By Francis Allan L. Angelo

The Institute of Contemporary Economics has urged local officials, regulators, and consumers to demand fuller explanations for the July 8, 2026 power interruptions in Iloilo, saying the day should be understood as a “reliability-chain event” spanning transmission, generation, reserves, and local distribution.

In a question-and-answer explainer, the Institute said the day began with an unscheduled interruption attributed to the National Grid Corporation of the Philippines (NGCP) and later escalated into a Visayas Grid Red Alert after available capacity fell below projected peak demand.

The first interruption occurred at around 1:32 to 1:33 p.m., when areas served by MORE Electric and Power Corporation’s (MORE Power) Diversion, Jaro, Mandurriao, Mobile, Molo, Megaworld, and Arevalo substations lost power.

MORE Power reported that the interruption was linked to no incoming voltage, that its initial assessment found no fault on its distribution lines, and that it was awaiting the official findings and communication of NGCP.

Power in the areas served by the affected substations was restored at 2:38 p.m., closing the first consumer-impact episode of the day.

At 2:50 p.m., NGCP declared a Visayas Grid Red Alert from 3 p.m. to 9 p.m. and a Yellow Alert from 1 p.m. to 3 p.m. and again from 9 p.m. to 11 p.m.

The advisory reported 2,397 megawatts (MW) of available capacity against 2,492 MW of projected peak demand, a projected shortfall of 95 MW during the Red Alert period.

NGCP also reported that 1,092.8 MW was unavailable to the Visayas Grid because of forced outages and derated plant capacities.

The grid operator identified two factors contributing to the Red Alert declaration: the tripping of the Iloilo–Panay Energy Development Corporation (PEDC) 138 kilovolt (kV) Line 3 at 1:32 p.m., which resulted in the isolation of PEDC Unit 3, and the emergency shutdown of Palm Concepcion Power Corporation (PCPC) at 2:06 p.m. due to a possible boiler tube leak.

Earlier information also referred to the tripping of the 69 kV Bus 1 and Bus 2 of Iloilo Substation, which the Institute said points to a transmission or substation-side event rather than a routine local distribution fault.

By mid-afternoon, the Red Alert reached consumers through Manual Load Dropping (MLD) implemented by NGCP and carried out through selected MORE Power feeders.

MORE Power’s notices show three confirmed MLD interruptions: La Paz Feeder 3 was offline from 3:42 p.m. to 5:48 p.m., or about two hours and six minutes; La Paz Feeder 1 from 4:19 p.m. to 6:08 p.m., or about one hour and 49 minutes; and La Paz Feeder 4 from 5:48 p.m. to 7:13 p.m., or about one hour and 25 minutes.

An earlier indicative MLD schedule identifying additional feeders did not fully materialize, and the confirmed curtailment was limited to the three La Paz feeders, all restored within or below the announced two-to-three-hour window.

By 7:13 p.m., MORE Power announced the complete restoration of all feeders affected by NGCP’s MLD and said power supply within its franchise area had normalized while it continued monitoring in coordination with NGCP.

The Institute said the unscheduled interruption and the MLD were not the same type of event, but stressed that the earlier transmission trip was not isolated from the wider grid condition because the PEDC line trip isolated PEDC Unit 3 and contributed to the Red Alert.

It said the public advisories identify immediate operational labels such as “no incoming voltage,” “tripping,” and “Manual Load Drop,” but do not yet explain cause, sequence, affected load, restoration action, and recurrence prevention.

The Institute listed several possible causes of the unscheduled interruption, including a line fault, substation fault, breaker operation, relay action, equipment problem, voltage disturbance, protection miscoordination, or another upstream abnormal condition, and said the event sequence is the most important technical question.

It noted that restoration in just over an hour was a positive operational sign but does not answer the root-cause question, since service could have been restored through re-energization, switching, isolation of the affected section, or backfeeding through alternate paths.

The Institute assessed MORE Power’s MLD implementation as orderly, saying it avoided immediate repeat curtailment of areas hit by the earlier interruption, used selected feeders to meet the required load reduction, and restored all feeders within the announced window.

It also said the first confirmed MLD feeders were outside the earlier outage footprint and that feeders with more sensitive facilities were not placed first where other options remained, calling this “a meaningful signal that the local distribution part of the system was being run with operational discipline and attention to equitable burden sharing.”

The serious failure, the Institute said, was that the wider grid condition deteriorated enough to require emergency load reduction in the first place.

The group urged local officials to seek a clear, non-sensitive incident account from NGCP, the Department of Energy (DOE), the Energy Regulatory Commission (ERC), and the concerned generation companies.

Among the questions it raised:

-what caused the PEDC 138 kV Line 3 to trip,

-why the trip isolated PEDC Unit 3,

-how much capacity was removed from the Visayas Grid,

-what role the PCPC shutdown played in the Red Alert,

-how much of the 1,092.8 MW of unavailable capacity came from forced outages and derations,

-whether sufficient reserves were available before the events,

-how much emergency load reduction NGCP required from MORE Power, and

-the total MW curtailed and megawatt-hours (MWh) not served within the franchise area.

Beyond questions, the Institute recommended that local governments convene a reliability briefing involving NGCP, MORE Power, ILECO I, hospitals, water utilities, large power users, cold-chain operators, ports, business groups, local disaster offices, and local economic offices.

It also called for a critical-load continuity map covering hospitals, water facilities, emergency operations centers, cold storage, public markets, schools used as evacuation centers, telecommunications facilities, ports, and major employment centers to guide backup-power planning and restoration-priority discussions.

For consumers, the Institute said the reasonable demand is a plain-language explanation of the cause, timely advisories, accurate restoration updates, and fair, disciplined, and time-bounded curtailment when emergency load reduction is required.

On when the region can expect reliable power, the Institute said there is no honest single-date answer, with incident reporting and continuity planning possible now, operational and coordination improvements expected within one to two years, and structural resilience such as major transmission corridors, substation upgrades, storage, and route diversity taking longer.

It identified four requirements for lasting reliability: root-cause discipline after every significant interruption, binding coordination backed by sufficient DOE legal tools and enforcement authority, deliverability of power rather than capacity on paper, and structural reinforcement.

The Institute said the Cebu–Negros–Panay (CNP) transmission backbone reduced Panay’s risk but did not complete resilience, citing the need for route diversity, downstream bottleneck removal, substation resilience, stronger local grid interfaces, better alignment between generation location and demand growth, and a serious review of the western Luzon–Mindoro–Panay gateway as a strategic reliability corridor.

After July 8, the Institute said, the public standard should be that advisories do not end with operational labels but provide cause, sequence, affected load, restoration action, corrective measure, and a timetable for reducing recurrence risk, with power reliability in Iloilo and Panay ultimately judged by delivered power under actual operating conditions.