In the year to mid-2025 the Malaysian state of Johor, a strip of land across the strait from Singapore, accumulated a data-centre pipeline of close to 5.8 gigawatts [4]. That is not energised load, but it is more prospective electricity demand than the peak load of many national systems. It is one province, in one ASEAN economy, and it is being built because Singapore had run into its own land, grid and carbon limits while Johor still offered room, power access and proximity. That single number captures the thing worth being optimistic about in Southeast Asian electricity: the demand is real, it is creditworthy, and it is arriving faster than almost anyone is ready for.
This is a brief about the opportunity, and it is a large one. Southeast Asia’s electricity demand is growing at around 4 percent a year, and grew more than 7 percent in 2024, close to double the global average [1][2]. The region holds roughly 20 terawatts of technical solar and wind potential against about 40 gigawatts installed, a resource it has barely begun to touch [2]. And in 2024 and 2025 the single-buyer model that had throttled private power for two decades finally began to crack in several of the region’s most important markets. The honest part of the story is the second half: the binding constraint has shifted from resource to grid, and from policy to money. Live market structure, third-party-access status, the interconnectors and their capacities sit on the Power Markets page [3], a structured market map built from public sources, with prices and grid carbon intensity on /data/electricity-costs/. The scenarios at the end are this analyst’s reading, not a forecast.
The demand is already here
Start with the pull, because it is unusually strong. The International Energy Agency puts Southeast Asia’s electricity demand above 1,300 terawatt-hours in 2024 and on track to exceed 2,000 by 2035 under stated policies, a rise of more than half in a decade [1]. The region accounts for over a quarter of the growth in global energy demand to 2035, second only to India, and on current trajectories its total energy demand overtakes the European Union’s around mid-century [1].
What is driving it is demographic before it is technological. Southeast Asia is young, fast-urbanising and growing richer, and that profile, mapped across the region on the demographics dashboard, is what converts into electricity demand. The largest single contributor is air conditioning, as incomes rise: cooling is set to climb from about 16 percent of buildings electricity toward 30 percent by 2035, and Indonesian air-conditioner ownership alone is projected to rise from under 15 percent of households to half [1]. Electric vehicles add to it, with EV shares of new car sales already near 15 percent in Vietnam and 10 percent in Thailand [1]. Manufacturing adds the industrial baseload. And data centres, the Johor story, add a dense, fast-growing block of demand that did not exist on this scale five years ago. Demand growth is the one thing the region does not have to engineer. It is already happening.
The buyers want clean electrons
The more interesting feature of the new demand is what it asks for. The data-centre boom and the manufacturing relocation out of China are not generic load. They are buyers with explicit preferences for power that is reliable, affordable, and increasingly low-carbon, and that combination is exactly what reorders an electricity market.
Take the scale first. Johor’s operational data-centre supply passed 1.6 gigawatts in 2024 and its aggregate capacity including the pipeline neared 5.8 gigawatts within a year [4]. In Malaysia as a whole, the utility TNB had signed electricity-supply agreements for 38 data-centre projects totalling 5.9 gigawatts of maximum demand by the end of 2024 [6]. Singapore, having frozen new data centres from 2019 to 2022, has reopened on its own terms: a managed green pipeline at home and up to 6 gigawatts of low-carbon electricity imports by 2035 [5]. Thailand approved a 2,000-megawatt direct-purchase pilot aimed squarely at data centres [14].
Behind the servers sits the manufacturing shift. Chinese greenfield manufacturing investment into ASEAN roughly doubled, from about 6.1 billion dollars in 2016 to 2019 to about 12.9 billion in 2020 to 2023, into Vietnamese electronics, Indonesian nickel and battery processing, and Malaysian semiconductor packaging [7]. These are power-hungry, outage-intolerant industries, and they increasingly answer to customers who price carbon. The buyers increasingly price the carbon behind the power. The hyperscalers building in Johor and the manufacturers relocating from China answer to their own customers’ Scope 2 targets, RE100 commitments and 24/7 clean-energy goals, none of which are EU-specific. For the narrower slice that exports CBAM-covered goods like steel and aluminium into Europe, there is also a hard border cost, the CBAM bill. Either way, the cost of carbon-intensive power is no longer only the tariff. It is a procurement risk and, increasingly, a lost contract.
