Southeast Asia's Waste-to-Energy Bet Comes Down to Who Pays the Tipping Fee

Presidential Regulation 35 of 2018 named twelve Indonesian cities and told each of them to build a waste-to-energy plant. By the start of 2025, seven years on, two were running: Benowo in Surabaya and Putri Cempo in Surakarta. Jakarta, the city that generates more municipal waste than anywhere else in the country, had started and abandoned six separate project attempts. I've spent the last few years advising regional market entries across Asia, after commissioning plants of my own in the Americas, and Indonesia's record is the cleanest illustration I know of something developers keep getting wrong about waste-to-energy in Southeast Asia. It almost never fails on the technology. It fails on who pays.

That sounds like a small distinction. It isn't. A mass-burn line from Hitachi Zosen, or a Martin reverse-acting grate under a B&W boiler, behaves the same in Surabaya as it does in Switzerland — the combustion engineering behind these waste conversion facilities crossed the equator decades ago. What doesn't travel is the cash flow. A WTE plant runs on two revenue streams: the tipping fee a city pays to hand over its waste, and the electricity the plant sells to the grid. In this region, the question of which government entity is contractually on the hook for each one has killed more projects than any boiler ever has. Indonesia just rewrote that contract. Vietnam wrote a different one a decade ago. The Philippines still hasn't decided whether the plant is legal to switch on. Three countries, three answers, and the technology is the least interesting variable in all of them.

Indonesia Moved the Money, Not the Technology

Under PR 35/2018 the deal looked reasonable on paper. A developer would collect a feed-in tariff from the state utility PLN — roughly $0.1335/kWh for plants at or below 20 MW, and a little more above that — plus a tipping fee from the local government, capped through central subsidy at IDR 500,000 per tonne, about USD 30, per Ashurst's analysis of the framework. Two revenue streams, two counterparties. And there's the trap. The tipping fee sat inside a municipal budget, and a municipal budget in Indonesia is an annual political negotiation, not a 20-year guarantee a project-finance lender will accept as security. So lenders priced that risk the only way they could: they declined to lend. Most of the Jakarta attempts died somewhere between feasibility and financial close, on a combination of land acquisition and exactly this financing gap.

PR 109 of 2025 took the municipal budget out of the structure entirely. Every WTE project now signs a single offtake agreement with PLN at a flat $0.20/kWh, fixed for 30 years, with no escalation and no separate tipping fee at all. One creditworthy counterparty, one contract, one number a lender can underwrite. The eligibility floor is set at 1,000 tonnes of waste per day, and the first wave of registrations targets ten municipalities. The demand side was never in question — Indonesia generates roughly 56.6 million tonnes of waste a year, around 61% of it openly dumped or otherwise unmanaged, with major landfills projected to reach capacity by 2030, per the same Ashurst review.

Notice what didn't change. No new technology was mandated. No combustion breakthrough arrived between 2018 and 2025. The regulator simply moved the payment obligation off a body lenders distrust and onto one they'll bank. That is the whole reform. I'd put it more bluntly than the law firms will: feasibility is mostly figuring out which assumption will move, and in Indonesia the assumption that moved was the identity of the payer. Whether $0.20/kWh is the right number is a separate argument — it's high by regional standards, and a flat rate that ignores plant size will overpay large facilities while possibly still underpaying small ones. But for the first time the cash flow is legible, and for a lender that's worth more than another five points of boiler efficiency.

I have killed a project for the absence of exactly this. On a Bogotá feasibility study in 2021 we reached the offtake stage and could not find a creditworthy buyer willing to pay the per-kWh price the plant needed to service its debt, so we killed it ourselves rather than carry it to financial close and discover the hole later. That isn't a failure. That's feasibility doing its job. If the offtake math doesn't close, you kill it at feasibility, not at financial close, and certainly not three years into operations. I've written before about why waste projects stall in Latin America, and the pattern under Indonesia's old framework was identical: developers were asked to sign anyway and hope the municipal line item held. PR 109 stops asking them to hope.

Vietnam Built the Plants. The Grid Is the Open Question.

