YPF Has Finished Becoming a Shale Company. Now It Wants to Be Argentina's Balance Sheet.
Record liquidity, 0.81x leverage and a $44 billion RIGI filing — yet the CEO still won't give a 2027 number until April, and the pump price has quietly become a social contract.
YPF · Earnings Call · 2026-10-29
A quarter that closes a three-year argument
For three years Horacio Marín has told anyone who would listen that YPF would stop being an Argentine integrated oil company and become a shale exporter. The third quarter is the receipt. Revenue of $6.6 billion rose 41% year over year; adjusted EBITDA of $2.5 billion rose 84% and was the second-highest in company history; the margin held at 38%; free cash flow reached $901 million, also a second-best. Conventional oil fell 47% year over year to roughly 37,000 bpd — and would have been about 17,000 excluding the Mendoza blocks now under contract — which means, in Marín's framing, that “about 95% of our oil output would have come from shale” — Horacio Marín, CEO or President · 2026-10-29. Shale averaged 224,000 bpd, up 32% year over year, with October preliminary figures above 245,000 and a single-day print of 252,330 bpd cited on the call. The balance sheet moved just as far. Net leverage fell to 0.81x from 1.1x in June and 2.1x a year ago — the lowest in more than a decade — while a strong liquidity position of $3.7 billion covers more than 2.5 years of maturities. The $1.2 billion nine-year bond at a 7.85% yield, 300bp over Treasuries, was the largest Argentine corporate issuance in eleven years and drew $2.2 billion of demand. That is not a distressed Argentine issuer's outcome; it is a company that has convinced the international market it is a shale operator with a sovereign attached, rather than the reverse. The operational detail underneath is what makes it credible rather than lucky. Drilling speed in the oil hub hit roughly 354 metres per day, up 29% versus 2023, completions ran 11.1 stages per day, and a new lateral length record of 4,770 metres was set in a single run. Lifting cost fell to $7.8 per BOE, below $7 excluding the divestment blocks, against $4.2 in the core hub.The bottleneck moved — and so did the ambition
Here is the subtle shift worth flagging. In May, Marín told analysts the constraint on growth was logistics: “we are going to reach the bottleneck of the evacuation between October and November” — Horacio Marin, Chief Executive Officer · 2026-05-09. Five months later the constraint has migrated inward: “not because of financing, because of bottlenecks in evacuation. Not in the oil pipe, but in facilities” — Horacio Marín, CEO or President · 2026-10-29. That is a different answer, and it is the closest thing on the call to an explanation for why YPF will not accelerate into a strong Brent tape even though, as Pickering's analyst put it, acceleration looks "highly compelling." The new La Angostura Sur integrated facilities — roughly $400 million, 60,000 bpd of oil and 4 million cubic metres of gas per day, started up in September — are the fix in progress, not yet the fix delivered. The ambition, meanwhile, has been re-based on a much larger number. The RIGI project for the North Hub covers five blocks, about $44 billion of gross capex over 16 to 26 years, roughly 2,200 drilling locations and a plateau of ~270,000 bpd of oil plus 28 million cubic metres per day of gas. At $70 Brent and $3.50 gas it would generate about $8.2 billion of gross revenue a year; YPF's average stake is around 40%. Add LLL Oil and the company says it has filed close to $70 billion of upstream investment under RIGI — a figure that should be read as a statement about partner capital, not YPF's own balance sheet. Against that, the refusal to give a 2027 number is striking. “you will be very surprised of the production of Vaca Muerta in December of 2027” — Horacio Marín, CEO or President · 2026-10-29, the CEO said — twice — before declining to quantify it pending board approval of next year's budget. This is a recurring construction, not a new dodge: as far back as February he was saying “next year in April, we are going to go to New York” — Horacio Marin, Chief Executive Officer · 2026-02-27, and every call since has pointed at the same April investor day. The date has held. What has changed is the weight it now carries: an entire growth story, an LNG FID and a rig-count increase from 18 to 22 by February all roll forward to a single presentation.The records, for me, the record are not important for the newspaper. I don't care. The record, what is important is you make more knowledge and you pass what you think is your limit.
The pump price has become policy
The most under-appreciated change on this call is in downstream. Local fuel prices sit roughly 20% below import parity, held there by a buffer scheme in which YPF absorbs the gap when international prices spike and recovers it when they fall. In May the CEO was confident that arbitrage would resolve itself: “I don't see a problem to pass through” — Horacio Marin, Chief Executive Officer · 2026-05-09. In October the language is different: demand outside Buenos Aires has become elastic, and "we cannot increase more than that." That is a real shift in the pricing regime, and it converts domestic demand protection from a tactical tool into a standing obligation.It has been enormously profitable so far — downstream margins of about $32 per barrel, record premium gasoline production, no fuel imports, 58% market share and 61% including third-party stations — but the asymmetry is now explicit. If Brent stays high, YPF finances Argentine consumption, and the recovery is deferred to a price decline nobody on the call could forecast.When the prices, they are up, we have two Vice Presidents that they calculate every day how much we finance the people. When they go down, we are collecting what we finance. That is the way that is going to continue.