Substation at Day 120: Earned Value, a Slip and a Demand for Early Energisation

Metrics.

• PV (BCWS) = 120 M; EV (BCWP) = 100 M; AC (ACWP) = 130 M; BAC = 180 M
• CV = EV − AC = 100 − 130 = −30 M (over budget)
• SV = EV − PV = 100 − 120 = −20 M (behind schedule)
• CPI = EV / AC = 100 / 130 = 0.77
• SPI = EV / PV = 100 / 120 = 0.83
• EAC = BAC / CPI = 180 / 0.77 = ≈ PHP 234 M
• ETC = EAC − AC = 234 − 130 = ≈ PHP 104 M to finish
• VAC = BAC − EAC = 180 − 234 = ≈ −PHP 54 M

Interpretation. For every peso spent the project has earned 77 centavos of value. At day 120, 67 % of the time has elapsed but only 56 % of the budgeted work is done. If the current burn rate continues, the project will overrun by roughly PHP 54 million - 30 % above the lump sum.

Two cautions apply. First, EAC = BAC/CPI assumes the inefficiency is systemic. If the overrun is a one-off, such as rework or a disputed variation, a bottom-up forecast from the remaining work will be more accurate and should be prepared. Second, SPI measured in cost terms is a poor schedule indicator at the end of a project and says nothing about the critical path. The six-week switchgear slip is a critical-path event; the SPI of 0.83 and that slip are consistent, but the SPI alone would not have revealed it.

The commercially important point is that the cost overrun cannot be assumed recoverable. The delay notice obligations determine whether the contractor has a route to an extension of time, and through it to relief from time-related costs.

Position. I would not certify the feeder as ready for energisation, and I would put that in writing. Energising a feeder into a hospital without functioning protection transfers an unacceptable risk to patients, to utility staff and to the contractor, and a verbal instruction from a project manager is not an adequate basis for it. The decision belongs to the utility, but it must be made knowingly and documented.

Engineering basis. Without the protection and control system in service, a fault on the feeder has no automatic means of clearance. The upstream 69/13.8 kV transformer protection will see the fault but will trip the whole substation, blacking out every customer, and the clearing time will be far longer than the feeder's own protection would achieve. Coordination with the hospital's downstream protection has not been demonstrated, so a hospital-side fault may not be cleared at all.

Conditions I would require before energisation:

1. A documented risk assessment signed by the utility's authorised manager, accepting the residual risk.
2. Temporary or interim protection in service - at minimum instantaneous and time-delayed overcurrent with tested settings, plus a functioning CB trip circuit and DC supply.
3. Verified CT ratios and polarity, and secondary injection test records for every device that will be in service.
4. Arc-flash labelling based on the as-energised configuration, and switching procedures with lockout/tagout.
5. A defined configuration boundary, so that no unauthorised work proceeds beyond the energised section.
6. A hold point and written sign-off from me before the breaker is closed.
7. An agreed programme for completing the full protection and control commissioning, with the interim measures removed at a defined date.

I would record all of this in the daily log and in a formal letter, so that the basis of the decision is contemporaneous.

Step 1 - Protect the notice position immediately. The contract requires written notice within 14 days of an event likely to delay completion. The switchgear vendor's six-week slip is such an event. Notice must be given now, in writing, describing the event, the expected effect and the fact that the notice is given without prejudice. Verbal assurances that the schedule is fixed do not displace the notice requirement, and missing the deadline may forfeit the extension of time regardless of the merits.

Step 2 - Build the factual record. Compile the vendor's notification, the purchase order and its delivery terms, correspondence, delivery expediting records, and a time impact analysis showing the delay on the critical path. Contemporaneous records are what decide these claims, not recollection a year later.

Step 3 - Characterise the instruction. A demand to accelerate is a change. If the utility wants the original completion date maintained despite an excusable delay, it is buying acceleration, and that cost belongs to it. The response is a formal variation request with a priced proposal - additional shifts, premium freight, extra supervision - for the utility to accept or reject. Complying silently and claiming afterwards invites the argument that the contractor absorbed the risk.

Step 4 - Avoid constructive acceleration. Do not simply mobilise additional resources on a verbal instruction and then claim. Either obtain a written instruction, or proceed under protest with a reserved right to claim, and keep the cost of acceleration separately coded so it can be substantiated.

Step 5 - Escalate appropriately. Route the matter through the contract's communication channel to the utility's authorised representative, not the project manager who gave the verbal direction, and propose a without-prejudice meeting to agree the extension of time and the early-energisation scope as a single package. Linking the two issues gives both parties something to trade.