The Oil & Gas Industry in Malaysia

Every barrel of oil and every cubic foot of gas beneath Malaysian soil and seabed belongs, by law, to a single company. Not the state directly, not the fields’ discoverers, not the multinationals that drill them — but PETRONAS, the national oil company created to hold the nation’s petroleum in trust. Understand that one fact and the rest of Malaysia’s oil and gas industry — how it is regulated, financed, taxed and shared — falls into place.

This guide walks through the whole chain: who owns the resource, who is allowed to extract it, what a production-sharing contract actually does, how big the sector really is, and where the oil and gas physically end up.

Who actually owns Malaysia’s oil and gas?

The founding rule of the entire industry is the Petroleum Development Act 1974 (PDA 1974). It vests PETRONAS with, in the words of the regulator’s own description, “the entire ownership, and the exclusive rights, powers, liberties and privileges of exploring and exploiting” petroleum resources, both onshore and offshore.

PETRONAS was established under that Act in 1974 as Malaysia’s national oil company. Crucially, this is not the usual arrangement where a government leases mineral rights to whoever finds the resource. In Malaysia, ownership of petroleum in the ground never passes to the operator. A company might spend billions drilling a field, but it never owns the crude — it owns a contractual right to a share of what it produces.

That single design choice explains why PETRONAS wears two hats that would normally be separated:

• Custodian and regulator of the nation’s petroleum resources, and
• Commercial operator that explores, produces, refines and trades in its own right.

The regulatory hat is worn through a dedicated division, Malaysia Petroleum Management (MPM), which acts “for and on behalf of PETRONAS in the overall management of Malaysia’s petroleum resources throughout the lifecycle of upstream oil and gas assets.” MPM is the body that qualifies contractors, awards contracts, approves field development plans and polices operating standards.

How is the industry structured, from wellhead to petrol pump?

Like every petroleum industry, Malaysia’s splits into three broad segments. What is distinctive is that PETRONAS or its subsidiaries sit somewhere in almost all of them.

Segment	What happens	Who does it in Malaysia
Upstream	Exploration, drilling, and production of crude oil and natural gas	Contractors (Shell, ExxonMobil affiliates, Hess, Petronas Carigali and others) operating under PSCs and RSCs, regulated by MPM
Midstream	Gathering, processing, liquefaction, pipelines, storage and shipping	PETRONAS Gas, MISC (shipping), the Bintulu LNG complex, gas processing plants and the national gas grid
Downstream	Refining crude into fuels, plus petrochemicals and marketing	Pengerang Integrated Complex (PRefChem), Melaka refineries, PETRONAS Chemicals, and the retail networks (PETRONAS, Shell, Petron, BHPetrol)

The upstream is where the ownership-and-contract logic bites hardest, so it is worth understanding in detail before moving downstream.

What is a production-sharing contract, and why does Malaysia use it?

When the PDA came into force, Malaysia replaced the older concession system — where a company was granted a block and largely kept what it found, paying royalties — with production-sharing contracts (PSCs). PETRONAS adopted the PSC model in 1976.

The mechanics of a classic PSC are straightforward in principle:

1. A contractor bids for, and is awarded, a defined contract area for a set period.
2. The contractor funds and carries all the exploration risk. If nothing commercial is found, PETRONAS pays nothing.
3. Once a field produces, the contractor first takes cost oil — a capped portion of production used to recover approved exploration and development costs.
4. The remaining profit oil is split between PETRONAS and the contractor according to the contract’s terms.
5. On top of its profit-oil share, the contractor pays petroleum income tax to the government.

Because PETRONAS keeps ownership of the resource and the assets throughout, the state captures value in three distinct ways at once — as resource owner (its profit-oil share and cash payments), as shareholder (PETRONAS dividends), and as tax authority (petroleum income tax). That layering is the reason Malaysia’s fiscal take from a producing field can be substantial even when the headline tax rate alone looks moderate.

