AIS, GIS, protection and control
Substation commissioning software for programmes where energisation depends on a TSO witnessing the right test.
A substation build stacks primary plant, protection and control panels, SCADA and a TSO or DNO witness programme on top of each other, and none of it can be energised out of order. Deskely holds bays, panels and points in one register with the injection tests, witness points and sign-offs that actually gate the switch.
- Plant
- AIS and GIS bays
- Panels
- Protection and control
- Tests
- Primary and secondary injection
- Gate
- TSO or DNO witness and energise
Choose your project type
The problem
Every bay has its own panel, and every panel has its own paper trail.
A transmission substation might carry twenty bays, each with primary plant, a protection and control panel, a SCADA gateway and a set of interlocks — and the network operator's witness list does not match any single contractor's paperwork.
Injection test results, relay settings and SCADA point checks arrive as separate PDFs from separate parties, and the energisation meeting spends its time reconciling them rather than deciding.
Deskely holds every bay, panel and point in one register with the tests that gate energisation modelled explicitly, so the switching request is backed by evidence rather than assurances.
Setting up the register
Bays, panels and SCADA points are structured with the interlocks between them.
Single line diagrams, protection schematics, cable schedules and SCADA point lists are parsed into a reviewed register, with each bay holding its primary plant, CTs and VTs, protection relays and control panel.
SF6 handling — filling, moisture and leak records for GIS bays — sits against the specific gas compartment, not a general project log.
Interlocks and permissives between bays are modelled explicitly, so a bay cannot be marked ready for energisation while a dependency it relies on is still open.
Execution
Injection testing and point checks are captured against the relay and the point, not a folder.
Protection engineers record primary injection and secondary injection results — pickup, timing, CT ratio and polarity checks — directly against the relay under test, with test set details and ambient conditions kept as part of the record.
SCADA points are checked end to end, from field device through RTU to control room indication, ticked off point by point rather than reported as a percentage.
Punch raised during commissioning is categorised by whether it blocks energisation, a bay handover, or can be carried, so the witness meeting works from a filtered list.
Witness and energisation
Energisation is authorised from the record set the network operator actually asked for.
TSO or DNO witness points are flagged in the register in advance, so the operator's engineer sees exactly the tests that require their sign-off, not the whole commissioning history.
The energisation certificate is issued once protection settings, injection results, interlock checks and SCADA verification are signed, with any carried punch listed against an owner.
The bay dossier — settings, test results, SF6 records and drawings — is exported at handover, which is what the operations team needs from day one of live service.
Busbar protection, CT ratios and revenue metering
A busbar protection scheme has to be right the first time, and the CT ratios behind the revenue meter matter as much to the commercial team as the relay settings matter to the TSO.
Busbar differential protection is tested with a scheme-specific commissioning procedure — CT polarity and ratio checks across every circuit into the zone, stability tests against through-fault conditions, and a trip test that has to work correctly across every combination of circuits in and out of service — and a wiring error here is the fault every protection engineer is most careful to rule out.
Revenue metering CTs and VTs sit on the same busbars but answer to a different authority: the ratio, accuracy class and burden have to be verified and certified for settlement purposes, often by a metering-specific test separate from the protection commissioning programme, and a dispute over that record can cost more than a protection miss.
Deskely holds busbar zone stability tests, CT ratio verification for both protection and metering, and the metering accuracy certificate in the same bay register, so the commercial metering evidence and the protection commissioning evidence are both traceable to the same CT rather than living in two different contractors' files.
How it runs
From a bay diagram to an energised switch.
Substation programmes are dominated by sequencing and witness coordination, which is exactly what a structured register makes explicit.
- 01
Parse the design set
Single line diagrams, protection schematics and cable and point schedules drafted into a reviewed bay register.
- 02
Model interlocks and permissives
Dependencies between bays and systems recorded so readiness reflects the real switching sequence.
- 03
Template protection and SCADA records
Injection test, relay setting and point-to-point verification forms defined once per equipment type.
- 04
Run field testing on tablet
Primary and secondary injection, SF6 handling and control panel checks signed at the bay, offline where needed.
- 05
Flag witness points
TSO or DNO hold and witness points marked in the register so the right tests are visible to the operator.
- 06
Certify and energise
Energisation certificates issued from signed records, with carried punch owned and dated.
FAQ
Questions about Transmission substations scopes.
Keep reading
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The full sector view: asset registers, protection and control evidence, energisation gating and handover.
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