This is where the opportunity meets the demographics. The workforce behind the relocation, and the consumers behind the demand, are the region’s demographic dividend, concentrated in Indonesia, the Philippines and Vietnam, the economies still in their working-age window. An earlier brief in this series argued that a young workforce is necessary but not sufficient: workers are not factories without the power, grid and logistics to employ them. Power is the converter. And the window is finite. Thailand and Singapore are already ageing, so the clean-power base has to be built while the workers and the demand are both still there. Grow the grid before the region grows old. That is what makes the clean-power question commercial rather than green, and it is why the reforms below matter for whether ASEAN captures the investment or watches it hesitate.
The resource is not the constraint
Here is the fact that should end any pessimism about supply. Southeast Asia sits on roughly 20 terawatts of technical solar and wind potential, around 55 times its entire current generating capacity of all kinds [2]. Solar module costs have fallen about 90 percent since 2010 [2]. The region is not short of renewable resource. It is short of the wires, the contracts, the storage and dispatchable flexibility, and the capital that turn resource into reliable electricity.
The specifics are striking. Indonesia holds about 23.7 gigawatts of geothermal potential, close to 40 percent of the world’s resource, of which under a tenth, about 2.3 gigawatts, is built [8]. Vietnam’s offshore wind technical potential is assessed by the World Bank at 599 gigawatts, against a base that is barely begun [9]. The Philippines, another deep-water archipelago, has 178 gigawatts of offshore wind technical potential and a roadmap for 21 gigawatts by 2040 [10]. Laos already exports hydropower to its neighbours and styles itself the battery of the region. Vietnam installed more than 16 gigawatts of solar in a few years, briefly making it a top-ten solar market globally [2]. The resource ranges from abundant to extraordinary. The question every time is whether the system can absorb and move it.
The unlock: prying open the single buyer
For two decades the answer was usually no, because in most of ASEAN one state utility bought all the power and decided what got built. That is the model this brief argues is finally changing, and the change is the most important positive development in the region’s power sector in years.
The instrument is third-party access, the right of a generator to use the incumbent’s wires to sell directly to a customer. It is the deeper reform, because a corporate clean-power contract is hollow if the seller cannot reach the buyer over the grid. In September 2024 Malaysia launched CRESS, its Corporate Renewable Energy Supply Scheme, the country’s first third-party-access framework, letting renewable generators pay a system charge to supply corporates directly [12]. Vietnam’s Decree 80 of July 2024, refined by Decree 57 of 2025, created two direct-power-purchase routes, private wire and grid-connected, that let large consumers bypass the single buyer [13]. Thailand launched its first Utility Green Tariff in January 2025 and approved the direct-purchase pilot for data centres [14]. Singapore is building its import framework. Malaysia, Vietnam and Thailand moved in the same direction inside eighteen months, and they moved because the data-centre and manufacturing buyers demanded it. Reform followed demand, which is the durable kind.
The status is uneven, and the Power Markets page tracks it country by country. The Philippines and Singapore have operational open-access frameworks. Malaysia, Vietnam and Thailand are opening, with the access still scoped or early. Indonesia, Laos, Myanmar and the smaller systems remain closed. But the direction is liberalising, even if it is not irreversible. The door opened for a hyperscaler can still be narrowed by access charges, eligibility rules and grid queues, yet it gets harder to shut once it is open.
The grid is the test
Now the realism. The reason resource abundance has not already become cheap clean power is the grid, and Vietnam is the cautionary tale. Between 2019 and 2021 it added roughly 20 gigawatts of solar and wind, faster than the transmission network could absorb, and the result was curtailment and stranded plants in the sunny, windy south while the industrial north ran short [18]. Building generation is quick. Building the wires to move it, and the market to balance it, is slow, and the gap between the two is where good projects go to die.