Vietnam did almost the opposite, and earlier. A 2014 support decision set a national feed-in tariff for waste-to-energy of about 10.05 US cents/kWh ($0.1005/kWh) for solid-waste incineration projects, per the IEA policy database — lower than Indonesia's new number, but it existed, it was national, and it was stable enough to build against. And Vietnam now operates the plant that proves the point. The Soc Son facility outside Hanoi, run by Thien Y Environmental Energy, takes in roughly 5,000 tonnes of municipal waste a day across furnace lines rated near 1,000 tonnes each and generates about 90 MW, per Vietnamese trade reporting. It's the largest WTE plant in the country and, by capacity, among the largest anywhere in the world. Fifteen more WTE plants are under construction nationwide, by the same reporting, and three are already exporting power to the grid.

So Vietnam's waste management story reads as a success next to Indonesia's, and in pure build-out terms it is. But — and this is the part regional entrants underweight — the rules underneath those numbers are moving. Vietnam is winding down the fixed feed-in tariff model across its entire renewables sector. Decree 57 of 2025 expanded direct power purchase agreements, where a generator contracts with a large industrial consumer instead of selling to the utility, and the country is shifting toward a negotiated two-component tariff — a capacity payment plus an energy payment — with a ceiling rate set by the Ministry of Industry and Trade. The revised Power Development Plan VIII targets somewhere between 1,441 and 2,137 MW of WTE capacity by 2030. The ambition is real, but the price mechanism that pays for it is, as of 2026, still being drafted.

Here's where I slow a client down. A plant commissioned in 2020 against a 2014 feed-in tariff has a known revenue line for its whole debt term. A plant reaching financial close in 2026 is being asked to underwrite against a tariff regime that doesn't fully exist yet. That's a different risk, and not one the combustion technology can touch. It also doesn't sit evenly across the country. A 90 MW plant outside Hanoi with industrial offtakers in range is a very different proposition from a 300-tonne-per-day plant in a provincial city with a weak grid connection and no DPPA-eligible buyer nearby. Below roughly 500 tonnes a day, almost everywhere in this region, the per-tonne economics turn hard regardless of the tariff, because capital cost per installed kW does not fall the way the brochure curve promises. Wet, high-organic, poorly segregated feedstock — the Southeast Asian norm — pushes the calorific value down and pushes that break-even the wrong way.

And the assumptions you don't examine are the ones that bill you. On the Monterrey MSW-to-energy project I developed between 2017 and 2020, I assumed the diesel backup generator would never run more hours than the OEM warranty modelled, because grid outages would be rare. In 2018, its first full operating year, that generator ran 380 hours and overran its fuel-and-warranty budget by about USD 74,000 — grid stability turned out to be meaningfully worse than the utility's own published data had claimed. A small line against a whole plant budget, but it taught me to read the grid-reliability data twice and then assume it's optimistic. In Vietnam's weaker provincial grids, that single lesson is most of the feasibility.

The Philippines Hasn't Decided If It's Legal

Then there's the market where the technology question genuinely doesn't matter yet, because the legal one isn't settled. The Philippines carries two laws in tension. Republic Act 9003, the Ecological Solid Waste Management Act of 2000, permits the conversion of waste to energy; Republic Act 8749, the Clean Air Act of 1999, prohibits the incineration of municipal, biomedical and hazardous waste. Read together, they leave a genuine ambiguity. Depending on which lawyer you ask, and which Department of Environment and Natural Resources administrative order is current, a mass-burn Philippines waste-to-energy plant is either permitted under strict emission certification or flatly unlawful.

That ambiguity is not abstract. Quezon City has spent years pursuing a facility to convert up to 3,000 tonnes per day of municipal waste into roughly 36 MW of net electricity, and has lobbied for amendments to both statutes to lift the incineration ban. It has met organised, sustained resistance.

More than fifty civil society organisations, convened by the Global Alliance for Incinerator Alternatives, have publicly urged the government to abandon moves to repeal the incineration ban and to stop promoting waste-to-energy incineration facilities — arguing the technology undercuts segregation, recycling and the country's existing solid-waste law.

