The Gulf’s most aggressive capacity builder is done taking quota instructions — spare capacity is now a sovereign strategy, not a cartel asset.

OPEC just lost a capacity-growth member with real barrels, real export optionality, and a long-running quota grievance. The market read is straightforward; the governance read is messier — cohesion is fraying at the same time U.S. shale discipline holds and Gulf volatility climbs.

• The UAE will exit OPEC and OPEC+ on May 1, 2026, ending a membership that began when Abu Dhabi joined in 1967 and continued after the UAE’s formation in 1971; the UAE has produced about 3.4 MMbbl/d (~13% of OPEC output) and held ~5 MMbbl/d of capacity before the U.S.-Iran war disrupted the Strait of Hormuz.

• Abu Dhabi has been pouring capital into capacity precisely while OPEC+ held output back — leaving the country with under-monetized barrels and an obvious incentive to set its own pace outside Saudi-led quota management.

Shell is buying Montney molecules, liquids uplift, and LNG Canada optionality without lifting its capex ceiling.

• Shell agreed to acquire ARC at US$13.6B equity / US$16.4B EV (incl. US$2.8B debt + leases) — C$8.20 cash + 0.40247 Shell shares per ARC share, a 25% cash / 75% stock mix — adding 370 kboe/d, ~2B boe of 2P reserves, and 1.5M net Montney acres on top of Shell’s existing 440,000 acres.

• The strategic frame is LNG: Shell owns 40% of LNG Canada, production CAGR steps from ~1% to ~4% through 2030, the $20–22B capex ceiling holds, and Shell guides to ~$250M of annualized synergies within a year of close.

Six days before Devon and Coterra stockholders vote on May 4, Kimmeridge wants the new board to act on day one.

• Mark Viviano dropped Kimmeridge’s open letter on April 28, six days before the May 4 stockholder vote that finalizes the $58B EV Devon–Coterra merger (close expected within days), with three explicit asks: an accelerated non-core divestiture program, a refocus of capital on the Delaware Basin core, and a “blank sheet” reset of executive compensation grounded in Kimmeridge’s 2020 white paper.

• The framing is a “conglomerate discount” the new board has the power to close on day one; the letter follows Kimmeridge’s earlier governance-focused letter to the legacy Coterra board pushing the same reset.

The Permian is still throwing off enough wet gas to underwrite midstream capex — even with producers talking discipline.

• Enterprise will build two 300 MMcf/d Permian processing plants — one Midland, one Delaware — both online in 2027, lifting Permian processing capacity another 12%; management guides Permian gas + NGL growth to run 1.6x crude growth.

• Q1 confirms the demand: record 8.3 Bcf/d processing inlet (+7% YoY), $2.7B adjusted EBITDA, $988M Q1 capex, and $2.3–2.6B of 2026 growth capex guidance net of $596M asset-sale proceeds.

The new utility pitch: data centers and industrial load can fund rate base and soften the bill hit — if regulators buy the math.

• Per Reuters, CMS raised its capex plan to ~$24B through 2030 from a prior $20B, citing rising power demand; Q1 adjusted EPS came in at $1.13 (vs. $1.02), 2026 guidance reaffirmed at $3.83–$3.90, and long-term growth held at 6–8% with “continued confidence toward the high end.”

• The fight is cost allocation: more load can help every ratepayer, but poorly structured load shifts costs to every ratepayer — and DTE’s parallel argument out of Michigan suggests this is now a regional template, not a CMS-only experiment.

An oilfield logistics company is being repriced as a behind-the-meter data-center power platform.

• The deal: 600+ MW of power capacity + balance-of-plant for an investment-grade global tech affiliate, 10-year term with a 5-year extension option, deployments starting late 2026 through 2028 — Solaris’ third long-term IG tech contract, taking total contracted capacity past 2 GW.

• Q1 backs the pivot: pro forma generation fleet steps to 3.1 GW after 900 MW of previously announced additions; $196M revenue, $32M net income, ~$84M adjusted EBITDA (+22% sequentially).

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