The family of contract types

The plain 1976-style PSC has since branched into a family of arrangements, each tuned to a different kind of geology or field economics. PETRONAS describes them roughly as follows:

Contract type	Designed for	Core idea
Production Sharing Contract (PSC)	The original, general-purpose model since 1976	Contractor recovers costs, then shares profit oil with PETRONAS
Revenue-over-Cost (R/C) PSC	Larger and technically demanding fields	Profit split moves on a sliding scale based on profitability, rewarding cost-efficient technology
Small Field Asset (SFA) PSC	Smaller reserves	A simple, straightforward fiscal model with operational flexibility
Late Life Asset (LLA) PSC	Mature, near-end-of-life fields	Simplified commercial terms that reward efficiency and extend field life
Enhanced Profitability Terms (EPT)	Marginal projects needing sweeteners	More equitable sharing of upside to make projects economic
Risk Service Contract (RSC)	Niche opportunities and local capability-building	Contractor is paid a fee for services rather than taking a production share

The proliferation is deliberate. As easy oil declined and Malaysia’s basins matured, PETRONAS needed lighter, more forgiving terms to keep small and late-life fields commercial — hence SFA and LLA PSCs — while still offering competitive terms for the deepwater and technically complex prizes.

How big is the industry, really?

Malaysia is a mid-sized but strategically important producer. According to the U.S. Energy Information Administration, at the end of 2023 Malaysia held proved crude oil reserves of about 2.7 billion barrels — the second-largest in Southeast Asia — and proved natural gas reserves of around 32 trillion cubic feet. The EIA ranks Malaysia the second-highest producer of petroleum and other liquids in Southeast Asia and the fifth-largest LNG exporter in the world in 2023.

Production is dominated by natural gas, much of it from offshore Sarawak and Sabah, while the bulk of oil sits off the coast of Peninsular Malaysia. The scale is visible in the Department of Statistics Malaysia’s quarterly figures. In the first quarter of 2024:

• Crude oil and condensate production totalled 48.0 million barrels (with crude oil making up 69.2% and condensate the rest).
• Natural gas production reached 799.8 billion cubic feet, up 9.1% year on year.

In its Integrated Report 2024, PETRONAS reported producing a record roughly 2,000 thousand barrels of oil equivalent per day (kboe/d) from its Malaysia operations in 2024.

The export side shows how the value is distributed across the chain. In Q1 2024, Malaysia’s exports were worth:

Product	Export value (Q1 2024)	Leading destinations
Crude oil & condensate	RM9.1 billion	Thailand (26.4%), Japan (26.2%), India (14.4%)
Refined petroleum products	RM33.6 billion	Singapore (22.1%), Indonesia (18.7%), Australia (15.0%)
Liquefied natural gas (LNG)	RM18.5 billion	Japan (44.5%), China (25.2%), Republic of Korea (22.0%)

Notice that refined products and LNG together dwarf raw crude exports. Malaysia does not simply pump and ship oil — it processes, liquefies and adds value before export, which is where the midstream and downstream come in.

How does the money reach the government?

Because PETRONAS is the resource owner, the state’s fiscal take flows through the company as well as around it. PETRONAS’s 2024 results make the magnitude clear. The group posted:

• Revenue of RM320.0 billion (down about 7% from RM343.6 billion in 2023),
• Profit after tax of RM55.1 billion, and
• A total contribution to the government of RM72.4 billion.

That RM72.4 billion contribution is worth unpacking, because it shows the several channels described earlier working simultaneously. According to the Integrated Report 2024, it comprised:

• RM32.0 billion in dividend to the Government (PETRONAS as a state-owned company),
• RM26.8 billion in taxes, including petroleum income tax, corporate income tax, state sales tax, export duties and other statutory payments,
• RM13.1 billion in cash payments to federal and state governments for the value of hydrocarbon resources, and
• RM0.5 billion to the National Trust Fund.

Separately, income from petroleum operations is taxed under the Petroleum (Income Tax) Act 1967 (PITA) at a headline rate of 38%, with an effective 25% rate applied to income from marginal fields. This is the tax that contractors pay on their share of production, distinct from the profit split PETRONAS takes as owner.

The dependence runs both ways. Petroleum revenue is a major pillar of the federal budget, which is precisely why successive governments have tried to reduce reliance on PETRONAS dividends and build up non-petroleum revenue. A national oil company that is also the single largest contributor to the treasury is a powerful institution — and a concentrated risk.

Where do the oil and gas physically go?

The downstream and midstream are where Malaysia turns geology into finished energy, and two facilities dominate.

