Malaysia
Gas goes out as LNG. The domestic power price comes from a regulator, not a curve: one buyer, one grid, and a fuel-cost formula where a spot market would be.
Overview
Malaysia has a wholesale electricity sector with no wholesale electricity market. Every megawatt-hour in Peninsular Malaysia is contracted to, dispatched by and settled through the same counterparty, the Single Buyer. What the consumer pays is decided by a regulator on a three-year cycle.
No market on this site is more administered, and that is the design, not an accident. Malaysia produces a lot of gas and has exported LNG for decades. Day to day, none of that shows up in the domestic power price. Fuel reaches the power sector at regulated prices, and the gap between those prices and the market cost gets carried by a formula. Nobody trades it.
Three bodies matter. Tenaga Nasional Berhad (TNB) owns the Peninsular grid and most of the distribution and retail business. The Single Buyer, ring-fenced inside TNB, plans capacity, runs procurement and dispatches the system. The Energy Commission — Suruhanjaya Tenaga — sets the revenue TNB is allowed to earn and the tariff consumers pay, under an Incentive-Based Regulation framework now in its fourth regulatory period.
Sabah and Sarawak are separate. Sarawak runs its own utility, its own regulator and, since 2025, its own gas aggregator. A different market inside the same country.
There is no spot power price to trade here. The exposure is regulatory: allowed revenue for the period, the fuel-cost pass-through formula, and what comes out of the capacity tenders. You are taking a view on a policy decision. Merit-order economics will not help you.
Market structure
One buyer, one grid owner, one regulator. Then two systems in East Malaysia that share none of that machinery and answer to different people.
Who does what
| Function | Body | Role |
|---|---|---|
| Regulator | Energy Commission (Suruhanjaya Tenaga) | Licensing, allowed revenue, tariff setting for Peninsular Malaysia and Sabah |
| Single Buyer | Ring-fenced unit within TNB | Capacity planning, procurement, scheduling and dispatch |
| Grid and retail | Tenaga Nasional Berhad | Transmission, distribution and the great majority of retail supply |
| Generation | TNB Power Generation and IPPs | Sell under long-term power purchase agreements, not into a market |
| Sarawak | Sarawak Energy Berhad | Vertically integrated state utility under state jurisdiction |
| Sabah | Sabah Electricity | Separate grid, separate tariff schedule |
The single-buyer model in practice
Independent power producers never compete for load. They compete once, at tender, for a power purchase agreement running twenty years or more. Payment usually splits into a capacity charge for being available and an energy charge that passes fuel through at cost. After signature, how the system actually runs barely touches the plant's revenue.
New capacity goes out to competitive bidding, run by the Single Buyer under Energy Commission oversight. That is where price discovery lives. A tender result for a combined-cycle plant or a large-scale solar tranche is as close to a forward curve as this market gets.
Cracks in the monopoly
Two mechanisms move power outside the single-buyer channel. NEDA, the New Enhanced Dispatch Arrangement, lets merchant and contracted plants bid energy for economic dispatch: a merit order running inside a contracted system. The Corporate Renewable Energy Supply Scheme (CRESS), opened in 2024, goes further: it grants third-party access to the grid so a renewable developer can sell directly to a high- or medium-voltage consumer, paying a regulated System Access Charge to the Single Buyer for use of the network. Projects must be at least 30 MW with a direct grid connection, and the access charge is fixed for three years with revisions capped at 15% between periods.
CRESS is small. It is also the first regulated third-party access to the Malaysian grid. Watch the System Access Charge. That toll decides whether bilateral supply pays, and a regulator sets it, not scarcity.
Infrastructure — power and gas
Three power systems, none of them wired to each other. On the gas side the Peninsula has been formally opened to third parties, while East Malaysia goes its own way.
Power
Peninsular Malaysia
The main system: TNB-owned transmission, dispatched by the Single Buyer, supplied by TNB plant and a fleet of contracted IPPs. Interconnected to Thailand and to Singapore.
Sarawak
Hydro-dominated and separately governed. Bakun alone is 2,400 MW installed, with Baleh adding a further 1,285 MW under construction.
Sabah
The smallest and weakest of the three, mostly gas and diesel fired, with no interconnection to the Peninsula.
Gas
The Peninsular gas system sits on the Peninsular Gas Utilisation pipeline, a 1,690 km trunk line with laterals and liquids pipelines hanging off it, plus two regasification terminals, PETRONAS Gas Berhad's terminals at Sungai Udang in Melaka and Pengerang in Johor. All three are regulated assets under third-party access, with published tariffs. For the regulatory period running January 2026 to December 2028 the approved base tariffs are RM1.196/GJ/day for PGU transportation and RM3.542 and RM3.142/GJ/day for regasification at Sungai Udang and Pengerang respectively.
A published, non-discriminatory tariff is what makes gas structurally more open here than power. A third-party shipper can land a cargo, regasify it and move it to a Peninsular customer at a cost he can work out in advance. Power has no equivalent toll available for general use.
Schematic — system topology, not a geographic map. Generation on the Peninsula contracts to the Single Buyer, which dispatches and passes energy to the TNB network. CRESS supply bypasses the contracting chain but still pays the regulated access charge. Sarawak and Sabah sit outside the arrangement entirely.
Demand and supply
Coal carries the base and gas does the flexing. The hydro is almost all in Sarawak, where the Peninsula cannot reach it. Solar is still a rounding error after a decade of tenders.
