You sell at ₱6. You buy back at ₱14. That's not a market — that's a tax.

The asymmetry, in one diagram

For the same one kilowatt-hour of solar production, net-metering gives you ₱6 of credit and zero-export gives you ₱14 of avoided cost. That is a ₱8 per kWh difference, every day, for every kilowatt-hour your panels produce that you would otherwise have exported. Across a 50 kWp commercial array producing ~200 kWh/day with 40% midday export, the gap is roughly ₱640/day, or ₱234,000/year — just from the export-vs-keep architectural choice, before any other configuration variable.

Side by side

Why net-metering looks attractive on paper (and isn't)

Most solar installers in the Philippines still lead with net-metering because it removes the need for battery storage from the proposal — bringing the headline capex down. The customer-facing pitch reads: "Your meter runs backward when you generate more than you consume." Which is true. What the pitch usually omits is the price at which the meter runs backward.

The Blended Generation Charge — the rate the utility credits you for exported solar — is a wholesale, time-averaged generation cost. It is not the retail rate. When the BGC was set, the idea was that distributed generators (you) should be compensated at the same rate as utility-scale generators. In practice this works as a transfer from the rooftop solar owner to the utility's distribution infrastructure: they take your midday energy at ₱6 and sell you the same energy back at ₱14 four hours later.

The asymmetry is also stable in the wrong direction. As the grid takes on more rooftop solar over the next decade, the BGC at midday is likely to fall (more supply, fewer evening peakers needed during the day). The retail rate is unlikely to fall at the same rate. The export-import gap is structurally widening.

What changed in April 2026 (and what didn't)

In April 2026, the Department of Energy raised the commercial net-metering cap from 100 kW to 1 MW. This was widely reported as a major reform. It is — for sites whose midday consumption naturally matches midday solar production. For everyone else, it makes the asymmetry larger, not smaller, because the customer can now build a 10× larger array and export 10× more energy at the BGC rate.

What did not change: the export rate is still BGC, the import rate is still retail, and the gap is still ~60%. The cap reform is good for sites with high daytime air-conditioning or refrigeration load (data centres, cold storage with daytime defrost, food manufacturing on day shift). For 24h operations, evening-shift industrial sites, hotels, hospitals, bakeries with night production, and most commercial real estate — the cap is irrelevant because zero-export with storage already produces a better return.

What this looks like over 15 years

Take a 50 kWp commercial rooftop array — modest by 2026 standards, suitable for a mid-size hotel or food plant. Average production: 73 MWh/year in the Philippines. Two scenarios over a 15-year asset life:

• Net-metering, 50% export: 36.5 MWh exported at ₱6 = ₱219K credit/year. 36.5 MWh self-consumed at ₱14 = ₱511K avoided cost/year. Total annual benefit: ₱730K. Over 15 years: ~₱11M.
• Zero-export iVOLT, 0% export, battery shifts ~30% to evening: All 73 MWh self-consumed at ₱14 = ₱1,022K avoided cost/year. Over 15 years: ~₱15.3M.

The zero-export configuration delivers ~₱4.3M more over the asset life on the same panels, from the same production, on the same site. The incremental capex for the battery and Karnot inverter typically pays back in 3–5 years on this delta alone — and earlier if the battery also shaves demand charge (which it does — see our 15-minute rule piece).