Methods and apparatuses for control of building cooling, heating and power co-generation systems

• US 7,567,859 B2
• Filed: 12/01/2004
• Issued: 07/28/2009
• Est. Priority Date: 12/01/2004
• Status: Active Grant

• Current Assignee: Honeywell International Inc.
• Original Assignee: Honeywell International Inc.
• Inventors: Subramanian, Dharmashankar, Mathur, Anoop K.
• Primary Examiner(s): Shechtman; Sean P
• Application Number:
  US11/001,221
• Publication Number:
  US 20060116789A1
• Time in Patent Office: 1,700 Days
• Field of Search: 700/9, 700/14, 700/16, 700/19, 700/22, 700/28, 700/36, 700275-277, 700287-288, 700/291, 700/297, 700/286, 703/18, 705/412
• US Class Current: 700/288
• CPC Class Codes: F24F 11/47 Responding to energy costs
• CPC Class Codes: F25B 27/02 using waste heat, e.g. from internal-combustion engines
• CPC Class Codes: G06Q 50/06 Energy or water supply
• CPC Class Codes: Y02A 30/274 using waste energy, e.g. from internal combustion engine
• CPC Class Codes: Y02E 20/14 Combined heat and power generation [CHP]
• CPC Class Codes: Y02P 80/15 On-site combined power, heat or cool generation or distribution, e.g. combined heat and power [CHP] supply

Abstract

A control system and method for achieving economic operation of CHP systems. A plurality of factors, including power source prices and operational needs, are assessed using multiple strategies. The solutions achieved by each strategy are compared, and the best performing strategy is selected. The solution can then be implemented. The assessment of factors and strategies can be updated periodically. A further embodiment includes a method of designing a CHP system using similar methods applied to simulated or estimated future loads and costs.

Claims

1. A controller for controlling the source of electric power for a cogeneration system, the cogeneration system including a local generator for generating local electric power, a fuel source, connections to an external electric power source for receiving externally generated power, and a number of operational components including heating and/or cooling devices, the controller configured to perform the steps of:

estimating future load conditions for thermal and electric power loads;

performing a first analysis using a first operational strategy to generate a first future cost figure for the cost of operating the cogeneration system, wherein the first operational strategy includes generating at least some local electric power for powering the cogeneration system;

performing a second analysis using a second operational strategy to generate a second future cost figure for the cost of operating the cogeneration system, wherein the second operational strategy includes receiving at least some externally generated electric power for powering the cogeneration system;

comparing the first future cost figure to the second future cost figure; and

when the first future cost figure is different than the second future cost figure, selecting the operational strategy corresponding to a lesser of the first future cost figure and the second future cost figure.

2. A controller as in claim 1 wherein the controller is configured to perform the step of performing the first cost analysis by including consideration of usage costs for the operational components of the cogeneration system.

3. A controller as in claim 1 wherein the controller is configured to perform the step of estimating future load conditions using a method including the steps of:

using data related to the operational components of the cogeneration system; and

using data related to environmental conditions in the vicinity of the cogeneration system.

4. A controller as in claim 1 wherein the controller is configured for use in a cogeneration system that includes a turbine generator as a local generator, a boiler, an absorption cooler, a heat recovery steam generator, and an electric chiller.

5. A controller as in claim 4 wherein the controller is configured to perform analysis using at least:

an operational strategy in which the preferred cooling source is the absorption chiller;

an operational strategy in which the preferred cooling source is the electric chiller.

6. A controller as in claim 4 wherein the controller is configured to perform analysis using at least:

an operational strategy in which the preferred electricity source is the turbine generator; and

an operational strategy in which the preferred electricity source is the external electric power source.

7. A controller as in claim 1 wherein the step of estimating future load conditions for thermal and electric power loads comprises:

accessing a database of historical load conditions; and

estimating future load conditions for the next hour.

8. A cogeneration system comprising a number of operational components adapted to provide heating, cooling, and power, and a controller as recited in claim 1, the controller coupled to the operational components to provide control signals thereto.

9. A method of operating a cogeneration system for providing electric power and thermal control to a facility, the cogeneration system including a number of operational components configured to provide power and one or more of cooling and heating, the method comprising:

estimating future load conditions for thermal and electric power loads for the cogeneration system;

performing a first analysis using a first operational strategy to generate a first future cost figure for the cost of operating the cogeneration system, wherein the first operational strategy includes using at least some locally generated electric power for powering the cogeneration system;

performing a second analysis using a second operational strategy to generate a second future cost figure for the cost of operating the cogeneration system, wherein the second operational strategy includes receiving at least some externally generated electric power for powering the cogeneration system;

comparing the first future cost figure to the second future cost figure; and

when the first future cost figure is different than the second future cost figure, selecting the operational strategy corresponding to a lesser of the first future cost figure and the second future cost figure.

10. The method of claim 9 wherein the steps of performing analyses using the first and second operational strategies further include considering usage costs of operational components of the cogeneration system.

11. The method of claim 9 wherein the step of estimating future load conditions comprises:

accessing a database of historical load conditions; and

estimating future load conditions for a next time period.

12. The method of claim 9 wherein the steps of performing analyses using the first and second operational strategies comprise:

using data related to fuel and electricity prices;

using data related to the operational components; and

using data related to environmental conditions in the vicinity of the cogeneration system.

13. The method of claim 9 wherein the method further comprises sending control signals to a turbine generator used as a local generator, a boiler, an absorption cooler, a heat recovery steam generator, and an electric chiller.

14. The method of claim 13 wherein:

the first operational strategy is one in which the preferred cooling source is the absorption chiller; and

the second operational strategy is one in which the preferred cooling source is the electric chiller.

15. The method of claim 13 wherein:

the first operational strategy is one in which the preferred electricity source is the turbine generator; and

the second operational strategy is one in which the preferred electricity source is the external electric power source.

16. A method of operating a cogeneration system for providing electric power and thermal control to a facility, the method comprising:

observing prices for a plurality of power and/or fuel sources;

observing likely electric power and thermal load conditions for the facility;

performing a first cost analysis using a first strategy for operation of the cogeneration system, wherein the first strategy includes using at least some locally generated electric power for powering the cogeneration system;

performing a second cost analysis using a second strategy for operation of the cogeneration system, wherein the second strategy includes receiving at least some externally generated electric power for powering the cogeneration system;

selecting an operational strategy in light of the first and second cost analyses.

17. The method of claim 16 further comprising configuring the cogeneration system for the selected operational strategy.

18. The method of claim 17 wherein the cogeneration system includes:

a gas turbine;

an absorption chiller; and

a heat recovery steam generator;

wherein the step of configuring the cogeneration system includes distributing load levels for the gas turbine, the absorption chiller, and the heat recovery steam generator.

19. The method of claim 18 wherein the cogeneration system is coupled to an electric grid, wherein the step of configuring the system includes modulating power drawn from the electric grid.

20. The method of claim 16 wherein the steps of performing the first cost analysis and the second cost analysis include consideration of the usage costs of one or more operational components of the cogeneration system.

21. A method comprising periodically performing the method of claim 16.

22. The method of claim 21 wherein the step of periodically performing occurs hourly.