Demand
Demand is growing, not flat. Industrialisation, cooling load and a fast data centre build-out in Johor and Selangor all pull the same way. Under a single-buyer model that growth has to be met by contracting capacity years ahead. No price is allowed to rise and pull supply in.
Supply
For a gas-producing country the mix reads oddly. Coal supplies more electricity than gas. A molecule is worth more shipped as LNG than burned at home, and the coal fleet exists to keep the domestic tariff away from that opportunity cost.
Shares for 2025. Source: Low Carbon Power, corroborated by Ember, which puts low-carbon generation at 21% and solar and wind combined at 2%.
| Indicator | Direction | Comment |
|---|---|---|
| Electricity demand | Rising | Industry, cooling load and data centre connections |
| Coal generation | Structurally dominant | Largest single source at 45% of 2025 output |
| Gas generation | Second, and policy-driven | Competes with the export value of LNG |
| Hydro | Rising, but East Malaysian | Baleh adds 1,285 MW to a system the Peninsula cannot reach |
| Solar | Rising from a very low base | Still around 2% of generation despite repeated tender rounds |
Malaysia exports LNG and takes the price consequences only at one remove. Gas reaches generators at administered prices, so a rally in Asian LNG lifts the export value without moving the domestic tariff that month. The bill turns up later, through the fuel pass-through formula and, in the end, through the government's subsidy account.
Price setting mechanism
Nothing clears. The tariff is calculated, approved, then adjusted by formula. What you model here is a regulatory decision, not a supply curve.
Incentive-Based Regulation
Since 2014 the Energy Commission has set TNB's allowed revenue over multi-year periods under an Incentive-Based Regulation framework. It approves a forecast of efficient operating and capital costs, a permitted return, and the demand base those costs are spread across. The base tariff then holds for the period. Beat the allowance and TNB keeps the difference; miss it and TNB wears it.
RP4 runs from 2025 to 2027. The revised RP4 schedule took effect on 1 July 2025 and raised the average base tariff to 45.40 sen/kWh from 39.95 sen/kWh, an increase of 13.64%. Just as importantly, the bill was restructured: consumers now see separate energy, capacity, network and retail charges rather than a single blended rate, and time-of-use pricing was extended to domestic customers.
From ICPT to AFA
The base tariff is only a starting point. Fuel costs move faster than a three-year settlement, so a pass-through sits on top. The old Imbalance Cost Pass-Through (ICPT) reconciled actual against benchmark fuel costs every six months and spat out a rebate or a surcharge. From 1 July 2025 the Automatic Fuel Adjustment (AFA) took over, which does the same job monthly rather than half-yearly against prevailing fuel prices and the exchange rate, with movements beyond 3 sen/kWh requiring government approval.
Six-monthly reconciliation let balances build up, and every ICPT announcement became a political event. Monthly adjustment keeps the balance small and shortens the lag between a coal or LNG move and the consumer bill. It also makes the pass-through mechanical rather than discretionary, which is the part that matters if you are pricing Malaysian utility credit or industrial power cost.
Where competition does set price
Two Malaysian prices are genuinely discovered by competition. One is the winning bid in a capacity tender, gas-fired or solar, which fixes an offtake price for decades. The other is the regulated third-party toll: gas transport and regasification tariffs, and the CRESS System Access Charge. Neither is a spot price. Both are published, both are contestable, and both decide whether a project works.
Regulatory regime
Federal law governs the Peninsula and Sabah. Sarawak governs itself. Which regime applies is the first question in any Malaysian energy transaction, and it is not always obvious.
| Body | Remit |
|---|---|
| Energy Commission (Suruhanjaya Tenaga) | Economic and technical regulation of electricity and piped gas in Peninsular Malaysia and Sabah |
| Ministry of Energy Transition and Water Transformation (PETRA) | Energy policy, transition targets and subsidy direction |
| Single Buyer | Procurement, planning and dispatch under Energy Commission oversight |
| PETRONAS | Custodian of national petroleum resources; upstream licensing and LNG export |
| Sarawak state authorities and PETROS | Electricity regulation and gas aggregation within Sarawak |
Gas market opening
The gas reform is real, and bounded. Amendments to the Gas Supply Act set up a licensed third-party access regime over the Peninsular transmission and regasification assets, so a shipper who is not PETRONAS can contract capacity at published tariffs. What was not deregulated is the price of gas delivered to power generation. That is still administered. So for a trader, access is a solved problem and the molecule price is not.
Subsidy reform is the live risk
Malaysian energy subsidies are large. They cover fuel, gas to the power sector and, in effect, the electricity tariff itself, and they are being unwound slowly. The RP4 tariff increase and the move to monthly AFA both push more of the real cost onto consumers. Every further step is a fiscal decision taken against a political constraint, and it lands as an announcement rather than as a price move. Take a view on Malaysian power costs and you have taken a view on the pace of that unwind.
The Sarawak divergence
Sarawak has asserted jurisdiction over its own gas distribution, with PETROS confirmed as sole gas aggregator in the state from 2025. Nothing structural in Malaysian energy has moved further in a decade. There are now two gas counterparties in one country, and contracts, licences and regulatory recourse in Sarawak are different instruments from the Peninsular versions.
Before you price anything Malaysian, work out which system it sits in: Peninsular, Sabah or Sarawak. Tariff, regulator, counterparty and gas supplier all differ. And there is no wire between them.
Key links
Primary sources for this market. Figures on this page are drawn from these and from published market data.