At the regional level the same problem has a hopeful name, the ASEAN Power Grid, and a sobering arithmetic. The vision is to wire the region’s mismatched resources, Lao and Vietnamese hydro, Indonesian geothermal and solar, Philippine wind, into a shared market. The reality is that only about 7.7 gigawatts of cross-border interconnection operates today, much of it dedicated dam-to-grid lines from Laos into Thailand rather than true grid-to-grid trade, and the masterplan calls for more than doubling interconnection by 2040 against a total investment estimate, on its own numbers, of about 764 billion dollars [11]. The genuine multilateral breakthrough, the Laos-Thailand-Malaysia-Singapore power integration project, moves up to 200 megawatts. It is a real first, and it is small. The interconnectors and their capacities, operating and planned, are mapped on the Power Markets page.
There is money behind it now. In October 2025 the Asian Development Bank and the World Bank launched the ASEAN Power Grid Financing Initiative, up to 12.5 billion dollars, to push the interconnection build [11]. That is a serious signal. It is also a down payment against a bill in the hundreds of billions, which brings us to the hardest part.
The money has to show up
The opportunity is large; the financing gap is larger. The IEA estimates Southeast Asia needs clean-energy investment above 190 billion dollars a year by 2035, roughly five times the current level, and grid investment of around 22 to 30 billion a year, roughly double [1]. Today the region attracts only about 2 percent of global clean-energy investment, and across the region capital still flows to fossil generation at a slightly higher rate than to clean [1]. The demand and the resource are world-class. The investment is not yet.
The flagship climate-finance vehicles show how hard mobilisation is. Indonesia’s Just Energy Transition Partnership was pledged at around 21.5 billion dollars in 2022; by 2025 only about 3.1 billion, near 14.5 percent, had been approved, and of the public tranche barely 1.5 percent was grant money rather than loans that add to emerging-market debt [15]. Vietnam’s 15.5-billion-dollar partnership moved slowly too: by early 2025 projects had been selected but disbursement had barely begun, and the first officially funded project only followed later in 2025 [16]. In March 2025 the United States withdrew from the partnerships entirely [17]. Meanwhile the region’s coal fleet, about 106 gigawatts and on average under 15 years old, is young enough that early retirement is expensive and politically fraught, and long take-or-pay contracts keep those plants running ahead of cheaper renewables [17]. None of this is fatal. All of it is friction, and friction at this scale is measured in years and percentage points of capital cost, where emerging-market grids and renewables already carry a high cost of capital and financing gaps on the order of 70 to 90 percent of national transition needs [19].
Three scenarios for 2026 to 2035
The framing below is this analyst’s reading of how demand, reform, grid and finance interact, not a quantitative forecast.
Scenario A: the unlock compounds. Third-party access widens from pilots to general rights, the data-centre and manufacturing buyers anchor bankable clean-power contracts, the ASEAN Power Grid financing crowds in private capital, and interconnection roughly doubles on schedule. ASEAN captures the bulk of the China-plus-one clean-manufacturing shift and becomes a structurally low-carbon, low-cost production base. Possible, and the upside is genuinely large, but it requires grid build-out and capital mobilisation to move faster than either has yet shown.
Scenario B: a two-speed region. The reformers pull ahead. Malaysia, Vietnam and Singapore turn corporate demand into clean build-out and interconnection, while Indonesia’s coal lock-in and the smaller single-buyer systems lag, their cheap subsidised power masking the deferred cost. The opportunity is captured in parts, by the markets that opened, and missed in others. This analyst’s base case, because it is what the 2024 to 2026 evidence already shows.
Scenario C: lock-in holds. Reform stays scoped to pilots, the grid keeps lagging generation, climate finance stays slow and loan-heavy, and surging demand is met the fast way, with coal and gas, because that is what a single buyer with take-or-pay contracts builds. The resource stays in the ground, the manufacturing investment hedges toward more reliable grids, and CBAM-exposed exporters pay the carbon bill. Less likely than B given the reform momentum, but the coal fleet and the financing gap keep it firmly on the table.
