Who Is Investing in Vaca Muerta? Where the Capital Is Actually Going

The Investment Map: Capital at Different Stages

The easiest way to overstate Vaca Muerta investment is to add every headline number together. The projects below do not represent the same level of financial commitment.

A useful capital map therefore needs at least five categories: upstream development, transport and processing infrastructure, acquisitions and portfolio rotation, financing, and supplier or service capacity.

Upstream Capital: Who Is Expanding Production?

Vaca Muerta reached 643,100 barrels of oil per day in July 2026, up 26.4% from July 2025. Gas production from the formation reached 96.5 million cubic metres per day, up 5.9% year on year. That production growth explains why capital is moving into both new wells and the infrastructure required to evacuate additional volumes.

YPF remains the central company in the development system. Management indicated that 2026 investment would reach roughly US$5.5–5.8 billion, with about 70% directed to unconventional operations. YPF is also a central shareholder or partner in VMOS and major LNG projects, making it difficult to separate its upstream role from the wider Vaca Muerta export build-out.

Tecpetrol has one of the clearest new upstream commitments. Its Los Toldos II Este project was admitted to RIGI with a total investment plan of US$6.4 billion. More than US$2 billion is expected to be deployed through the end of 2027, and Tecpetrol targets around 70,000 barrels per day from the project by mid-2027.

Pampa Energía received RIGI approval for Rincón de Aranda in July 2026. The investment plan totals approximately US$4.522 billion through 2041 and includes 259 wells, a processing plant with capacity for 45,000 barrels per day of crude and 800,000 m³/day of gas, plus oil, gas and water infrastructure.

Chevron is potentially larger again. In June 2026 the company submitted an application under RIGI for a US$13.8 billion El Trapial development plan. The project is intended to increase production at El Trapial Este from roughly 7,000 to 30,000 barrels per day.

The RIGI application is not the only Chevron capital signal. During 2026, Chevron also completed two capital increases in its Argentine subsidiary with a combined reported value of approximately US$444 million. This provides a useful distinction: the US$13.8 billion plan remains under evaluation, while separate capital has already moved into the Argentine corporate vehicle supporting the business.

Vista Energy is expanding partly through acquisition. Its May 2026 purchase of interests previously held by Equinor added a 25.1% non-operated interest in Bandurria Sur and 35% in Bajo del Toro.

The transaction had an initial purchase price of approximately US$712 million, consisting of cash and Vista ADSs, with a further US$131 million paid for cash, debt, working-capital, contribution, leakage and other customary adjustments. Vista's filings estimate that the acquired portfolio adds 27,733 net acres and approximately 243 net drilling locations. The acquisition price should be separated from the development CAPEX that will later be required to drill those locations.

Pluspetrol is another capital-rotation case that has moved into development. It acquired majority interests in former ExxonMobil-linked Vaca Muerta assets and is expanding La Calera and Bajo del Choique–La Invernada. In February 2026 the company issued US$167.4 million of notes specifically to continue developing those two assets.

Pan American Energy deserves a separate place in the capital map. PAE operates six areas in the Neuquén Basin and has built shale-oil and shale-gas development across Lindero Atravesado, Coirón Amargo Sureste, Bandurria Centro, Aguada Cánepa, Aguada Pichana Oeste and Aguada de Castro. Its current operating portfolio includes dozens of producing unconventional wells as well as oil and gas treatment, compression and transport infrastructure.

PAE is also a shareholder in both VMOS and Southern Energy. That gives it exposure across production, crude export infrastructure and LNG, rather than through one isolated upstream development.

A newer foreign entrant is Continental Resources. In August 2026 it agreed terms to acquire 50% of Phoenix Global Resources and form a 50/50 operating platform with Mercuria. The proposed platform would hold about 163,000 net acres across six Vaca Muerta blocks and expects more than US$4 billion of capital deployment over five years. The transaction remains a planned expansion rather than completed multi-year expenditure.

The Second Investment Wave: Midstream and Export Infrastructure

More wells only create commercial value if oil and gas can move out of the basin. That makes midstream investment inseparable from the upstream capital story.

VMOS: a dedicated oil-export system

Vaca Muerta Oil Sur, or VMOS, is the largest dedicated crude-export infrastructure project now under construction for the basin. The core Allen–Punta Colorada pipeline runs approximately 437 km and connects with storage and offshore loading infrastructure at the Atlantic coast in Río Negro.

