What the projects in Río Negro are going to buy

It took shale to the Río Negro side of the basin at Confluencia: proving that the formation produces commercially there is a netback decision, because every well on the edge sits closer to the profitability line than one in the Neuquén core.

Río Negro development depends on where the crude comes out, and that outlet is the corridor ending at Punta Colorada. Its activity is read by looking at the corridor's capacity as much as at the price of the barrel.

It charges a twenty-year charter rate under a tolling model: that long contract is what makes the vessels financeable, and it is also what gives the coastal supply chain a horizon —demand for services does not switch off when construction ends, it lasts as long as the charter.

Its calendar is the project's calendar: Hilli in 2027 and MK II in 2028. Everything the onshore works, the pipeline and the moorings have to deliver is ordered against those two dates, and a supplier can read its window there without waiting for any announcement.

It is Techint's partner in the joint venture that built VMOS and it lost the San Matías pipeline job to the Víctor Contreras-SICIM joint venture, whose bid was ~15 % cheaper: the local incumbent stopped winning by default in the corridor. For a supplier that means the buyer of each job can change from one tender to the next.

Its market is the laying and assembly phases, not the operating ones: it comes in when heavy construction starts and leaves before commissioning. Whoever sells to it has that same window and not the one of the whole project.

It won the San Matías pipeline job from Techint-SACDE with a bid ~15% cheaper: it is the incumbent's second defeat in the corridor, after the pipe. Open competition brought the price of the work down and changed who signs the purchase orders downstream.

As a pipeline EPC it comes in at the laying and welding phase, between May 2026 and April 2028 on San Matías. What it buys in the area —logistics, camp, testing, earthworks— is bought inside that window.

It took over Río Negro's conventional production: a mature field is the first to fall below the profitability line when the margin narrows and the first to come back when it improves. Its activity is the most sensitive reading of the netback in the whole basin.

A mature conventional asset does not buy new construction: it buys maintenance, workovers, facility repairs and surface services. It is a different market from shale, with smaller, nearby suppliers, and it is open today.

It is the country's largest pipeline builder and in the Río Negro corridor it lost two tenders in a row: the San Matías pipeline and, on the pipe side, the one to Welspun. The protection that capped the market stopped working, and the incumbent now wins or loses on price.

It built VMOS's 437 km and is building Duplicar Norte: its window is laying and assembly. The supplier that sells to it comes in at that phase, not at the operating phase of the pipeline it built.

It is the other face of openness: an Argentine basin contractor, based in Añelo, which in alliance with an international EPC beat the incumbent to the job. The gap competition opens was not captured only by imports — it was also captured by the local firm that partnered well.

A 49% partner in the San Matías pipeline joint venture: its window is the laying work, May 2026 to April 2028, and it is the tier the basin's small supply chain sells to.

It is a shareholder in both VMOS and Southern Energy: it put capital into both ways out —crude through the Atlantic and liquefied gas through the Gulf— because its output grows at the speed of evacuation and not of the well. Its plan is read by looking at the pipelines and the coast.

Putting together an LNG business with international partners requires the return to be collectable abroad: free access to foreign exchange is what turns the project into something a major is willing to sign. Without it, Vaca Muerta gas stays in the domestic market and the export plan does not exist.

Its bet is on the export business through both routes, crude via VMOS and gas via Southern Energy: both are evacuation. As long as the capacity to take the product out is the constraint, that is where its spending concentrates, and not on adding wells.

As the country's second-largest oil producer, its drilling pace moves with the netback: every improvement in relative prices at the wellhead widens the margin and pulls activity forward, with demand for sand, water, equipment and logistics behind it.

It is the dataset's textbook case for the rule: it multiplied its capex tenfold at Rincón de Aranda once it secured the crude's way out. It was not the price that moved the investment, it was evacuation — first you settle where it comes out, then you drill.

Rincón de Aranda has three stages dated in the resolution: CPF, pipelines and 50 wells through 2028; 70 wells through 2031; 139 wells through 2041. The first buys civil works and plant; the following ones, drilling and repeat logistics.