What should I check first when choosing an upstream operator in Oman?

Start with proven delivery on similar geology in Oman and evidence of stable drilling cadence. Also confirm the operator's plan for water, power, and logistics under local permitting expectations.

How do I evaluate an EPC contractor for a gas plant or refinery upgrade in Oman?

Prioritize live references in Oman that involved brownfield tie ins and constrained shutdown windows. Then test their local subcontractor depth and their plan to manage long lead equipment.

What are practical signs of strong In Country Value performance?

Look for local training capacity, measurable local procurement, and sustained Omanization in technical roles. Also verify whether local vendors are used on critical path scopes, not only low risk packages.

What matters most when contracting LNG supply from Oman?

Confirm delivery reliability history and clarity on pricing structure, including any indexation optionality. Then review shipping terms, flexibility on destination, and how disruptions are handled contractually.

How should I assess risk for steam based recovery projects in Oman?

Ask how steam demand is reduced through efficiency and how water sourcing is protected during stress conditions. Also evaluate contingency plans for lifting failures, corrosion, and extreme weather events.

How can buyers compare decarbonization readiness across Oman focused companies?

Check whether they have funded energy efficiency projects, electrification plans, and measurable certification progress at operating sites. Then confirm governance, reporting cadence, and realistic timelines for implementation.

Top Oman Oil And Gas Companies - Key Players & More

Petroleum Development Oman (PDO)

Execution depth remains the clearest advantage for this leading company, as it can scale complex recovery programs across a very large asset base. The Miraah solar steam initiative near Amal signals a practical path to reduce gas burn in thermal recovery, which matters as Oman tightens expectations on efficiency and water stewardship. If licensing terms keep favoring capable operators, PDO should continue winning brownfield reinvestment mandates, but delivery risk rises when multiple upgrades compete for rigs and skilled crews. A realistic upside is faster solar steam rollout that frees gas for higher value use, while the critical risk is thermal recovery disruption during extreme weather or supply chain delays.

Leaders

OQ Exploration & Production

Policy alignment is being used as a growth lever by this Muscat-listed upstream operator, because Oman's participation structure can translate into early access to de-risked assets. Its public disclosures highlight scale in production and reserves, and EPSA extensions plus new agreements improve long-dated cash visibility if prices soften. The practical moat is portfolio breadth across blocks and the ability to fund asset upgrades while maintaining dividends. The what-if to watch is faster gas monetization tied to new LNG and industrial demand, while the operational risk is cost creep in multi-year field expansions when local capacity tightens.

Leaders

Occidental Oman

Steam flood performance is the strategic center for this leading player, and Oman's decision to extend Block 53 to 2050 reinforces long-term commitment expectations. The extension creates room for new recovery phases and reservoir development, but it also increases scrutiny on efficiency and capital discipline as projects mature. A realistic upside is better uptime and lower artificial lift failures through focused reliability work, while a hard operational risk is water availability and the cost of maintaining steam injection at scale. The policy angle is simple: longer concessions reward operators that can show measurable recovery gains with tighter environmental controls.

Leaders

BP Oman

Gas reliability is the core differentiator for this major player, since Block 61 capacity underpins domestic supply and LNG feed flexibility. bp has highlighted Block 61's combined Khazzan and Ghazeer capacity expectations, which supports long-horizon planning for gas-linked projects. If drilling campaigns accelerate, contractor availability becomes a constraint, and the Abraj drilling contract timing points to that ramp in late 2025. The realistic upside is incremental tight gas recovery that supports new industrial load, while the key risk is well delivery productivity slipping if service intensity rises faster than local supply chain depth.

Leaders

Shell Development Oman

Operational ramp discipline stands out for this top manufacturer of gas supply commitments, since Block 10 startup milestones directly affect downstream offtake and new LNG plans. Shell announced the start of gas production from Block 10 with a targeted ramp to 0.5 bscf per day, tying into the national gas network. A sensible what-if scenario is a smoother-than-planned decline profile that supports longer contracting, but the downside is bottlenecks in brownfield tie-ins and water infrastructure for additional wells. Policy pressure on emissions and flaring can also raise compliance costs, so execution consistency becomes a key advantage.

