Oil And Gas Midstream Market Size & Share Analysis - Growth Trends and Forecast (2026 - 2031)

Global Oil And Gas Midstream Market Trends and Insights

Surging U.S. LNG export capacity build-out

U.S. LNG export capacity is on track to rise 80% by 2028 as new Gulf Coast terminals come online. The projects enable the country to supply nearly one-third of global LNG by 2030, spurring investments in upstream gathering, processing, and trunkline infrastructure.^{(1)CME Group, “LNG Outlook 2025,” cmegroup.com} Cheniere Energy reported USD 4.6 billion Q2 2025 revenue alongside USD 1.6 billion net income, highlighting robust earnings visibility under long-term take-or-pay agreements. Federal Energy Regulatory Commission approvals dictate construction pacing, yet favorable contract coverage and rising Asian demand keep final investment decisions on track. Liquefaction developers are increasingly partnering with midstream MLPs to secure feed gas and reduce balance-sheet strain.

Rising Asian gas demand shifting global flow patterns

Morgan Stanley projects 5% annual Asian gas consumption growth through 2030, dwarfing 1% in Europe.^{(2)Morgan Stanley, “Global Gas Demand Outlook,” morganstanley.com} China imported 79 million tonnes of LNG in 2024 and plans to connect 150 million more residents to pipelines by 2030. India’s 27 million-tonne LNG tally in 2024, up 20% from 2023, aligns with a five-year plan to serve 30 million new consumers. Rising imports stimulate the construction of regasification terminals, storage caverns, and last-mile distribution grids. The demand wave reshapes shipping routes, drives longer-tenor offtake agreements, and underpins LNG-linked midstream tariffs. It also encourages U.S. exporters to secure destination-flexible contracts that capitalize on arbitrage.

Crude-by-rail replacement with pipelines

North American crude-by-rail movements continue to cede share to pipelines as new takeaway capacity cuts transport costs and spill risks. The Matterhorn Express Pipeline commenced operations in November 2024 with a 2.5 Bcf/d gas capacity, indicative of cross-commodity infrastructure development. Permian and Canadian oil sands producers secure multi-year transport contracts to lock in egress and eliminate rail discounts. States tighten rail safety rules, pushing shippers toward safer pipelines, while carbon reduction goals favor lower-emission transport modes. Midstream developers utilize brownfield corridors to expedite permitting and reduce capital intensity.

Aging onshore pipelines requiring replacement CAPEX

Many North American pipelines have surpassed 40 years of operation, coinciding with stricter regulations from the Pipeline and Hazardous Materials Safety Administration. Enterprise Products Partners advanced the Athena gas processing plant, which has a 300 MMcf/d capacity, to integrate with replacement lines and increase recoveries. New materials and fiber-optic monitoring reduce spill frequencies and lower long-term maintenance costs. Utilities accelerate parallel-loop projects to eliminate integrity digs and boost throughput. Replacement CAPEX sustains construction backlogs, lifts service revenues, and supports fee escalators tied to inflation.

Heightened ESG-driven capital scarcity

Large banks continue to tighten their lending to fossil fuels, prompting mid-tier lenders and private equity firms to bridge the resulting funding gaps. Sustainability-linked bonds are gaining traction as operators tie coupon step-ups to methane intensity targets. Mission Secure reports that cyber-hardened facilities cut insurance costs by USD 50,000 per site each year, partially offsetting higher financing spreads.^{(3)Mission Secure, “Case Study: Midstream Cyber Resilience,” missionsecure.com} Project developers also explore public-private partnerships to align energy-security goals with environmental mandates. Delays in capital formation lead to contingency budgets and extend payback periods.

Volatile oil price outlook dampening long-term contracts

Spot-market crude swings deter shippers from locking into 10-year transportation deals, constraining pipeline earnings visibility. Counterparties favor volume-based over acreage-dedicated commitments, shifting volume risk back to operators. MLPs respond by diversifying into gas and NGL corridors that enjoy firmer demand. Hedging strategies grow more sophisticated as marketers blend physical storage with futures to manage volatility. While short-term pain suppresses tariff escalations, diversified asset portfolios cushion cash flows.