The Bintulu LNG complex in Sarawak is the heart of Malaysia’s gas-export business. It runs a fleet of LNG trains across three plants owned and operated by Malaysia LNG, MLNG Dua and MLNG Tiga in joint venture with PETRONAS. Its liquefaction capacity is about 29.3 million tonnes per annum, expanded from an earlier 25.7 mtpa when Train 9 (about 3.6 mtpa) was added in the mid-2010s. It is the machinery behind Malaysia’s standing as one of the world’s top LNG exporters, feeding the long-term contracts with Japan, China and Korea seen in the export table above.

The Pengerang Integrated Complex (PIC) in Johor anchors the liquids and petrochemicals side. Its refinery processes up to 300,000 barrels per day of various crudes into Euro 5 gasoline and diesel, Jet A1 and other products, and is owned and operated by PRefChem, a joint venture between PETRONAS and Saudi Aramco. Alongside the refinery sit a steam cracker producing about 3.4 million tonnes a year and a petrochemical complex of about 3.3 million tonnes a year — housing what PETRONAS calls the nation’s only integrated refinery, steam cracker and petrochemical plants under one roof.

Between the wellhead and these complexes sits the midstream backbone — the offshore platforms, gas processing plants, the Peninsular Gas Utilisation pipeline grid, and the MISC-operated tanker and LNG-carrier fleet — much of it under PETRONAS-linked ownership.

How should an investor or operator read the Malaysian market?

For anyone weighing an entry into Malaysian oil and gas — as an exploration contractor, a service provider, or an equity investor — a few structural questions matter more than the commodity price of the day.

1. Are you an owner or a contractor? You can never own the resource. Model your returns as a contractor’s share plus a fee, taxed under PITA, not as a concession-holder keeping the upside.
2. Which contract type fits the asset? A deepwater discovery, a marginal field and a late-life asset are governed by very different fiscal packages (R/C vs. EPT vs. LLA). The same barrel is worth different amounts under different contracts.
3. Is PETRONAS your regulator, your partner, or your competitor? Often it is all three at once — MPM regulates you, Petronas Carigali may be your joint-venture partner, and PETRONAS’s downstream arms may be your customer. Governance and conflict-management deserve real attention.
4. Where in the chain is the margin? Malaysia’s export mix shows value concentrating in LNG and refined products, not raw crude. Service and technology providers to the midstream and downstream face a different demand cycle than upstream drillers.
5. How exposed are you to policy? Because the sector is a fiscal pillar, contract terms, local-content expectations and dividend policy are politically live. A stable field can still sit under shifting fiscal winds.

Common misconceptions to avoid

• “The Malaysian government drills the oil itself.” It does not. PETRONAS — a company, albeit state-owned — holds the resource and licenses contractors to do the drilling.
• “If you find oil in Malaysia, you own it.” No. Ownership stays with PETRONAS under the PDA 1974. You own a contractual share of production, nothing more.
• “PETRONAS is just a regulator.” It is a full commercial operator across upstream, LNG, refining, petrochemicals and retail — as well as the regulator, through MPM. The dual role is the defining feature of the industry.
• “Royalty and profit split are the same thing.” They are not. The profit-oil split, cash payments for resource value, PETRONAS dividends and the 38% petroleum income tax are separate, stacking channels.
• “Oil is the main product.” By value, natural gas — especially LNG — and refined products are at least as important as crude. Malaysia’s reserves and exports are gas-heavy.
• “Marginal fields pay the full 38%.” An effective rate of 25% applies to marginal-field income, one of several tools used to keep smaller fields economic.

What’s next

Malaysia’s petroleum sector is entering a mature phase: shallow-water fields are ageing, the frontier is moving into deeper and more technically demanding acreage, and the LLA and EPT contract types exist precisely to squeeze more life from what is already discovered. At the same time, PETRONAS is pushing into biorefining, solar, hydrogen and carbon capture as the energy transition reshapes demand, while remaining the treasury’s single largest corporate contributor.

If you are researching further, the highest-value next steps are:

• Read the Petroleum Development Act 1974 and the Petroleum (Income Tax) Act 1967 directly for the exact statutory language behind ownership and taxation.
• Track the Malaysia Petroleum Management pages for current bid rounds, fiscal terms and field development requirements.
• Follow the annual PETRONAS Integrated Report and DOSM quarterly petroleum statistics for the latest production, export and contribution figures.

Those primary sources will keep you current as the numbers move — but the underlying architecture, one owner licensing many contractors under production-sharing terms, has held since 1974 and shows no sign of changing.