Mid-Year Outlook: H2 2025 Preview

Taking Stock at the Halfway Point

With Q2 2025 drawing to a close, the upstream oil and gas sector looks materially different from where consensus expected it to be six months ago. WTI has averaged roughly $71/bbl year-to-date — below the $75–80 range that most operators used for their 2025 capital budgets. Natural gas (Henry Hub) averaged $3.40/MMBtu through May, modestly above consensus, driven by cold January-February weather and LNG export strength.

The divergence between oil and gas fortunes is one of the defining stories of 2025's first half — and it's shaping how operators think about capital deployment in H2.

Oil Market: The OPEC+ Overhang

The June OPEC+ decision to accelerate production returns — covered extensively in our earlier issue — is the dominant macro variable for oil in H2. Adding roughly 1 million bbl/d of supply into a market growing at 1–1.5 million bbl/d annual demand growth doesn't leave room for inventory draws. The EIA, IEA, and OPEC's own data all point toward a flat-to-building inventory environment through Q3 and Q4 2025.

For WTI, the strip market is pricing accordingly: Q3 futures near $67–69, Q4 futures near $65–67. This is a significant haircut from where operators set their 2025 plans. The implications are real:

Capex cuts are coming. Multiple operators have telegraphed flexibility to reduce activity if prices deteriorate further. Devon Energy has the most publicly explicit framework: they guide to reducing activity at sub-$65 WTI on a sustained basis. Others operate similarly but communicate it less directly.

DUC inventories will build. When economics tighten, operators tend to slow completions faster than drilling, allowing drilled-but-uncompleted well inventories to accumulate. This isn't necessarily bad — DUCs are optionality on price recovery — but it signals caution about near-term production growth.

Natural Gas: A Brighter Half

The natural gas outlook for H2 2025 is more constructive than oil. Several factors align:

LNG export growth. U.S. LNG export capacity is operating near nameplate capacity (~14 Bcf/d) with demand pulled by strong Asian spot prices and European supply concerns. Sabine Pass Train 7 and the Golden Pass LNG project (ExxonMobil/QatarEnergy) are advancing toward commercial operations, with first volumes possible by late 2025.

Utility demand for power generation. The AI data center buildout has become a genuine near-term driver of electricity demand. Natural gas accounts for roughly 43% of U.S. power generation. Major hyperscalers (Microsoft, Google, Amazon) have all executed utility-scale power purchase agreements that ultimately pull gas demand. This wasn't in the 2024 forecast models; it's a real incremental driver.

Structural storage trajectory. Natural gas storage ended the 2024–2025 withdrawal season below the 5-year average — the first time since 2021. Storage injections through summer 2025 will need to be above-average to normalize inventory by November. That provides price support in the $3.20–3.80/MMBtu band.

Capital Budget Scenarios for H2

Running the numbers at two price scenarios:

Base case ($68 WTI / $3.40 Henry Hub): Upstream capex holds near H1 levels with modest efficiency improvements. Rig count stabilizes around 580–600 (currently 583 per Baker Hughes). Free cash flow is positive but muted. Return of capital programs continue at reduced pace.

Bear case ($60 WTI / $2.80 Henry Hub): Capex cuts of 10–15% from original budgets. Rig count falls to 520–540. Completions activity drops faster than drilling. H2 production guidance reductions begin appearing in Q3 earnings calls. M&A activity spikes as stressed operators become available.

Themes to Watch in H2

M&A momentum continues. The deal cycle that began in 2023 hasn't exhausted itself. Mid-cap operators with sub-premium acreage — Civitas Resources, Callon Petroleum (now part of APA), Vital Energy — remain consolidation candidates. Watch for deals announced in the Q3 window as operators use equity at current multiples before year-end portfolio decisions.

Gas basin differentiation. Haynesville operators will outperform Appalachian peers on a realized price basis through H2 as LNG pull tightens Gulf Coast basis differentials. Expand Energy and Comstock Resources are the primary beneficiaries.

Technology capex rises as operating capex falls. Operators are investing in digital twins, AI-driven well optimization, and real-time production surveillance even as they cut drilling budgets. The efficiency imperative doesn't pause during price downturns — it intensifies.

H2 2025 will test whether the capital discipline of the past four years is structural or situational. The answer will shape how this industry enters 2026.

Crude Intelligence Report is an independent upstream oil and gas intelligence publication. Content is for informational purposes only and does not constitute investment advice, financial advice, or a recommendation to buy or sell any security. Always conduct your own due diligence before making investment decisions. The author and publisher hold no positions in any companies mentioned in this article. © 2026 Crude Intelligence Report. All rights reserved.