Transfer switches and paralleling

A generator is useless until something connects it to the load at the right moment and disconnects the utility at the same time. That is the job of transfer equipment, from a simple automatic transfer switch serving one distribution board to a lineup of medium-voltage paralleling switchgear that synchronizes a dozen generators onto a common bus. Transfer equipment also has to put everything back when the utility returns, ideally without the load noticing. This lesson covers transfer switch types and ratings, the sequence of operation during an outage, paralleling and synchronizing, load sharing and load management, and interconnection with the utility.

Automatic transfer switches

An automatic transfer switch (ATS) is a switching device with two sources, normal (utility) and emergency or standby (generator), and one load connection. Its controller monitors both sources and transfers the load when the normal source fails and the alternate source is acceptable. ATSs range from 30 A units in small buildings to 4000 A units feeding a data centre switchboard. Larger facilities use pairs of circuit breakers (a utility main and a generator main, electrically interlocked) in switchgear to perform the same function, which allows higher ratings and better protection.

Transfer switches in Canada are certified to CSA C22.2 No. 178.1, Transfer switch equipment. The Canadian Electrical Code requires transfer equipment for emergency systems to be designed so that the normal and emergency sources cannot be connected together inadvertently, and emergency systems themselves are covered by Section 46 and CSA C282.

Transition types

• Open transition (break-before-make): the switch disconnects the load from one source and then connects it to the other, with an interruption of about 50 to 200 ms. This is the usual mode for transfer to the generator, because the utility has already failed.
• Delayed transition: the switch pauses in a centre-off (neutral) position for an adjustable time, typically 0.5 to 3 seconds, before connecting the new source. The delay lets the residual voltage of spinning motors and transformer magnetization decay, so that connecting the new source out of phase does not cause high inrush currents and torques.
• Closed transition (make-before-break): when both sources are available, for example when returning to the utility or in a test, the switch synchronizes the generator to the utility and briefly connects both, for less than about 100 ms, before opening the source being released. The load sees no interruption at all, avoiding a second outage on retransfer.
• Soft-load closed transition: the generator and utility stay in parallel for several seconds while the generator's controls ramp the load gradually from one source to the other, avoiding a large step on either. Because the generator is paralleled with the grid for longer, the utility requires interconnection protection and approval.

Bypass-isolation and other features

A bypass-isolation ATS has a second switching mechanism that can carry the load directly from either source while the main transfer mechanism is drawn out for testing or repair, so that maintenance never requires an outage. This feature is common on data centre mechanical and house loads fed through ATSs.

Switching the neutral

Whether the transfer switch must switch the neutral (four-pole) or not (three-pole) depends on how the generator is grounded. If the generator's neutral is bonded to ground at the generator, making it a separately derived system, the neutral must be switched; otherwise neutral current would return partly through the bonding conductors and the two neutral-to-ground bonds would confuse ground-fault protection. If the generator neutral is solidly connected to the utility service neutral through a three-pole switch, the generator is not separately derived and must not be bonded at the generator. Data centres with ground-fault protection on their main breakers usually use four-pole switching or careful sensor arrangements to avoid nuisance tripping.

Ratings

A transfer switch must carry its continuous current and survive the available fault current until the upstream protective device clears it. Its withstand and closing rating (WCR) is stated either with specific upstream breakers or fuses, or as a time-based rating (for example, 65 kA for 30 cycles) that allows coordination with short-time delayed breakers upstream. Data centre designs often need time-based ratings so that the selective coordination studied in DCE-310 is not compromised.

Sequence of operation

A typical automatic sequence for a data centre on a utility outage is:

• The utility voltage on any phase falls below its pickup (often 85 to 90% of nominal) or the frequency goes out of limits. The UPSs transfer to battery instantly.
• A short engine-start delay (typically 1 to 3 seconds) avoids starting the generators for a momentary interruption that utility reclosers will clear.
• The generators start. When each reaches rated voltage and frequency (within about 10 seconds), the paralleling controls close the first generator onto the dead bus and synchronize the others.
• The transfer switches or generator main breakers transfer the loads, in a planned sequence, after the utility main breakers have opened.
• The UPS rectifiers walk in onto the generator power over 10 to 30 seconds and begin recharging the batteries; mechanical loads restart in steps.