*Our forecasts treat driver/restraint impacts as directional, not additive. The impact forecasts reflect baseline growth, mix effects, and variable interactions.

Segment Analysis

By Infrastructure: Storage Facilities Drive Capacity Expansion

The oil and gas midstream market size for pipelines stood at USD 33.72 billion in 2025, equal to 45.02% share, confirming the segment’s backbone status. Storage, however, is projected to expand at a 5.14% CAGR, the fastest among infrastructure categories, as power grids need flexible gas withdrawal to balance renewable intermittency. Enstor’s Mississippi Hub expansion is expected to increase working gas to 56.3 Bcf by 2028, a 2.5-fold increase that highlights investor interest in cavern assets. EnLink’s Jefferson Island Storage will add 8 Bcf capacity under long-term take-or-pay agreements, highlighting how utility customers value seasonal balancing. Cavern projects benefit from favorable geology, low operating cost, and revenue uplift from arbitrage trading between summer injection and winter withdrawal spreads.

Terminals play a critical role in supporting LNG imports, exports, and coastal refined product distribution. Bulgaria’s Chiren facility completed a 20% capacity step-up in 2024 to fortify regional supply resilience. Dubai awarded Baker Hughes its largest integrated compressor contract for the Margham expansion to manage solar-driven demand swings. Terminal operators integrate automation and advanced metering to trim boil-off gas losses and comply with International Maritime Organization regulations. Combined, these investments expand the oil and gas midstream market by raising fee-based revenue streams and enhancing network reliability.

By Product Type: LNG Acceleration Reshapes Traditional Gas Flows

Natural gas held a 39.47% slice of the oil and gas midstream market share in 2025, reflecting its dominant throughput volume. LNG outpaces all segments with a 6.41% CAGR through 2031 as Shell projects global demand to rise 60% by 2040. China’s 79 million-tonne import volume and India’s 27 million-tonne surge in 2024 strain regasification and storage capacity, accelerating the need for pipeline tie-ins. Marine LNG demand is projected to exceed 16 million tonnes annually by 2030, driving the development of new bunkering infrastructure along major shipping lanes. U.S. Gulf Coast liquefaction terminals anchor upstream gathering systems that transport shale gas from the Permian, Eagle Ford, and Haynesville plays under fixed-margin agreements.

Crude oil volumes face contract headwinds linked to price volatility; however, pipeline optimizations and blending services help mitigate margin erosion. Refined-product corridors innovate with drag-reducing agents and real-time batch tracking to optimize line pack. NGLs benefit from petrochemical growth and propane export arbitrage. Altogether, product diversification shields the oil and gas midstream industry from cyclical exposure, maintaining growth trajectories intact.

By Service Type: Transportation and Logistics Consolidate Market Position

Transportation and logistics services captured 40.12% of the oil and gas midstream market size in 2025 and led growth at a 4.44% CAGR. Complexity in global trade flows lifts demand for end-to-end scheduling, tariff optimization, and capacity marketing. Howard Energy Partners' Nueva Era Pipeline connects Eagle Ford gas to Monterrey's industrial demand, highlighting the value of cross-border logistics. Vaquero Midstream's 70-mile extension near Waha Hub pairs with a 200 MMcf/d plant to elevate system utilization to 800 MMcf/d. Service providers layer software-defined networking and predictive maintenance to minimize downtime and monetize uncommitted capacity.

Pipeline construction and repair services secure steady workloads from replacement and expansion projects. Storage handling services leverage cavern pressure management know-how and multi-cycle withdrawal rights to extract incremental revenue. Taken together, integrated offerings reinforce customer stickiness, extend contract tenors, and deepen barriers to entry across the oil and gas midstream market.

Geography Analysis

North America's oil and gas midstream market size reached USD 22.64 billion in 2025, accounting for a 30.22% share, driven by established networks, regulatory clarity, and robust LNG export pipelines. Permian Basin gathering buildouts, such as Matterhorn Express, and Enterprise's Midland Basin acquisitions, highlight a pivot from greenfield to optimization projects. Replacement CAPEX and brownfield loopings dominate spend, while cybersecurity mandates from the Transportation Security Administration widen compliance budgets.

