Oman Oil And Gas Market Size & Share Analysis - Growth Trends And Forecast (2025 - 2030)

Oman Oil And Gas Market Trends and Insights

Block 61 Gas Expansion Reshapes Supply Dynamics

Block 61 supplies 1.2 billion cubic feet per day (bcf/d) and targets 1.5 bcf/d by 2026, confirming the commercial development of tight gas in the Middle East. Phase 2 adds 500 million cubic feet per day, utilizing multi-stage hydraulic fracturing, and directly supports Oman LNG’s Train 4 project. Water-recycling systems limit freshwater intake, addressing concerns about scarcity in the desert interior. Success at Khazzan-Ghazeer has catalyzed analogous investment in Blocks 77 and 40, collectively assessed at more than 2 bcf/d potential. These volumes underpin domestic power supply and sustain LNG exports, shielding fiscal revenues against oil-price swings. The project’s digital twin platform has already reduced unplanned downtime by 10%, illustrating the technology’s role in enhancing the resilience of the Oman oil and gas market.

Production Sharing Contract Liberalization Accelerates Capital Inflow

The 2024 PSC overhaul reduced the government's take from 85% to 75% for discoveries and extended the cost-recovery period to 10 years. The auction of 15 blocks secured USD 1.2 billion in signature bonuses, leading to a 40% increase in exploration spending to USD 800 million. Streamlined environmental approvals now trim typical project lead times by 18 months. Operators welcome a clear local-content target of 35%, which nurtures domestic supply-chain capacity without stalling project schedules. The updated regime, therefore, attracts technology-intensive majors that can monetize frontier acreage and share digital expertise with national partners, thereby strengthening the competitive landscape of the Oman oil and gas market.

Domestic Power and Petrochemical Demand Sustains Gas Consumption

Natural gas fuels 94% of Oman’s electricity fleet, whose installed capacity is expected to reach 8.2 GW by 2025.^{(1)Oman Electricity Transmission Company, “Capacity Expansion Plan 2025,” oetc.om} First-half 2025 gas use reached 27.58 billion m³, up 5.3% year-on-year as new combined-cycle turbines lifted efficiency by 15%. OQ Chemicals’ expanding methanol and ethylene units add stable baseload demand, while seasonal cooling needs boost summer gas burn by 20%. GCC grid interconnection enables surplus exports to the UAE during shoulder months, smoothing dispatch patterns. The firm’s offtake commitments anchor long-cycle gas projects, securing steady cash flows even during periods of weaker crude prices.

Downstream Capacity Build-Out Bolsters Regional Hub Status

Duqm Refinery reached 255,000 barrels per day (b/d) in 2025 after debottlenecking, while Sohar now processes 230,000 b/d, resulting in a combined throughput of 485,000 b/d.^{(2)OQ Group, “Duqm Refinery Performance Report,” oq.com} Both complexes integrate with polypropylene and aromatics lines that earn premiums over crude exports. Deep-water access reduces freight costs by USD 2-3 per barrel for Asian customers, thereby widening margins. The Duqm Special Economic Zone further waives selected tariffs, attracting USD 15 billion in follow-on petrochemical and storage investments. These additions diversify revenue streams, helping the Oman oil and gas market navigate the headwinds of the energy transition.

Oil-Price Volatility Clouds Capital Allocation

Brent’s 2024 range of USD 70-90/bbl complicates the sanctioning of EOR projects that require USD 45-50/bbl breakevens.^{(3)Petroleum Development Oman, “Annual Report 2024,” pdo.co.om} Developers employ modular concepts to stagger funding and trim initial outlays by up to 40%. Hedging shields 40-60% of production but reduces returns by 2-3 percentage points. The treasury, therefore, prioritizes quick-payout gas schemes over heavier oil projects. Lower-cost digital monitoring mitigates some volatility, yet fluctuating prices remain the most immediate headwind for the Oman oil and gas market.

Energy-Transition Pressure Narrows Long-Term Oil Window

IEA scenarios place global peak oil demand between 2028 and 2030, thereby squeezing the investment runway for 15- to 20-year EOR assets.^{(4)International Energy Agency, “World Energy Outlook 2024,” iea.org}Oman accelerates mature-field depletion and channels surplus cash toward blue-hydrogen, carbon-capture, and solar-EOR pilots. Alignment with Paris targets necessitates constant emissions audits and incremental CO₂ abatement. Downstream operators retrofit renewable feedstocks and circular-economy processes, extending asset life without violating future carbon budgets. This dual-track approach cushions the Oman oil and gas industry against a structurally lower-carbon future.

