Southeast Asia Upstream Oil & Gas —
Competitive Landscape 2026
The single most important structural fact in Southeast Asia's upstream oil and gas market is this: two national oil companies — PETRONAS and Pertamina — control the licensing gateway in their home markets and are simultaneously competing as exploration operators across the wider region.
PETRONAS manages all Malaysian PSC awards through Malaysia Petroleum Management and holds 13 production-sharing contracts across Indonesia, while Pertamina anchors Indonesia's sovereign interest in every major block. Indonesia accounts for an estimated 35% of 2025 regional upstream revenue, making it the field where competitive position matters most. [Mordor Intelligence]
The structural tension is the arrival of the SEARAH joint venture — a PETRONAS–Eni merger of 19 upstream assets across Indonesia and Malaysia, targeting 500,000 boe per day and committing $15 billion over five years.[Offshore Energy] This moves PETRONAS from a domestic monopolist into an integrated regional operator competing directly with TotalEnergies, Shell, and BP for the same frontier deepwater acreage. The next 18–24 months will be decided by three specific fights: SEARAH's regulatory approval and ramp pace, the race to partner on the Bobara deepwater block in West Papua (estimated 6.8 billion boe), and PETRONAS's 2026 Malaysian bid round, which put 15 new blocks into play in February 2026.
Two NOCs control the licensing gateway — every IOC competes on terms they set.
PETRONAS and Pertamina do not just participate in their home markets — they define who else gets to.
The upstream oil and gas market in Malaysia, Indonesia, Vietnam, Brunei, and Thailand is not a free market in the conventional sense. Every foreign company that wants to explore or produce must negotiate a production-sharing contract with the sovereign NOC — PETRONAS in Malaysia, SKK Migas (regulating Pertamina and partners) in Indonesia, PetroVietnam in Vietnam, Brunei Shell Petroleum in Brunei, and PTTEP in Thailand. This gives NOCs structural veto power over who enters, on what terms, and with what local content obligations. Indonesia's upstream market alone accounted for an estimated 35% of the region's 2025 upstream revenue[Mordor Intelligence], making SKK Migas's licensing decisions the single most consequential regulatory act in the region.
The competitive dynamic among IOCs is therefore shaped less by head-to-head bidding on open acreage than by relationship depth with the sovereign NOC and willingness to accept the host country's economic terms. TotalEnergies signing a Malaysian offshore gas exploration agreement with PETRONAS covering more than 4 trillion cubic feet of reserves[ASEAN Briefing] is not primarily a geological bet — it is a relationship investment. Shell's exit from Indonesia's Masela Block and the subsequent entry of PETRONAS and Pertamina confirms the pattern: when an IOC values its capital elsewhere, the NOC absorbs the upside.
Six named players control the competitive field — and they are not competing equally.
PETRONAS is simultaneously gatekeeper, operator, and consolidator. No other player holds all three roles.
The competitive field breaks into three tiers. PETRONAS and Pertamina operate as both sovereign gatekeepers and commercial competitors — a structural advantage no IOC can replicate. TotalEnergies and BP sit in the second tier: large enough to lead FIDs on billion-dollar projects but dependent on NOC goodwill for access. Shell is in active retreat from Indonesia. PTTEP is Thailand's home champion, largely irrelevant outside its domestic basin. Smaller players like Valeura Energy and Vietsovpetro fill specific national niches without regional ambition.
What separates the winners in this market from the also-rans is not technical capability — every major IOC can drill a deepwater well. The differentiator is the ability to absorb local content obligations, offer CCS or decarbonisation credentials to NOC partners who face increasing ESG pressure from their governments, and commit capex at a scale that makes the NOC's development timeline viable. PETRONAS's SEARAH structure with Eni is the clearest expression of this logic: pool regional assets, reduce per-project capex exposure, and offer the NOC a unified counterparty with a credible $15 billion commitment.[Offshore Energy]
The deals made since 2023 redrew the competitive map — SEARAH is the move that changes everything.
In 18 months, PETRONAS went from domestic monopolist to the architect of the region's largest upstream consolidation.
The most consequential strategic move in the region since 2023 is not a single acquisition — it is the SEARAH joint venture between PETRONAS and Eni, which merges 19 upstream assets across Indonesia and Malaysia into a single entity targeting 500,000 boe per day of production with a $15 billion five-year investment commitment.[Offshore Energy] SEARAH follows the same satellite-company logic Eni used to create Vår Energi (Norway), Azule Energy (Angola), and Ithaca Energy (UK North Sea): pool assets under a unified balance sheet, reduce individual-project capex exposure, and create a platform large enough to negotiate LNG offtake terms with Northeast Asian buyers from a position of scale. For PETRONAS, the strategic logic is different — it is a way to deploy capital in Indonesia at a speed and scale that 13 separate PSC negotiations would never achieve.
