System for controlling power distribution to customer loads

• US 4,419,666 A
• Filed: 08/06/1982
• Issued: 12/06/1983
• Est. Priority Date: 07/02/1979
• Status: Expired due to Fees

• Current Assignee: Sangamo Weston, Inc. (Atos SE)
• Original Assignee: Sangamo Weston, Inc. (Atos SE)
• Inventors: Nelson, Bruce J., Gurr, George P.
• Primary Examiner(s): YUSKO, DONALD
• Application Number:
  US06/406,038
• Time in Patent Office: 487 Days
• Field of Search: 340/825.06, 340/310 A, 340/310 R, 340/825.22, 340/825.08, 307/39, 364/492, 364/493
• US Class Current: 379/102.01
• CPC Class Codes: H02J 13/00007 using the power network as support for the transmission
• CPC Class Codes: H02J 13/00034 the elements or equipment being or involving an electric power substation
• CPC Class Codes: H02J 2310/60 Limiting power consumption in the network or in one section of the network, e.g. load shedding or peak shaving
• CPC Class Codes: H02J 3/144 Demand-response operation of the power transmission or distribution network
• CPC Class Codes: Y02B 70/3225 Demand response systems, e.g. load shedding, peak shaving
• CPC Class Codes: Y02B 90/20 Smart grids as enabling technology in buildings sector smart grids supporting the management or operation of end-user stationary applications in general, or like technologies with no associated climate change mitigation effect Y04S20/00
• CPC Class Codes: Y04S 20/222 Demand response systems, e.g. load shedding, peak shaving
• CPC Class Codes: Y04S 40/121 using the power network as support for the transmission

Abstract

A method and apparatus which permits a power utility to have direct control of customers loads (CD) with a view toward facilitating enablement of a load management philosophy which includes peak shaving and load deferral. A master control station (MCS), which comprises a programmable microprocessor-based central controller, is in two-way communication with a plurality of substation injection units (SIU), one of each of which is positioned at a separate substation of the power utility. Each substation injection unit (SIU), under the control of its own microprocessor, responds to master control signals from the master control station (MCS) to inject a pulse code signal onto the power lines of the utility. The system includes a plurality of remote receiver units (RRU) which are positioned at and connected to control the on and off times of customer loads (CD). Each remote receiver unit (RRU) is preset to respond to particular pulse code signals from the substation injection units (SIU) to carry out the desired command functions, which can be implemented either automatically or manually on a fixed or dynamic-cycle basis as the need arises. The system utilizes a command signal and pulse code signal verification technique to insure system integrity and reliability.

Claims

1. A system for permitting an electric power utility to control the distribution of its three-phase, AC high voltage power along its power lines from a plurality of substations to a plurality of customer loads arranged in groups, which comprises:

a master control station including first programmable digital data processor means and input/output devices under the control of an operator for generating data signals in response to group control command signals;

a plurality of substation injection units in two-way communication with said master control station, each of said units located at a different one of said substations and having its own programmable digital data processor means, each of said substation injection units responsive to said data signals for generating pulse code signals for injection onto said power lines; and

a plurality of remote receiver units each located at and connected to control one of said customer loads and responsive to a particular one of said pulse code signals for connecting or disconnecting its load from said power lines; and

wherein said master control station includes;

means for polling each of said substation injection units to obtain information pertaining to its status, possible alarm conditions, and analog or discrete data generated at the respective substation;

means for transmitting and receiving serial binary block messages to and from each of said substation injection units, said block messages including substation injection unit address data, substation injection unit function commands and said data signals; and

means for prioritizing and executing said group control commands.

2. Apparatus as set forth in claim 1, wherein said data signals are adapted to be transmitted over telephone lines, and wherein said master control station further comprises means for converting said data signals for transmission over telephone lines.

3. Apparatus as set forth in claim 2, further comprising interface means for connecting said master control station and said input/output devices, said master control station further including means for initializing said interface means.

4. Apparatus as set forth in claim 2, wherein said remote receiver units further comprise contact means, and wherein said master control station further comprises means for switching said contact means on and off.

5. In a load management system wherein a master control station is in two-way communication with a plurality of substation injection units located respectively at a plurality of substations, and a plurality of remote receiver units are in one-way communication, respectively, with a plurality of customer loads arranged in groups, a method of permitting an electric power utility to control the distribution of its three-phase, AC high voltage power along its power lines from said plurality of substations to said plurality of customer loads, which comprises the steps of:

generating load group command signals;

generating data signals in response to said load group command signals;

generating pulse code signals for injection onto said power lines in response to said data signals;

alternately switching said loads on and off in response to said pulse code signals from said power lines;

polling each of said substation injection units to obtain information pertaining to its status, possible alarm conditions, and analog or discrete data generated at the respective substations;

transmitting and receiving serial binary block messages to and from each of said substation injection units, said block messages including substation injection unit address data, substation injection unit function commands and said data signals; and

prioritizing and executing said group control commands.