Gulf of America Pipeline Snag Trimmed Occidental Output in September

Occidental Petroleum kept total company production inside its guidance range for the latest quarter despite temporarily curtailing output at certain Gulf of America facilities in September, according to a mid-October pre-earnings filing with the SEC. The culprit was operational, not geological: a constraint on a third-party gas pipeline, compounded by maintenance work. Only part of the affected volume has returned, and the rest is expected back once the pipeline issue clears.

Full results land Monday after the market closes, with a conference call scheduled for Tuesday afternoon Eastern time. A webcast runs through the investor section of Occidental's website, and a recording posts several hours later.

What exactly did the filing say?

The document was an exhibit to a current report — a quarterly earnings-item disclosure that Occidental has published ahead of earlier reports as well. It lists items management expects to affect results, and the company flagged that it is not a complete statement of the quarter. Numbers remain subject to finalization.

Even so, the data points give analysts the raw material for models. The most newsworthy item in the exhibit was a problem rather than a milestone.

What went wrong in the Gulf of America?

Per the filing, the company temporarily curtailed production at certain Gulf of America facilities in September, citing two causes:

• a constraint on a gas pipeline owned and operated by a third party;
• maintenance activities at the affected facilities.

Output has been partly restored. The remainder should return once the pipeline constraint is resolved.

Offshore Gulf production is a minority of company-wide output — but a valuable one, because those barrels are oil-rich and carry higher unit margins than onshore wells with heavy gas content.

How did prices and hedges shape the quarter?

Realized oil prices came in close to the West Texas Intermediate benchmark, while domestic natural gas realizations stayed weak. Realized natural gas liquids prices represented a meaningful share of the crude benchmark on a per-barrel basis.

Oil made up roughly half of total company production in the quarter, with natural gas liquids and gas accounting for the rest. That mix reflects Occidental's large Permian Basin position in Texas and New Mexico, where wells deliver plenty of associated gas and liquids alongside crude.

The hedges worked against cash flow. Settlements on crude oil collars reduced operating cash flow before working capital in the quarter. A collar sets both a floor and a ceiling on price — and when the market trades above the ceiling, the company pays the difference to the counterparty.

Why do Permian gas prices matter so much here?

The Permian produces far more associated gas than local pipelines and processing plants can always absorb. When takeaway capacity tightens, basin gas can trade at deep discounts to the national benchmark and has even turned negative for stretches — a dynamic visible in the company's mid-year figures. A producer with a Permian footprint the size of Occidental's feels that pinch directly.

The company's midstream and marketing segment — which gathers, transports and markets its own and third-party volumes, and includes equity earnings from Western Midstream — sits between those dynamics and the balance sheet.

On capital returns, Occidental has laid out a clear priority order: pay down debt first, then raise distributions.

What's the watch item?

Monday's close. The confirmed production number, the pace of Gulf restoration, and the size of the collar drag on operating cash flow are the three figures to check when the full release drops.

By Elena Vasquez, Rig & Refinery