples into a cubic spline function space.

5. The non-transitory computer-readable storage medium of claim 4, wherein formulating the continuous-time generation and ramping trajectories comprises projecting generation trajectories of each of the one or more power generation units into the cubic spline function space.

6. The non-transitory computer-readable storage medium of claim 5, the operations further comprising formulating the unit commitment model in the cubic spline function space.

7. The non-transitory computer-readable storage medium of claim 6, the operations further comprising determining an optimal solution to the unit commitment model, wherein the optimal solution to the unit commitment model determines generation trajectory of the one or more power generation units.

8. The non-transitory computer-readable storage medium of claim 1, wherein the sequence of net load samples comprises an hourly day-ahead load forecast for the power system.

9. The non-transitory, computer-readable storage medium of claim 1, wherein modeling the non-linear variance of the net load comprises a cubic expansion of the net load samples.

10. The non-transitory computer-readable storage medium of claim 1, the operations further comprising:

acquiring power consumption data indicating the linear net load on the power system at respective sample intervals; and

determining the sequence of load forecast values based on the acquired power consumption data.

11. A computer system comprising:

one or more processors; and

one or more computer-readable hardware storage devices having stored thereon computer-executable instructions that are executable by the one or more processors to cause the computer system to;

determine a net load forecast for a power system that includes one or more power generation units, wherein;

the net load forecast corresponds to a sequence of net load samples,

each net load sample defines a linear net load on the power system during a respective time interval within an operating period of the power system,

determining the net load forecast comprises utilizing a unit commitment model that models a non-linear variance of the net load on the power system within one or more time intervals of the net load samples by constructing continuous-time generation and ramping trajectories for the power system,

the continuous-time generation and ramping trajectories being included as a part of the net load forecast;

use the continuous-time generation and ramping trajectories provided by the unit commitment model to configure the one or more power generation units to satisfy the determined net load forecast for the power system, including the non-linear variance of the net load modeled within the one or more time intervals by the unit commitment model; and

configure the one or more power generator units to generate power in accordance with the continuous-time generation and ramping trajectories during the operating period.

12. The computer system of claim 11, wherein the net load forecast is a day-ahead load forecast for the power system.

13. The computer system of claim 11, wherein the unit commitment model is generated, at least in part, using metadata information associated with the power system.

14. The computer system of claim 13, wherein the metadata information includes information describing a topology of the power system, the topology information describing one or more bus locations at which respective power generator units are electrically coupled to a transmission infrastructure of the power system.

15. The computer system of claim 11, wherein a unit commitment processor associated with the unit commitment model is configured to apply continuous-time ramping constraints to the unit commitment model by capping one or more coefficients of a continuous-time ramping trajectory associated with the one or more generator units.

16. The computer system of claim 11, wherein the unit commitment model identifies and models inter-temporal variations in the net load forecast for the power system.

17. The computer system of claim 11, wherein execution of the computer-executable instructions further causes the computer system to:

determine one or more decision variables for the one or more power generator units, wherein the one or more decision variables include an hourly commitment status detailing whether a particular one power generator unit is to be committed for power generation during a particular time period.

18. A method for managing and configuring a power system to respond to changes in load requirements, the method being performed by a computer system and comprising:

determining a net load forecast for a power system, the net load forecast corresponding to a sequence of net load samples, each net load sample defining a linear net load on the power system during a respective time interval within an operating period of the power system, wherein determining the net load forecast further comprises, modeling a non-linear variance of the net load on the power system within one or more time intervals of the net load samples;

formulating a generation trajectory to configure one or more power generation units to satisfy the determined net load forecast for the power system, including the non-linear variance of the net load modeled within the one or more time intervals; and

configuring the one or more power generators to generate power in accordance with the determined power generation trajectory during the operating period,

wherein modeling the non-linear variance of the net load comprises projecting the net load samples into a cubic spline function space,

wherein formulating the generation trajectory comprises projecting generation trajectories of each of a plurality of power generation units into the cubic spline function space, and

wherein the operations further comprise formulating a unit commitment model in the cubic spline function space.

19. The method of claim 18, wherein the net load forecast is a day-ahead load forecast for the power system, and wherein the unit commitment model is formulated, at least in part, using metadata information associated with the power system.

20. The method of claim 18, wherein a unit commitment processor associated with the unit commitment model is configured to apply continuous-time ramping constraints to the unit commitment model by capping one or more coefficients of a continuous-time ramping trajectory associated with the one or more generator units.