Leaders

Oman LNG

Contracting momentum is strong, but the near-term focus is delivery discipline rather than capacity growth. Reuters reported a 10-year SPA to supply TotalEnergies starting in 2025, adding to a broader set of term agreements also beginning that year. S&P Global described a shift toward more JKM-linked pricing in some term volumes, which changes commercial risk allocation for buyers and sellers. A realistic upside is better portfolio flexibility that supports higher netbacks, while the operational risk is reliability and maintenance planning if expansion decisions tighten schedules.

Established

Oman Oil Marketing Co.

Mobility transition exposure is rising, and that can be an advantage if it stays tied to profitable forecourt economics. OOMCO stated that EVO, created in 2023, has built an interconnected network of 84 EV chargers across Oman, directly responding to policy goals for lower emissions transport. The company also described a broad station footprint and continued station upgrades, which support non-fuel revenue growth when fuel margins tighten. A realistic risk is underutilized chargers during early adoption, while the upside is capturing premium locations as fleet electrification accelerates.

Established

Sohar Refinery Company

Decarbonization engineering is becoming a practical selection filter, not a marketing claim, and Sohar is moving in that direction. Oil & Gas Journal reported Worley's FEED work for a decarbonization effort at the Sohar refinery focused on heat recovery and energy efficiency improvement, signaling a structured pathway for emissions reduction. OQ also pointed to ISO 50001 certification and climate adaptation planning for the Sohar facility, reinforcing governance expectations. The upside is lower fuel and power intensity, while the operational risk is tie-in execution at an operating refinery with limited shutdown windows.

Established

TotalEnergies E&P Oman

Project optionality is the main value here, because Marsa LNG links upstream gas, electrified liquefaction, and dedicated solar supply into one build. TotalEnergies and OQEP broke ground on Marsa LNG, targeting first LNG in Q1 2028, which should broaden Oman's marine fuel offering if execution stays steady. If regulators raise expectations on carbon intensity for export contracts, Marsa's design choices could become a practical advantage rather than a branding claim. The risk is interface complexity across upstream feed, grid integration, and EPC delivery. A reasonable upside is faster commercial ramp if shipping demand shifts toward LNG bunkering.

Performers

OQ Chemicals

Product refresh is the main moat, because new polymer grades can protect utilization when customer specifications tighten. Trade reporting in 2025 described OQ introducing 17 new polymer solutions across PP and PE families, signaling continued product development investment. OQ has also emphasized energy efficiency and certification progress, which matters as Sohar operations face higher expectations on emissions and resource use. The upside is stronger conversion demand tied to water and infrastructure needs, while the critical risk is feedstock and margin volatility in down cycles.

Performers

Petrofac Oman

Workforce capability is a credible differentiator for a leading service provider when project schedules are tight and Omanization targets matter. Petrofac highlighted Takatuf Petrofac Oman reaching its five-year milestone in 2023, positioning training capacity as a long-term enabler for local execution. That human capital base can strengthen delivery credibility for brownfield modifications and reliability-driven scopes, especially when policy requires measurable in-country value. A realistic upside is winning more integrated support roles as operators push debottlenecking, while the key risk is margin pressure if contract structures shift toward tighter performance terms.

Performers

Larsen & Toubro Oman

Regional EPC capacity can translate into Oman wins when gas processing and compression projects move from FEED to award, but timing is uncertain. L&T's hydrocarbon business continues to announce large gas processing and compression project awards in the Middle East, which supports a credible mobilization base for nearby Oman scopes. The upside is capturing discrete packages in compression, tankage, and associated utilities, especially where schedule certainty is valued. The main risk is limited local reference visibility versus entrenched incumbents, which can raise bid costs and reduce conversion rates. Strong local delivery partners become essential under Oman's in-country value requirements.

Performers

Eni Oman

Exploration proof points are still developing, and the near-term story is technical follow-through rather than scale. Reporting in 2025 tied to Block 47 shows gas indications at Najid 1 and a contract extension to complete post-well studies, which keeps optionality alive. If Oman prioritizes additional gas discoveries for domestic demand, Eni's position could improve quickly, but it remains exposed to appraisal outcomes and partner alignment. The realistic risk is a non-commercial result after the data work, which would shift capital away from Oman. Regulatory clarity on license extensions helps, yet it does not replace subsurface success.

Aspirants

China National Petroleum Corp. (CNPC)

In-country partnership is the main lever for this major supplier of external capital and technical depth, but near-term visibility depends on how new work programs move from signing to drilling. Oman's Ministry of Energy and Minerals described Block 15 commitments for studies, 3D seismic, and wells under Daleel as operator with Chinese participation. A positive what-if is a fast transition from evaluation to field development, which can support near-term volumes. The main risk is slower decision cycles across partner groups, especially when domestic priorities shift toward gas and emissions compliance.

