OPEC+ Year-End Meeting: 2026 Production Policy
OPEC+ wrapped up its year-end policy meeting in early December with an outcome that surprised very few people who have been paying attention: another extension of existing voluntary cuts, a delay in unwinding the production restraints that have been in place since late 2023, and language vague enough to provide cover in either direction. The group will convene again in Q1 2026 to reassess.
What Was Decided
The eight OPEC+ members that had pledged voluntary cuts of approximately 2.2 MMbbl/d — led by Saudi Arabia and including Russia, UAE, Kuwait, Kazakhstan, Iraq, Algeria, and Oman — extended those cuts through at least Q1 2026. The original unwind timeline, which had proposed a gradual return of 180 Mbbl/d per month starting in late 2025, was pushed back for the third consecutive time.
Saudi Arabia's Energy Minister Prince Abdulaziz bin Salman made clear that the group retains the flexibility to pause, reverse, or accelerate any unwind. The message was directed as much at recalcitrant members — Kazakhstan and Iraq have consistently overproduced relative to their quotas — as it was at the market.
The broader OPEC+ group, which includes the core cartel members plus Russia and its affiliated producers, collectively holds notional output near 43 MMbbl/d on paper. Actual production, accounting for overproduction and voluntary cuts, runs closer to 40–41 MMbbl/d. That restraint is the floor under crude prices.
The Compliance Problem
OPEC+ compliance has been deteriorating for the better part of two years. Iraq pumped approximately 4.3 MMbbl/d through much of 2025 against a quota of roughly 4.0 MMbbl/d. Kazakhstan, producing from the giant Tengiz expansion operated by Chevron, has been similarly inconsistent. The group's internal monitoring committee has logged overproduction exceeding 500 Mbbl/d on a combined basis in multiple months.
The mechanism for accountability within OPEC+ is compensatory cuts — members who overproduce are expected to cut more deeply in subsequent months. The track record on compensation is, charitably, mixed. Saudi Arabia has repeatedly signaled its frustration privately while avoiding a public confrontation that would destabilize the alliance.
For U.S. producers, the compliance issue is meaningful. Every barrel of overproduction from an OPEC+ member that is not offset by Saudi restraint adds supply pressure to a market that is already well-supplied. The IEA has estimated global oil inventories were roughly 100 MMbbl above the five-year average entering Q4 2025.
The 2026 Unwind Question
The central issue for 2026 is whether OPEC+ can begin unwinding its voluntary cuts without crashing prices. The math is not flattering. A gradual return of the full 2.2 MMbbl/d over 12 months would add roughly 180–200 Mbbl/d of new supply per month to a market where demand growth is expected to be 80–90 Mbbl/d per month. Net result: every month of unwind adds incremental inventory.
Saudi Arabia's fiscal breakeven — the oil price needed to balance the kingdom's budget — is estimated at $85–$90/barrel by the IMF. With WTI averaging in the low-to-mid $70s through 2025, Riyadh has been drawing on its sovereign wealth fund to cover the gap. That is sustainable in the near term but creates pressure to either raise prices or produce more volume. Neither option is easy.
Our read: OPEC+ extends cuts through at least Q2 2026, with any unwind pushed to the back half of the year at the earliest. Saudi Arabia does not want to test the market's appetite for additional supply heading into what could be a well-supplied first half. The full 2.2 MMbbl/d return remains unlikely in 2026.
Implications for U.S. Upstream
A WTI price held in the $70–$80 range by OPEC+ restraint is workable for most U.S. operators but does not incentivize meaningful activity expansion. The all-in breakeven for new Permian development — drilling, completion, and infrastructure — sits around $45–$55 per barrel for top-tier acreage. At $70 WTI, there is margin; at $65, the math gets uncomfortable for smaller operators and higher-cost basins.
The more interesting dynamic is basis differentials. Midland crude has traded at a premium to WTI Cushing for much of 2025 as pipeline capacity improved, while Waha Hub natural gas has returned to near-flat or slight discounts versus Henry Hub after the worst of the congestion in 2023–2024. Those differentials matter at the wellhead level.
For 2026, watch the February OPEC+ meeting closely. If the group shows any softening on cuts — even modestly — expect WTI to test the lower end of the range. If compliance tightens and Saudi holds firm, the price floor holds. The U.S. rig count will follow the commodity, not lead it.
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.