I'm not going to adjudicate that fight here, and I don't think a trade column should. My point is narrower, and it's strictly a project-development point. A plant whose legal basis can be reversed by a court ruling, a fresh DENR order, or a change of national administration is not financeable on the terms an institutional investor will accept — not on the same terms as a plant in Indonesia holding a 30-year PLN contract. The political and legal risk sits upstream of everything an engineer controls. You can specify the cleanest flue-gas train in the region — SNCR for NOx, a bag-filter and activated-carbon line for dioxins and mercury, continuous emissions monitoring to match anything in the EU — and none of it changes whether a future Philippine government will let you run the plant. The right time to walk away from a contractor is the first time they ask you to relax a spec. The right time to be most careful is when the spec is fine and the law itself is the variable.

This is also where the urban waste recovery argument gets stuck. Metro Manila has the waste, it has the population density, and on paper it's an obvious candidate for energy recovery. What it doesn't have is a settled answer to whether recovery-by-combustion is allowed at all, and no feed-in tariff, however generous, prices around that.

So when a client asks whether Southeast Asia is a single waste-to-energy opportunity, my answer is that it's three opportunities with three completely different shapes, and the boiler is roughly the same in all three. Indonesia has made the cash flow legible, and the next 24 months will show whether ten municipalities can actually reach financial close on the new terms — registration being open is not the same as money being spent. Vietnam has the plants, the demand, and a tariff regime in mid-rewrite. In the Philippines, engineered and financeable-on-paper facilities sit idle behind a legal question nobody in Manila will answer cleanly. Waste-to-energy belongs inside a wider set of circular economy solutions, but in each of these markets it lives or dies on contract structure, not on conversion chemistry.

The Quezon City plant is, by most accounts, fully designed. The contractors are available. The waste is certainly there — 3,000 tonnes of it a day, going to landfill while the plant waits. The only missing input is a sentence of law. I've commissioned plants where the hard part was the feedstock, plants where it was the grid, and one where it was a backup generator I'd been sure I would never run. I've never commissioned one where the hard part was whether switching it on counted as a crime. Which leaves the question every developer eyeing this region should sit with before spending a dollar on feasibility: when the binding constraint is a law that hasn't been written yet, what exactly are you being paid to take the risk on?

Sources & Notes

1. Ashurst, "Accelerating Waste-to-Energy in Indonesia: PR 109/2025's Impact and Challenges" (2025) — basis for the PR 35/2018 feed-in tariff (USD 0.1335/kWh at or below 20 MW), the IDR 500,000/tonne tipping-fee cap, PR 109/2025's flat USD 0.20/kWh 30-year PLN offtake, the 1,000 t/day eligibility floor, the 56.6 Mt/yr waste figure and the ~61% unmanaged share. https://www.ashurst.com/en/insights/accelerating-waste-to-energy-in-indonesia-presidential-regulation-109-2025/
2. IEA Policies database, "Decision on support mechanisms for the development of waste-to-energy power projects in Vietnam (feed-in tariff)" — basis for the ~10.05 US cents/kWh WTE incineration tariff set by Vietnam's 2014 support decision. https://www.iea.org/policies/5705-decision-on-support-mechanisms-for-the-development-of-waste-to-energy-power-projects-in-vietnam-feed-in-tariff
3. Vietnam Law Magazine, "Waste-to-energy projects need to be accelerated to address environmental pollution" — operator data for the Soc Son plant (≈5,000 t/day intake, ≈90 MW, ~1,000-tonne furnace lines) and the count of 15 WTE plants under construction. https://vietnamlawmagazine.vn/waste-to-energy-projects-need-to-be-accelerated-to-address-environmental-pollution-72113.html
4. Global Recycling, "Philippines' Waste and the Ban of Incineration" — regulatory basis for the RA 9003 / RA 8749 tension and the Quezon City 3,000 t/day to 36 MW proposal. https://global-recycling.info/archives/5534
5. Global Alliance for Incinerator Alternatives (GAIA), "Civil Society Coalition Slams Moves to Repeal Incineration Ban and Promote WtE" — source for the civil-society opposition cited in the blockquote. https://www.no-burn.org/civil-society-coalition-slams-moves-to-repeal-incineration-ban-and-promote-wte/