Aspirants

CC Energy Development

Operational continuity is the strongest signal, since CCED highlighted the export of its 150 millionth barrel from Blocks 3 and 4, implying sustained field management discipline. If Oman continues to reward steady producers with efficient reinvestment, CCED can stay relevant as a mid-tier operator, but it will remain sensitive to reservoir management limits and service cost inflation. A realistic upside is better recovery through facility optimization and drilling cadence, while the core risk is production volatility if water handling and power reliability lag field needs. Policy emphasis on local value creation also pushes staffing and procurement commitments.

Aspirants

Daleel Petroleum

Expansion optionality is improving, because Oman formalized a new EPSA for Block 15 with a defined program of seismic and wells, while Daleel continues operating its existing concession. In late 2025 Oman also signed an addendum for Block 5 operated by Daleel, signaling continued alignment with national reserve goals. The upside scenario is converting early subsurface work into a development queue that uses proven operating playbooks. The operational risk is that simultaneous work across concessions stretches drilling and subsurface teams, especially if local procurement targets tighten.

Aspirants

ARA Petroleum

Rig intensity is the clearest execution cue, because ARA described mobilizing a third rig for Block 44 in mid 2025 while maintaining activity in other fields. Oman's concessions listing also shows ARA as operator for Block 44, which matters for permitting and work program accountability. A realistic upside is faster appraisal conversion if early wells confirm continuity, while the core downside is cost escalation from running multiple rigs at once. Policy and stakeholder expectations on in-country value can become a differentiator for smaller operators, yet they also raise delivery complexity when capacity is limited.

Aspirants

Masirah Oil Ltd.

Offshore uptime is the priority for this key participant, because production depends on a small number of wells and critical equipment like flowlines and lifting systems. Masirah Oil reported January 2025 production levels at Yumna and highlighted completion of a new flowline, which reduces single point failure exposure. The upside scenario is stable production with incremental lift improvements, which supports cash-funded drilling. The operational risk remains weather-driven downtime and logistics constraints that delay repairs. Regulatory requirements for offshore safety and environmental controls also raise the cost of any unplanned event.

Aspirants

Partex Oil & Gas

Small non-operated positions can still matter when LNG contracts get re-priced and extended, but influence remains limited. Offshore Energy described Oman LNG's shareholder group and included Partex among the owners, tying Partex to ongoing LNG commercialization in Oman. If Oman LNG expands its contracting approach toward more flexible indexation, Partex benefits indirectly, yet it has little control over operating decisions. The realistic downside is value dilution if new capital programs are funded under less favorable terms. The practical upside is steady distributions when term contracts remain resilient.

Aspirants

Samsung Engineering Oman

Refinery delivery depth is the core strength for this major contractor, and Samsung E&A positions Duqm among its active refinery references. Samsung's own materials cite the Oman DRPIC Duqm project as part of its refinery work, indicating continued association with complex execution in country. If Oman's downstream build-out accelerates again, Samsung can benefit through packages tied to reliability upgrades and energy efficiency improvements. The realistic risk is that EPC competition pushes pricing down while clients demand faster schedules. A credible upside scenario is follow-on work that leverages lessons learned from commissioning support and utility integration.

Aspirants

Oman Oil And Gas Companies: Leaders, Top & Emerging Players and Strategic Moves

Top 5 Oman Oil And Gas Companies

Oman Oil And Gas Companies Matrix by Mordor Intelligence

MI Competitive Matrix for Oman Oil And Gas

Analysis of Oman Oil And Gas Companies and Quadrants in the MI Competitive Matrix

Petroleum Development Oman (PDO)

OQ Exploration & Production

Occidental Oman

BP Oman

Shell Development Oman

Oman LNG

Oman Oil Marketing Co.

Sohar Refinery Company

TotalEnergies E&P Oman

OQ Chemicals

Petrofac Oman

Larsen & Toubro Oman

Eni Oman

China National Petroleum Corp. (CNPC)

CC Energy Development

Daleel Petroleum

ARA Petroleum

Masirah Oil Ltd.

Partex Oil & Gas

Samsung Engineering Oman

Frequently Asked Questions

Methodology

Analysis of Leading Oman Oil And Gas Companies