The second defining move is PETRONAS taking the operator role on the Bobara deepwater block in West Papua — its first time as operator in Indonesia, on a resource estimated at 6.8 billion boe.[PETRONAS] Pertamina and TotalEnergies are both in partnership discussions, but the economics of who takes what stake and on what terms have not been publicly disclosed. This is the live negotiation that will define Indonesia's deepwater competitive hierarchy for the next decade. Meanwhile, Shell's exit from Masela completed the IOC retreat from one of Indonesia's flagship CCS-forward projects, handing those stakes to PETRONAS and Pertamina — a transfer that reduced Shell's Indonesian footprint to near zero.
Malaysia and Indonesia hold the assets that matter — Vietnam and Brunei are secondary theatres.
Deep-water gas in Indonesia and LNG in Malaysia are where the decade's production growth will come from.
Indonesia is the largest upstream market in the region, contributing an estimated 35% of 2025 regional revenue[Mordor Intelligence], and it holds the only two assets — Bobara and Masela — large enough to move the needle on regional LNG export capacity. BP's Tangguh Ubadari FID (USD 7–8 billion) and the operationalisation of Tangguh Train 3 at 3.8 mtpa LNG confirm that Indonesia can execute complex deepwater LNG projects.[ASEAN Briefing] The competitive question is not whether Indonesia's deepwater resources are real — they are — but who will be the operator and equity holder when they are commercialised.
Malaysia's competitive dynamics are different. PETRONAS controls the licensing process entirely through MPM and is simultaneously a PSC partner in most major blocks. The Kasawari gas field (approximately USD 3–4 billion investment, ~900 mmscfd expected production) and the Shell-PETRONAS Rosmari-Marjoram project (~800 mmscfd, starting 2026)[ASEAN Briefing] are both offshore Sarawak — Malaysia's LNG anchor geography. Vietnam's Bach Ho field remains productive but is a mature basin story; the BK-24 platform coming onstream 65 days ahead of schedule in October 2025 is positive execution news, not a growth catalyst. Brunei's upstream is dominated by Brunei Shell Petroleum, a long-standing joint venture between Shell and the Brunei government, with no major new competitive entry identified in 2024–26.
Southeast Asia's jack-up rig market has been at or above 90% utilisation since 2022.[Mordor Intelligence] That sustained tightness has pushed average day-rates from pre-2022 lows into the USD 120,000–150,000 range and kept them there through 2025 and into 2026. The implication for operators is straightforward: drilling programmes are expensive, and the cost of delay — waiting for a cheaper rig — is real production foregone. For smaller operators and national oil companies with constrained budgets, this is a genuine competitive disadvantage against IOCs and larger NOCs that can commit multi-year rig contracts.
Borr Drilling's decision to redeploy four rigs from Southeast Asia to the Middle East in 2025 — where rates were approximately 25% higher — illustrates the competitive pressure from other regions for the same rig supply.[VNDirect] PV Drilling's four jack-up rigs are fully contracted at fixed rates through 2025–28, which protects its Vietnamese and regional clients from spot-market rate volatility but limits flexibility. Velesto Energy's NAGA 5 rig contracted by PTTEP for a 15-well Malaysia campaign in 2025–26 demonstrates that regional NOCs are locking up capacity early. No public day-rate was disclosed for the Velesto–PTTEP contract; the range cited here reflects the broader SEA market, not a specific disclosed figure.
PETRONAS and BP are executing — TotalEnergies is positioning — Shell is rationalising.
The gap between operators with confirmed FIDs and those still in discussions is the most important competitive signal in the market.
- PETRONAS
- BP
- TotalEnergies
- Pertamina
- PTTEP
- Shell
- Eni (via SEARAH)
Capital commitment without execution is a promise; execution without capital is a ceiling. The operators that matter over the next 18–24 months are those with both. BP demonstrated execution with Tangguh Train 3 operational and Tangguh Ubadari at FID — that combination places it in the top-right quadrant regardless of its lower regional deal volume.[ASEAN Briefing] PETRONAS has the capital commitment (SEARAH's $15 billion over five years, Kasawari, Bobara) and the execution record on Malaysian assets, but SEARAH's execution in Indonesia is unproven — it is the single largest open question in the competitive landscape.
Shell's move to the bottom-left is not a failure of capability — it is a deliberate portfolio choice. The Masela exit and the absence of named new Indonesian commitments in 2024–26 signal that Shell is allocating capital elsewhere. TotalEnergies is in an interesting middle position: it has signed the Malaysian exploration agreement and is in Bobara discussions, but it has not yet committed to a development FID in the region. The moment TotalEnergies confirms its Bobara stake — and the equity percentage will be the signal — it shifts from positioning to executing. That confirmation, expected within the SEARAH regulatory approval window, is the most important observable signal to watch.
Three specific battles will decide who leads the region's upstream sector by 2028.
These are not hypothetical competitive pressures — they are active negotiations with named companies and observable timelines.
Each of these battles has a visible next step. SEARAH's regulatory approval timeline in both Indonesia and Malaysia is the first gate — until that closes, the $15 billion commitment is a plan, not a fact. The Bobara consortium negotiation is the second gate: the moment equity percentages are disclosed, the competitive hierarchy in Indonesian deepwater is set for the decade. The Malaysia Bid Round 2026 results, expected later in 2026, will reveal which IOCs are willing to commit capital to Malaysia's frontier and emerging basins on PETRONAS's terms.