The important point is the capacity ramp. VMOS expects initial operations at around 180,000 barrels per day toward the end of 2026, followed by progressive expansion during 2027 toward 550,000 barrels per day. Further expansion above that level would require additional infrastructure and should be treated as an option rather than current base capacity.

Project-cost figures also depend on the definition used. The RIGI approval was based on an investment amount of approximately US$2.9 billion, while VMOS originally communicated an initial project investment of around US$3 billion. More recent financing reporting places the overall project requirement at approximately US$3.3 billion.

That difference is not trivial. It shows why RIGI-eligible investment, original budget and current project financing requirement should not automatically be treated as the same number.

VMOS also connects directly with Econosur's analysis of the Pacific export route for Vaca Muerta. Export infrastructure is no longer one corridor. Argentina is building Atlantic capacity while Chile remains relevant as a Pacific-facing outlet.

TGS: gas transport and NGL processing

TGS reached final investment decision in June 2026 on a US$3 billion NGL project. It includes new facilities at Tratayén, a gas-stream segregation pipeline, a products pipeline to Bahía Blanca, fractionation and storage facilities, and complementary export-terminal works.

More than 80% of the project's capacity is already covered by agreements with YPF, Pluspetrol and Chevron. TGS explicitly links the project to a production bottleneck: associated gas has to be processed and evacuated if oil production is to continue scaling.

TGS is also responsible for the RIGI-approved expansion of the Gasoducto Perito Francisco Pascasio Moreno. The RIGI approval assigns the project an investment value of US$550 million and 14 million m³/day of incremental transport capacity in the Tratayén–Salliqueló section.

Other public estimates of the wider expansion have reached roughly US$700–800 million because they use a broader project perimeter. The difference is a concrete example of why project-cost definitions need to be stated rather than silently combined.

Oldelval: Duplicar Norte

Oldelval's Duplicar Norte adds another oil-evacuation layer. The project involves a new 207 km, 24-inch pipeline and approximately US$380 million of investment between the northern production area and Allen.

Oldelval expects early commissioning toward the end of 2026 and definitive operation during the first quarter of 2027. The project integrates with the existing Oldelval system and VMOS, increasing the ability of northern Vaca Muerta production to reach refining, storage and export infrastructure.

LNG: two different export chains

Vaca Muerta's investment map also extends into LNG, but two distinct project structures need to be separated.

Argentina LNG is being developed by YPF, Eni and XRG as an integrated upstream, transportation, processing and floating-liquefaction system. Eni signed an agreement in June 2026 to acquire 32% in Meseta Buena Esperanza, Aguada Villanueva and Las Tacanas. Subject to completion, YPF would hold 36%, Eni 32% and XRG 32%.

The upstream assets are designed to feed two FLNG units with combined initial capacity of 12 million tonnes per year. The project submitted its RIGI application in August 2026 and targets final investment decision toward the end of 2026. It should therefore still be treated as a pre-FID project.

Shell had previously participated in an earlier pre-FEED phase of Argentina LNG but withdrew after the project scope changed. That is a confirmed project-level exit and should be separated from the separate, disputed reports about a possible sale of Shell's upstream Vaca Muerta assets.

The second LNG chain is Southern Energy. Its ownership is Pan American Energy 30%, YPF 25%, Pampa Energía 20%, Harbour Energy 15% and Golar LNG 10%.

The first vessel, FLNG Hilli Episeyo, is expected to begin operations around the end of 2027 under a 20-year charter. The second unit, now referred to as FLNG Esperanza, is expected to follow in 2028. Together the two units are designed for approximately 6 MTPA of LNG capacity.

Golar reported around US$1.4 billion invested in the conversion program by mid-2026. Southern Energy therefore provides a useful contrast with Argentina LNG: one project has already taken FID on its vessels and is moving toward operations, while the larger YPF-Eni-XRG chain remains pre-FID.

The gas-export question also connects directly with Econosur's Vaca Muerta–Brazil gas corridor analysis. LNG and regional pipeline exports serve different markets and financing structures but ultimately depend on the same underlying expansion of gas production and transport capacity.

Capital Rotation: Who Is Entering, Who Is Selling?

Vaca Muerta investment is not only greenfield capital. Some of the largest recent transactions involve existing assets changing hands.

Shell illustrates why project exit and corporate exit need to be separated. Shell withdrew from an earlier phase of Argentina LNG, which is a completed project-level decision. Separately, Reuters reported in January 2026 that Shell was exploring a possible sale of its upstream Vaca Muerta assets. Shell executives subsequently rejected reports that a sale process was under way, and Shell Argentina told the Neuquén government that it intended to continue operating. Without a completed transaction, Shell should not be classified as having exited Vaca Muerta.