When the utility returns, the controls wait for a retransfer delay, commonly 5 to 30 minutes, to be sure it is stable, then return the load by closed transition (or open transition, in which case the UPS batteries carry the brief gap). The generators run unloaded for a cool-down period of 5 to 15 minutes before stopping.

Paralleling generators

Large facilities connect several generators to a common bus through paralleling switchgear rather than giving each load its own generator. Paralleling allows N+1 redundancy shared across the whole load, the use of standard generator sizes for any load, and maintenance of one generator at a time. The switchgear includes a breaker for each generator, a bus, feeder breakers to the distribution, and controls for synchronizing, load sharing, load add and load shed.

Synchronizing

Before a generator breaker closes onto a live bus, the incoming generator must match the bus in four respects:

• Phase sequence (rotation), checked once at commissioning.
• Voltage magnitude, typically within about 5%.
• Frequency, with a small slip so that the phase angle drifts slowly, typically 0.05 to 0.2 Hz.
• Phase angle, within about ±10° at the instant the contacts close.

Closing out of phase is extremely damaging: at 120° the voltage difference across the breaker approaches twice the system voltage, producing currents larger than a short circuit and torque on the shaft that can crack couplings and crankshafts. An automatic synchronizer adjusts the governor and AVR of the incoming set and issues the close command slightly in advance of zero phase difference, to allow for the breaker's closing time. A synchronism check relay (device 25) independently blocks closing outside the window.

First-up and dead-bus closing

After an outage the paralleling bus is dead. The first generator to reach rated voltage and frequency is allowed to close onto the dead bus without synchronizing, and the master controller then blocks all other generators from doing the same, because two generators closing on a dead bus simultaneously could be out of phase. This first-up arbitration is a critical piece of logic, usually implemented with redundant hardware and interlocks. The remaining generators synchronize to the live bus one after another. Some designs close all generator breakers before the engines are excited and build up voltage together ("dead-field" paralleling), getting every set on the bus within a few seconds.

Load sharing

Once paralleled, the generators must share real power (kW) and reactive power (kvar) in proportion to their ratings. Two methods are used:

• Isochronous load sharing: the generator controllers communicate (through analogue load-sharing lines or a digital network) and adjust their governors so that all run at exactly 60 Hz while carrying equal per-unit loads. Reactive power is shared by cross-current compensation or communicated voltage control.
• Droop: each governor reduces its speed setpoint as load rises, for example by 4% from no load to full load. Generators connected together must run at the same frequency, so they settle at a frequency where their loads correspond to that frequency on each droop line. Droop works without communication and is used as a fallback, and when paralleled with the utility.

Load add and load shed

The master controller adds loads to the bus in priority order as generators come online: critical UPS loads first, then the cooling needed to protect them, then non-critical loads. If a generator fails while the plant is running, the remaining capacity may be less than the load, and the controller must shed low-priority loads instantly (within a fraction of a second, often on an under-frequency signal) to prevent the remaining generators from overloading and collapsing one after another. Load shed schemes are tested at commissioning by tripping a generator under load.

Medium-voltage paralleling

On large campuses, generators are increasingly connected at medium voltage, either as MV generators (for example 13.8 kV) or LV generators with step-up transformers, onto an MV paralleling bus that feeds the substations. MV paralleling reduces currents, cable sizes and switchgear count, and allows generator plants of 50 MW or more to back up an entire building. It also introduces MV protection, transformer energization inrush and longer sequences that must still fit within the UPS battery runtime.

Paralleling with the utility

Closed-transition transfer, soft loading, load bank testing on the utility bus and peak shaving all require generators to operate in parallel with the grid, if only briefly. Utilities require protection that prevents the generator from back-feeding or destabilizing their network: synchronism check, reverse power (device 32), under- and over-voltage and frequency relays, and limits on the time spent in parallel (often 100 ms for closed transition without further study).

In Canada, interconnection of generation to the distribution system follows CSA C22.3 No. 9, Interconnection of distributed resources and electricity supply systems, along with each utility's technical interconnection requirements and approval process.

Lesson 8 covers the protection studies that must account for each source and transfer state, and Lesson 10 how transfer sequences are proven during commissioning.