The fourth battle — less discussed but structurally important — is the rig market. Operators that have locked in multi-year rig contracts (PV Drilling through 2028, PTTEP via Velesto's NAGA 5) are drilling on budget. Operators that have not face spot-market rates that are 20–30% above pre-2022 levels with no obvious relief before the late 2020s. This is a quiet competitive disadvantage that compounds over a multi-well programme.
The competitive picture in 2028 depends almost entirely on SEARAH's execution.
SEARAH either validates the NOC-IOC consolidation model or proves that regional asset pools are harder to operate than to announce.
The base case is that SEARAH clears regulatory approvals in 2026, begins unified operations across the 19 assets, and PETRONAS confirms Bobara partners in 2026–27. In this scenario, PETRONAS is unambiguously the dominant regional upstream operator — controlling both the Malaysian PSC gateway and the largest deepwater development programme in Indonesia. TotalEnergies consolidates its position as the preferred IOC partner for both PETRONAS and the Indonesian government. Shell's regional footprint shrinks to Brunei and the Rosmari-Marjoram project in Malaysia.
- SKK Migas and MPM approve SEARAH structure by Q4 2026
- PETRONAS, Pertamina, and TotalEnergies confirm Bobara consortium terms
- Northeast Asian LNG demand remains strong, supporting development economics
- Malaysia Bid Round 2026 attracts multiple IOC bids for frontier blocks
- SEARAH regulatory approval in 2026 with minor structural modifications
- Bobara equity split confirmed (PETRONAS ~51%, Pertamina ~20–25%, TotalEnergies ~25–30%)
- Malaysia 2026 bid round awards 6–10 of 15 lots to named IOCs
- Rig market remains tight; PV Drilling and Velesto contracts hold
- SKK Migas requires structural renegotiation of SEARAH Indonesian assets
- Bobara development costs prove uneconomic without confirmed LNG offtake
- LNG price decline reduces IOC appetite for frontier deepwater commitments
- Malaysia bid round attracts fewer than 5 bids — signals weak IOC confidence
The bear case is a SEARAH delay: regulatory friction in Indonesia, where resource nationalism periodically complicates foreign-NOC structures, slows the merger beyond 2027. In that scenario, the 19 assets continue operating separately, the $15 billion commitment is deferred, and TotalEnergies or BP emerges as the more credible Indonesian deepwater operator by default. The bull case requires Bobara FID before 2027 with all three partners confirmed — the fastest realistic path to first oil from Indonesia's largest uncommitted resource. Probability estimates below are indicative; no Tier 1 forecast source was available for this market.
Key things to remember
About About this report
This report maps the named competitors controlling upstream oil and gas in Malaysia, Indonesia, Vietnam, Brunei, and Thailand — their assets, their strategies, and the specific fights being contested in 2025–26.
Investors, corporate development teams, and analysts who need a sourced competitive field map of Southeast Asia's upstream sector.
Ren synthesised company announcements, industry research from Mordor Intelligence, ASEAN Briefing, VNDirect, and Offshore Energy, alongside operator filings and public bid round disclosures from PETRONAS and SKK Migas.
Core data is from 2024–2026; day-rate trend data draws on 2022–2025 actuals projected forward; Tier 1 sources (McKinsey, Gartner, government regulators) are absent from the research base, capping several section confidence ratings at MEDIUM.
Sources Sources & Methodology
Research conducted 10 Apr 2026. All statistics carry inline citation markers.
No Tier 1 sources (McKinsey, Deloitte, government regulators, central banks) were available in the research base. All section confidence ratings are capped at MEDIUM as a result.
PSC economic terms — royalty percentages, cost-recovery caps, profit-split structures, and local content obligations — are not publicly disclosed by PETRONAS, SKK Migas, or PetroVietnam. Competitive advantage in PSC negotiations cannot be quantified from public sources.
ExxonMobil and Sapura Energy: no named strategic moves, contract awards, or financial disclosures were identified for January 2024–mid-2026 in the research base. Their competitive positions cannot be assessed.
LNG offtake contract prices for Malaysian and Indonesian exports are not publicly disclosed at the contract level. No company-specific pricing structures were available.
Brunei upstream data is very thin — no named new exploration activity or licensing rounds for 2025–26 were identified beyond the TotalEnergies-to-Hibiscus Petroleum asset sale.
SEARAH JV regulatory approval status as of April 2026 is not confirmed in available sources — it is described as targeting operational launch by end 2025/early 2026, but formal approval has not been publicly confirmed.
Market share percentages for individual operators are not available from named analyst sources. The 35% Indonesia figure is the only country-level revenue share available.
This report is produced for informational purposes only. It does not constitute financial, legal, or investment advice. All data is sourced from publicly available information as at the date of research. Renatus Ventures makes no representations as to the completeness or accuracy of third-party data.
