Synchronized metrology in power generation and distribution networks
Phasor Measurement Units (PMUs) tend to be specialized and expensive—relegated to only key points in power distribution networks, and are generally reliant on GPS technology. The present disclosure details how any smart meter—using wireless communication—can perform sub-microsecond-grade synchrophasor measurements. Other aspects concern smart meter-based determination of A, B or C phase of the tri-phase power network. This can involve count-stamp enabling message packets sent to and/or from a smart meter, and then associating such count-stamps to local measurements of power phase by a metrology unit. Once a network of such enabled smart meters and other devices is formed, sub-microsecond metropolitan-wide and entire region-wide synchronizing time standard can calibrate local measurements of power phase, where simple A, B and C phase determination is one low hanging fruit application of such. Low cost aggregate monitoring of metropolitan-wide synchrophasors promises a next chapter of importance for that relatively recent art.
1. A method comprising:
at an interconnect of a distributed generator to a power grid, count-stamping an event with a free-running clock that runs at 100 KHz or more, to thereby provide a time reference, said count-stamped event being a zero-crossing of an AC power signal produced by said generator, a transmission of a data packet, or a receipt of a data packet;
establishing a timing relationship between the time reference at the interconnect and a time reference associated with the power grid;
based on the timing relationship, correlating a first power line measurement at the interconnect with a corresponding second power line measurement of the power grid;
detecting a deviation of the first and second power line measurements, and
in response to detecting a deviation that exceeds a threshold, triggering interconnect management at the interconnect.
2. The method of claim 1 wherein the time reference at the interconnect is provided by a local clock in a smart meter.
3. The method of claim 2 wherein the smart meter is in communication with a data collector of the power grid to establish the timing relationship.
4. The method of claim 3 further including:
wherein the communication from the smart meter comprises packet communication;
and the method comprising:
gathering clock count data over a period of time, and communicating the gathered clock count data in a packet; and
calibrating the timing relationship using the gathered clock count data from the packet.
5. The method of claim 4 wherein time between packet communication is on the order of minutes, whereas the timing relationship is calibrated on the order of 10 microseconds or better.
6. The method of claim 1 in which the count-stamped event is a zero-crossing of an AC power signal produced by said generator.
7. The method of claim 1 in which the count-stamped event is a transmission of a data packet.
8. The method of claim 1 in which the count-stamped event is a receipt of a data packet.
9. The method of claim 1 in which the distributed generator is a photovoltaic electricity generator.
10. The method of claim 1 in which triggering interconnect management at the interconnect of the distributed generator to the power grid comprises triggering an anti-islanding protection method.
11. A system comprising:
a free-running local clock that runs at 100KHz or more;
a processor configured to gather clock counts from the local clock, and clock counts from a remote timing reference of a power system, and derive a calibrated timing relationship between the local clock and the remote timing reference, the clock counts gathered from the local clock indicating time stamps associated with events, namely: zero-crossings of an AC power signal, or receipt or transmission of data packets.
12. The system of claim 11 in which the clock counts gathered from the local clock comprise clock stamps associated with zero-crossings of an AC power signal.
13. The system of claim 11 in which the clock counts gathered from the local clock comprise clock stamps associated with receipt or transmission of data packets.
14. The system of claim 11 in which the local clock comprises a clock in a smart meter that clock-stamps received messages.
15. The system of claim 11 in which the local clock comprises a clock in a smart meter that clock-stamps transmitted messages.
16. The system of claim 11 in which said remote timing reference of a power system comprises count-stamping performed by a node in a power distribution system.
17. The system of claim 16 in which said node comprises a smart meter.
18. The system of claim 11 in which said calibrated timing relationship comprises a determined timing between zero-crossings of AC power signals at two smart meters.