The Asia-Pacific region advances at a 4.74% CAGR through 2031, the swiftest among all regions, as coal-to-gas switching accelerates. Countries target household pipeline penetration and peak-shaving storage, driving demand for steel pipes and the rollout of compressive stations. LNG import share eclipses indigenous supply growth, prompting flexible contract structures indexed to Henry Hub rather than oil-linked Japan Korea Marker prices. Geopolitical diversification strategies favor U.S. and Qatari cargoes, reducing the risk of single-supplier dependence and increasing voyage-charter activity.

Europe moderates as energy-security upgrades converge with decarbonization imperatives that prioritize hydrogen networks. South America channels investment to offshore pre-salt gas monetization, notably in Brazil. The Middle East and Africa rely on modular floating LNG to monetize remote fields, while regional storage expansions act as a buffer against seasonal demand spikes. Collectively, these geographically diverse investments sustain a balanced growth profile for the oil and gas midstream market.

Regulatory Landscape

In the United States, midstream tariffs and operating requirements are shaped by Federal Energy Regulatory Commission (FERC) rate mechanisms and Federal pipeline safety oversight. In April 2026, FERC finalized the oil pipeline index for the five-year period starting July 1, 2026, setting a PPI-FG minus 0.55% index level, which affects the ceiling for indexed tariff changes on regulated oil pipelines. Separately, FERC issued a final rule in May 2026 to incorporate mandatory business practice standards for interstate natural gas pipelines (18 CFR 284.12), with compliance filings due September 1, 2026 and implementation aligned to an effective date of January 1, 2027. The changes are intended to reinforce standardized electronic nominations, scheduling, and capacity release processes for shippers.

Safety and emissions compliance also feed into integrity spending and operating procedures for pipelines and related assets. PHMSA moved to modernize anomaly response criteria for gas transmission and hazardous liquid pipelines through a July 2026 NPRM that shifts from rigid timelines to engineering-based, risk-informed response criteria (comments due September 8, 2026). This supports alignment of replacement CAPEX and integrity programs with updated risk frameworks. In Europe, policy has tightened around gas system reform and methane management: the EU adopted the decarbonized gas and hydrogen package in June 2024 (Regulation (EU) 2024/1789 and Directive (EU) 2024/1788), while the EU methane regulation entered into force in August 2024, with reporting obligations beginning to apply from September 2026 and extending compliance requirements across upstream and midstream-linked value chains for imported and domestically supplied gas.

Market Opportunities and Future Outlook

Near-term opportunity is centered on lifting utilization and margin capture from existing pipeline, terminal, and storage footprints through debottlenecking and digital optimization, especially where LNG feedgas, power-sector load, and seasonal balancing requirements increase intra-year flow variability. Storage-led flexibility remains a focal area because intermittency management increases the value of multi-cycle injection and withdrawal. Recent capacity moves referenced in the report context, including Enstor's Mississippi Hub expansion to 56.3 Bcf by 2028 and EnLink's Jefferson Island Storage addition under long-term take-or-pay agreements, point to active customer-led contracting for peak-shaving and reliability. On the liquids and terminals side, operating improvements and automation that reduce losses and increase throughput also support fee-based earnings, including Phillips 66 commissioning Advanced Process Control at its Coastal Bend facility in February 2026 to raise throughput from 121,000 bpd toward 130,000 bpd.

Regulatory and operational changes are creating whitespace for service providers and operators in compliance-heavy activities, including integrity management, cyber-hardening, and standardized commercial operations. FERC actions in 2026, including business practice standardization for interstate natural gas pipelines and the oil pipeline index reset for the July 1, 2026 period, reinforce the need for nomination, measurement, scheduling, and tariff-management capabilities that can be productized across multi-asset portfolios. At the asset level, PHMSA's July 2026 proposal to modernize anomaly response criteria supports demand for advanced inline inspection, monitoring, and engineering services that can translate risk-based requirements into repair and replacement programs. For international gas trade corridors, modular FLNG and regasification-linked midstream buildouts continue to be an actionable pathway where stranded or remote gas resources need export solutions, and where LNG-linked logistics and infrastructure partnerships can reduce balance-sheet strain for developers.