Parex Doubled Its Size and Cut Its Decline in Half — Now It Wants the Market to Agree
A Step Change Nobody Paid For
For most of the past two years Parex Resources was the Colombian oil producer running to stand still: a mid-40,000 BOE/d business with a steep base decline, a thinning drilling inventory and a share price that refused to reflect the free cash flow it generated. The third quarter of 2026 is the first clean look at what emerged from that fight. With the Frontera assets fully consolidated and the Ecopetrol Middle Magdalena farm-in beginning to earn its 50% of base production, Q3 output averaged more than 83,000 BOE/d and October ran near 86,000 — inside the maintained second-half guidance midpoint of 86,500. Funds flow from operations came in at $196 million, dented by roughly $10 million of crude inventory built in the quarter and sold after it.
The language from the top of the call was unusually declarative: “we have fundamentally changed the scale of our business, delivering a step change in production and establishing a stronger foundation” — Imad Mohsen, President and Chief Executive Officer · 2026-11-06. That is the claim. The market, on a roughly $1.35 billion market cap, does not appear to have accepted it yet — enough so that the CEO, asked about restarting the buyback, broke from prepared jargon to say “on a personal level, I can tell you it's a buying opportunity” — Imad Mohsen, President and Chief Executive Officer · 2026-11-06. When a chief executive starts making the bullish case in the Q&A rather than the deck, the gap between narrative and price is usually the story.
The Decline Rate Is the Real Prize
Strip out the production headline and the most consequential number on the call was buried mid-Q&A. The base decline — the rate at which existing wells lose output before a dollar of new capital — has collapsed.
The decline rate matters more than any single quarter's beat because it sets how much of the capital budget is consumed simply holding production flat. A 15% base means a materially smaller maintenance burden per barrel than the 25% base of a year ago — and that is the arithmetic that turns a production story into a free-cash-flow story.Last year it was close to 25%; a couple of years ago was north of 30%. To be now at [15%] decline rate by the addition of all these assets and the investments we made makes our cash flow much more predictable... as well as reducing significantly our maintenance capital.
Two engines got there. The Frontera and Middle Magdalena properties sit at the shallow end of the portfolio's decline curve, while the legacy Llanos fields are now in full enhanced-recovery mode after years of waterflood and polymer work. The other half of the equation is where the rigs go. Imad Mohsen described the reallocation plainly: “we've moved so far 3 rigs, probably 4 to come, from wells that would deliver 150 barrels a day for... $1.5 million to places like Eastern Llanos where the wells will probably cost... $3 million base... but they will produce anywhere between 1,000 and 3,000 barrels a day” — Imad Mohsen, President and Chief Executive Officer · 2026-11-06. That is capital efficiency in one sentence — double the well cost for ten to twenty times the barrel.
The Eastern Llanos corridor is the growth engine and also the current constraint. Block 111 is holding around 6,000 bbl/d because of egress, not reservoir: wet-season access has capped how fast the company can move, so a 10-inch, roughly 40,000 bbl/d pipeline and truck-offload facilities are now sanctioned to unblock it. Management guides to about 2,000 bbl/d of incremental volume by year-end and 20 wells over the next twelve months across more than 1.6 million acres at 100% working interest. The exploration record behind that plan — a 70% success rate in the Eastern Llanos and 100% across the rest of the portfolio — is the strongest support for the significant exploration success framing used throughout the call.
The Cost Asterisk
None of this came free in the quarter. FFO was squeezed by wider Vasconia-linked differentials, higher diluent and diesel, and two specifically Colombian items: peso appreciation worth about $3 a barrel on the netback and power costs worth another $2. Management's framing was that “we view many of these pressures as transitory rather than structural” — Cameron Grainger, Chief Financial Officer · 2026-11-06, and it has collared roughly half of Q4's Colombian peso exposure while starting to build 2027 cover.
Worth flagging, though, that this is a return engagement. On the November 2025 call the CFO was explaining a $2.50 OpEx spike from power costs and a 5% peso move and guiding toward “around $12 to $13 per barrel” — Cameron Grainger, Chief Financial Officer · 2025-11-04 for the following quarter. The El Niño weather pattern that lifted power prices then is doing it again now — a macro theme that has recurred in the wider market's keyword flow this year, not merely a Parex one. The bull case requires that the transitory label sticks this time; the burden of proof sits with 2027 guidance rather than the fourth quarter.
Gas, Buybacks and the December Catalyst
The quietest value driver is gas. The VIM-1 well near La Belleza tested 22 MMcf/d of gas plus 3,000 bbl/d of liquids — about 6,600 BOE/d — and will be tied into the existing facility by year-end. A dedicated export line targeted for mid-2027 would let Parex monetize up to 25 MMcf/d of currently reinjected gas into a Colombian domestic market where, as Mohsen put it, “today's spot prices are crazy. We're talking $30 MMBtu... you're thinking more closer to $15 MMBtu” — Imad Mohsen, President and Chief Executive Officer · 2026-11-06 on a longer view. This is not a fresh promise — management flagged the La Belleza gas-sales strategy as far back as mid-2025 and confirmed the pipeline path in May 2026 (“we are commencing a pipeline and expect to proceed to sales” — Eric Furlan, Chief Operating Officer · 2026-05-12). What is new is the new discovery that gives the line something to fill, and a timeline that has held rather than slipped.
Capital allocation is where the tension concentrates. Synergies from Frontera are now expected above the top of the original range — “next year, we expect more than $50 million of free cash flow extra” — Imad Mohsen, President and Chief Executive Officer · 2026-11-06 against an initial $20-50 million estimate, with more than half coming from tax. And yet the buyback stays parked: management wants debt below 0.5x first, preferring a stronger balance sheet to a cheap share price in a volatile world. The combined portfolio argument — a shallower decline base, cheaper growth barrels and a gas stream that did not exist two years ago — gets a scheduled hearing on December 9, when Parex hosts its Capital Markets Day in Colombia. Until then the shares are priced as though the step change is still a promise rather than a fact.