Implications
For manufacturers and data-centre operators siting in ASEAN: the clean-power question is now a location question. Where open access is operational, as in the Philippines and Singapore, or newly opening, as in Malaysia and Vietnam, you have a route to contract for the electrons your customers and the EU’s carbon border will demand. Where that route is absent or still a narrow pilot, you are betting on a single buyer’s plan.
For investors and financiers: the binding constraint is grid and balance-sheet, not resource. The returns sit in transmission, storage, and the contractual plumbing of third-party access, not only in generation, where the resource is so abundant that it is close to commoditised.
For global buyers and their suppliers: ASEAN’s grid carbon intensity is becoming an embedded cost in your supply chain, whether through customer clean-energy targets or, for CBAM-covered goods into Europe, a border charge. It is about to diverge sharply between the reforming markets and the locked-in ones. Source accordingly, and watch /data/electricity-costs/.
For ASEAN policymakers: the demand and the resource have done their part. The decade will be decided by whether the wires get built and the capital shows up, and by how quickly third-party access stops being a pilot and becomes a right. The region has been handed one of the best clean-growth setups in the world. It is now an execution problem, which is a far better problem to have than a resource one.
Building the clean-power base is necessary but not sufficient. The deeper test is what the region does with the electricity: whether it can automate and lift productivity fast enough to stay rich as its workforce ages. That race, automation against the demographic clock, is where this series turns next.
References
[1] International Energy Agency, Southeast Asia Energy Outlook 2024. Electricity demand above 1,300 TWh in 2024 rising past 2,000 TWh by 2035; ~4%/yr growth; cooling, EV and data-centre drivers; region as >25% of global energy-demand growth to 2035; clean-energy investment need above USD 190 bn/yr and grid investment of ~USD 22–30 bn/yr by 2035. https://www.iea.org/reports/southeast-asia-energy-outlook-2024 [2] IEA, Integrating Solar and Wind in Southeast Asia (22 September 2025). ~20 TW solar and wind technical potential against ~40 GW installed; 2024 demand growth above 7%; solar costs down ~90% since 2010. https://www.iea.org/reports/integrating-solar-and-wind-in-southeast-asia [3] A1AYN, Power Markets and Electricity Costs layers. Market structure, third-party-access status, interconnectors and capacities; industrial prices and grid carbon intensity. Compiles public-source material into A1AYN’s structured market map, not an official regulatory database. https://a1ayn.com/data/power-markets/ [4] DC Byte; White & Case, Malaysia data-centre analysis (2025). Johor operational data-centre supply above 1.6 GW in 2024 and aggregate capacity near 5.8 GW including pipeline by 2025. https://www.whitecase.com/insight-our-thinking/what-propelling-malaysias-data-centre-boom [5] Energy Market Authority (Singapore). Up to 6 GW of low-carbon electricity imports by 2035; managed green data-centre pipeline after the 2019–2022 moratorium. https://www.ema.gov.sg/our-energy-story/energy-supply/regional-power-grids [6] TNB; Malaysian Investment Development Authority (MIDA). Electricity-supply agreements for 38 data-centre projects totalling 5.9 GW of maximum demand by end-2024. https://www.mida.gov.my/mida-news/malaysias-data-centre-boom-johor-emerges-as-a-regional-powerhouse/ [7] Rhodium Group; Asia Society Policy Institute. Chinese greenfield manufacturing FDI into ASEAN roughly doubled from ~USD 6.1 bn (2016–19) to ~USD 12.9 bn (2020–23). https://cbm.rhg.com/research-note/chinas-manufacturing-fdi-asean-grew-rapidly-faces-tariff-headwinds [8] ASEAN Briefing, Indonesia geothermal overview (2024). ~23.7 GW geothermal potential (~40% of the world resource), ~2.3 GW installed (<10% of potential). https://www.aseanbriefing.com/news/an-overview-of-indonesias-geothermal-energy-sector/ [9] World Bank / ESMAP, Offshore Wind Roadmap for Vietnam (2021). Vietnam offshore wind technical potential assessed at 599 GW. https://documents1.worldbank.org/curated/en/261981623120856300/pdf/Offshore-Wind-Development-Program-Offshore-Wind-Roadmap-for-Vietnam.pdf [10] World Bank, Offshore Wind Roadmap for the Philippines (2022). 