Who Is Financing Vaca Muerta?

The investment map becomes more revealing when the source of capital is added. Vaca Muerta is being financed through corporate cash flow, bonds, shareholder contributions, acquisition facilities and international project finance.

VMOS reopened international project finance

VMOS signed a syndicated international financing facility of up to US$2 billion in July 2025. It has a five-year term and carries a rate of SOFR plus 5.5%.

The financing was led by Citi, Deutsche Bank, Itaú, JPMorgan and Santander and included another 14 banks and institutional investors. VMOS described the transaction as the reopening of Argentina's international project-finance market after its closure since 2019.

The facility is designed to finance roughly 70% of the required project capital, with the remaining 30% supplied through shareholder equity.

The financing should also be read by drawdown stage. As of June 30, 2026, VMOS reported approximately US$1.37 billion of financial debt and around US$597 million of shareholder capital contributions. The planned total shareholder contribution is roughly US$900 million. A further local debt tranche of around US$300 million has also been prepared to complete the financing structure.

The current shareholder structure also shows how broadly the project distributes capital exposure across the industry: YPF 29.82%, Pluspetrol 14.55%, Chevron/CDC 12%, Pan American Energy 10%, Vista 9.09%, Pampa Energía 9.09%, Shell 7.27%, Tecpetrol 7.27% and GyP Neuquén 0.91%.

That structure matters because VMOS is not simply a pipeline built by one operator. It is shared export infrastructure backed by several of Vaca Muerta's main producers and their future transport commitments.

Corporate, bond and acquisition financing

Pluspetrol's February 2026 US$167.4 million Class 6 notes provide a smaller but clearer example of capital-market funding linked directly to Vaca Muerta development. The company states that proceeds are being used for La Calera and Bajo del Choique–La Invernada.

Vista's Equinor acquisition shows another capital channel. The US$712 million initial transaction consideration was funded through cash and Vista equity, while financing arrangements around the transaction included access to a syndicated facility of up to US$600 million.

Golar adds the asset-finance dimension. Its investment in the floating liquefaction fleet sits alongside Southern Energy's upstream supply commitments and long-term vessel contracts, connecting vessel finance with Argentine gas production.

Supplier and Service Investment: Capital Before the Well Produces

Supplier investment is another part of the Vaca Muerta build-out. Service companies need equipment and local operating capacity before producers can execute large drilling programs.

Tenaris started operating its third hydraulic-fracturing set in August 2026 after a US$110 million investment. The equipment is deployed at Tecpetrol's Los Toldos II Este field for an initial 18-month service period.

Tenaris says it has invested more than US$240 million since 2020 in developing and expanding its Argentine oilfield-services operation. This illustrates the second-order effect of upstream capital: a producer's drilling plan becomes a capacity decision for contractors, equipment operators, logistics providers and industrial suppliers.

Nabors provides another indicator of the scale of the service layer. The company expects around 15 active drilling rigs in Argentina during the second half of 2026, with Vaca Muerta driving much of the activity.

That distinction is particularly relevant to the Econosur European Suppliers and Vaca Muerta brief. A project headline does not automatically equal an open supplier opportunity. Procurement structure, incumbent relationships, qualification requirements, local execution and project timing determine when investment becomes addressable demand.

RIGI: A Useful Investment Filter, Not a Cash Counter

Argentina's Régimen de Incentivo para Grandes Inversiones has become one of the main frameworks through which large Vaca Muerta projects are presented and approved.

By September 18, 2026, 48 projects across sectors had been submitted to RIGI. Of these, 23 had been approved with stated investment of approximately US$49.766 billion, while another 25 projects representing US$159.713 billion remained under evaluation.

Several important Vaca Muerta-linked projects sit inside this framework. Tecpetrol's Los Toldos II Este and Pampa Energía's Rincón de Aranda are approved. TGS's Perito Moreno expansion is approved. Argentina LNG remains in evaluation. Chevron's El Trapial plan remains an application rather than an approved project.

Econosur examines the wider execution issue in RIGI and Argentina's Energy Execution Question. The central distinction remains the same: incentives can improve project conditions, but commercial execution still depends on capital, construction, infrastructure, contracting and markets.

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Marcus A. Volz

Marcus A. Volz is a market analyst and international B2B consultant based in Argentina since 2006. His work focuses on South American companies, projects, supply chains, infrastructure, procurement and the commercial structures behind market development.