Segment Analysis

By Sector: Upstream Dominance Anchors Cash Flow

Upstream activities accounted for 74.3% of Oman's oil and gas market share in 2024, generating the bulk of fiscal receipts that fund diversification programs. Polymer flooding and miscible-gas injection at Amal, Marmul, and Harweel lifted aggregate rates by 39,000 b/d, lengthening field life by about a decade. Midstream pipelines, at 18.2% share, trail upstream in revenue but enjoy stable tariffs linked to take-or-pay agreements. Targeted investments strengthen feedstock security for polypropylene and polyethylene facilities serving GCC manufacturers, thereby embedding greater domestic value addition along the twin 42-inch pipelines that channel Block 61 output to coastal LNG and petrochemical hubs, while reducing transport costs by approximately USD 1.50 per barrel.

Downstream assets capture just 7.5% of the Oman oil and gas market size today, yet the segment's integrated business model earns higher margins per barrel than crude exports. Duqm's complex now runs 11% above nameplate, validating process-control upgrades and workforce skill transfer. Continuous emissions monitoring and flare-gas recovery meet Oman Environmental Authority thresholds without impeding throughput. The build-out also enhances feedstock security for polypropylene and polyethylene plants that supply GCC manufacturers, thereby embedding domestic value addition within the broader Oman oil and gas market.

Note: Segment shares of all individual segments available upon report purchase

By Location: Offshore Growth Rebalances Portfolio

Onshore basins accounted for 78.9% of Oman's oil and gas market share in 2024, utilizing 4,200 km of pipelines and 850 gathering stations to achieve sub-USD 35/bbl breakevens. Digital twin rollouts across 200 wells have pushed average uptime above 95%, while drone-enabled inspections have reduced lifting costs by USD 3-4/bbl. Yet production from maturing reservoirs inches lower, prompting operators to test solar-generated steam that cuts gas consumption by 80%.

Offshore projects, although accounting for only 21.1% of current revenue, are projected to capture the highest 5.5% CAGR through 2030 within the broader Oman oil and gas market size. Three new platforms, Bukha, West Bukha, and Yumna, unlock deeper reservoirs at a water depth of 200 meters. Subsea boosting and compact processing reduce topside footprints, thereby curbing installation costs. Regulatory oversight by the Oman Maritime Authority ensures compliance with IMO-aligned safety codes, thereby mitigating investor perception risks. Over the forecast horizon, offshore gains diversify asset exposure and smooth the country's production profile.

By Service: Decommissioning Takes Center Stage

Maintenance and turnaround captured 38.1% of the Oman oil and gas market size in 2024, reflecting aging infrastructure that requires 45- to 60-day shutdowns every four to five years. Specialized contractors mobilize up to 3,000 technicians for each Sohar or Duqm campaign, while predictive analytics condense outage duration by roughly one week. Construction services, with a 32.7% share, continue to rise on the back of new midstream links and compressor upgrades, although fewer mega-projects are expected beyond 2027.

Decommissioning accounts for 29.2% of revenue but posts an unrivaled 6.1% CAGR through 2030, reflecting stringent rules for well plugging and site remediation. More than 150 injection wells need reclassification by 2026, creating a steady workflow for robotics-enabled cutting, cleaning, and recycling units that recover up to 90% of structural steel. The segment thus morphs from a compliance cost into a growth niche that attracts engineering firms equipped for circular-economy execution.

Note: Segment shares of all individual segments available upon report purchase

Geography Analysis

Oman's hydrocarbons lie mainly in the interior Fahud-Natih-Al Huwaisah triangle, an area that has yielded over 7 billion barrels since the 1960s. These mature onshore fields currently supply 75% of the national output; however, rising water cuts and higher lift costs are prompting the wider adoption of polymer and solar-steam EOR to maintain production above 800,000 b/d. The centrality of existing gathering lines keeps operating expenditures competitive, even as incremental recovery challenges multiply.

Coastal governorates from Muscat to Sohar host 85% of the petrochemical capacity and 60% of the gas processing infrastructure. Pipeline tie-ins to the interior ensure real-time gas allocation between LNG liquefaction, power generation, and methanol trains. Deep-draft ports enable the loading of Very Large Crude Carriers (VLCCs), making Duqm a cost-efficient springboard for Asian deliveries. Proximity to sea lanes shortens voyages to India and China by up to 800 nautical miles versus Persian Gulf ports, a distinct freight advantage that reinforces the Oman oil and gas market's export competitiveness.^{(5)Special Economic Zone Authority at Duqm, “Logistics Cost Benchmarking,” sezad.gov.om}

Southern Dhofar Governorate hosts the 6.7 million-tpa Salalah LNG complex and emerging green-hydrogen clusters. Synergy between gas feedstock, desalinated water, and high solar irradiance attracts proposals for blue ammonia and green methanol, targeting Japanese and Korean buyers. Cross-border grid links with Saudi Arabia stabilize power supply during summer peaks, reflecting a broader GCC push toward shared infrastructure. As interior reservoirs mature and offshore output scales up, supply chains will continue to pivot toward the coast, cementing Oman's role as a hybrid hydrocarbons-and-renewables export platform within the broader Oman oil and gas market.