178 GW technical potential; potential for 21 GW by 2040. https://www.worldbank.org/en/news/press-release/2022/04/20/new-roadmap-shows-potential-for-21gw-of-offshore-wind-by-2040-in-the-philippines [11] ASEAN Centre for Energy; ADB; World Bank. ASEAN Power Grid Financing Initiative of up to USD 12.5 bn (launched 15 Oct 2025); ~7.7 GW operating interconnection, to more than double by 2040; AIMS III investment estimate ~USD 764 bn; fully connected grid targeted by 2045. https://aseanenergy.org/press-release/adb-and-world-bank-group-launch-the-asean-power-grid-financing-initiative-with-the-asean-secretariat-and-the-asean-centre-for-energy-ace [12] Energy Commission (Malaysia); Rajah & Tann; Global Compliance News. CRESS (Corporate Renewable Energy Supply Scheme), Malaysia’s first third-party-access framework, applications from 30 September 2024. https://www.globalcompliancenews.com/2024/08/14/malaysia-introduction-of-the-corporate-renewable-energy-supply-scheme-cress/ [13] Government of Vietnam, Decree 80/2024/ND-CP (3 July 2024); Decree 57/2025; Vietnam Briefing. Direct power purchase agreements via private wire and via the grid for large consumers. https://www.vietnam-briefing.com/news/vietnam-notifies-decree-80-2024-nd-cp-on-direct-power-purchase-agreements-key-details.html/ [14] Thailand: ERC Utility Green Tariff (Nishimura & Asahi, Jan 2025); NEPC direct-PPA pilot (Hunton). First Utility Green Tariff launched 23 January 2025; 2,000 MW direct-purchase pilot for data centres approved 25 June 2024. https://www.hunton.com/insights/legal/thailands-draft-regulation-on-direct-power-purchase-agreements-via-third-party-access-for-data-centers [15] IEEFA, Indonesia JETP analysis (February 2026); Jakarta Globe. Pledged ~USD 21.5 bn; ~USD 3.1 bn (~14.5%) approved by 2025; of the public tranche only ~1.5% grant. https://ieefa.org/resources/building-credibility-indonesias-energy-transition-insights-etm-and-jetp-indonesia [16] Wilson Center, Vietnam JETP (2025). USD 15.5 bn pledged; projects selected by early 2025 with disbursement only beginning later in the year. https://www.wilsoncenter.org/article/whats-next-vietnams-just-energy-transition-partnership [17] CSIS, clean energy and decarbonization in Southeast Asia (2025); IEA, Southeast Asia Energy Outlook 2024. SEA coal fleet ~106 GW, average age under 15 years (IEA and CSIS); single-buyer dominance; US exit from the Just Energy Transition Partnerships, March 2025 (CSIS). https://www.csis.org/analysis/clean-energy-and-decarbonization-southeast-asia-overview-obstacles-and-opportunities [18] TransitionZero, Southeast Asia power-grid connectivity (2024). ~20 GW of solar and wind added in Vietnam in 2019–2021 ahead of grid capacity, causing curtailment in the south. https://www.transitionzero.org/insights/southeast-asia-power-grid-connectivity-challenges [19] World Resources Institute, industrial-decarbonization finance, Indonesia and Vietnam (2025). Financing gaps and emerging-market cost of capital for grid and renewable build-out. https://www.wri.org/technical-perspectives/industrial-decarbonization-finance-indonesia-vietnam
Demand, investment and resource figures are IEA, World Bank and ASEAN Centre for Energy estimates, with scenario ranges where the underlying sources differ; data-centre pipeline figures are announced and under-construction capacity, not energised load. Market-structure, third-party-access and interconnector data are A1AYN’s curated Power Markets layer; prices and grid carbon intensity are the Electricity Costs layer. Current as of June 2026.