More than $30 billion in announced private investment, spread across seven concurrent infrastructure projects anchored in the Vaca Muerta formation, one of the world's largest shale plays in Argentina's Neuquén Basin, is repositioning Argentina from a regional energy producer to a competitive supplier of liquefied natural gas, crude oil, and natural gas liquids in Atlantic and Asian markets.
Argentina's advantage in the current global context is geographic: its Atlantic export routes bypass both the Strait of Hormuz and the Suez Canal, an advantage that has become increasingly material as Middle East supply disruptions have reshuffled global energy trade flows since early 2026. The seven projects span the full upstream-to-export value chain, a reversal from the energy deficit years of 2011–2022, when Argentina spent billions annually importing LNG and refined products despite holding world-class reserves.
1. Argentina LNG: The $30 Billion Bet on Atlantic Gas Exports
The largest project in the current infrastructure cycle is the Argentina LNG project, a phased LNG export initiative led by YPF, Argentina's state-controlled oil and gas company, in partnership with ENI, the Italian energy company, and XRG, ADNOC's international investment arm. Total investment is estimated at approximately $30 billion, with a final investment decision (FID) targeted for the second half of 2026.
The project calls for a liquefaction plant at the Punta Colorada terminal on Río Negro province's Atlantic coast, integrated with dedicated large-diameter gas transmission pipelines to move volumes from the Neuquén Basin. The facility is engineered to allow Argentina to compete in transatlantic and Asian LNG markets directly, offering an alternative supply source alongside established exporters.
The most significant recent development came at Bank of America's Argentina Week, an annual investor forum focused on Argentina's energy and macroeconomic outlook, held in New York: an active high-level banking round aimed at securing financial close for the project's initial phases, focused on floating liquefaction units and subsequent permanent onshore facilities. Sustained interest from international banks confirmed that Argentina LNG has moved from technical feasibility into active financial structuring, significant in a country that has historically struggled to attract long-term capital commitments to energy infrastructure, a pattern the administration of President Javier Milei has sought to break through Argentina's Large Investment Incentive Regime (RIGI), a tax and regulatory stability framework designed to attract long-cycle capital to energy projects.
2. Southern Energy: First Exports by 2027 via Floating Liquefaction
Southern Energy, the consortium created to execute the first phase of Argentina LNG, comprises Pan American Energy (PAE), Argentina's largest private oil producer; YPF; Pampa Energía, a diversified Argentine energy company; Harbour Energy, the U.K.-based E&P company; and Golar LNG, the Norway-based LNG infrastructure company.
The consortium is targeting 6 MTPA of LNG exports from two floating LNG units (FLNGs) moored in the Golfo San Matías, a deepwater gulf in Argentina's Río Negro province suited to loading large-scale vessels. The FLNG approach was selected specifically for its execution speed: floating liquefaction units can be deployed and commissioned significantly faster than permanent onshore plants, which is why Southern Energy is the most immediate LNG export initiative currently active in Argentina.
In Berlin, Southern Energy signed its first commercial export contract with SEFE Securing Energy for Europe, committing to 2 MTPA over eight years with deliveries scheduled to begin in late 2027. Golar LNG owns both floating liquefaction vessels. The Hilli Episeyo is completing its current contract in Cameroon, scheduled to conclude in July 2026, after which it will enter the Seatrium shipyard in Singapore for maintenance, life extension, winterization, and installation of a new mooring system before arriving at the Golfo San Matías for commercial operations in the second half of 2027. The MKII, with a nameplate capacity of 3.5 MTPA, is under conversion at the CIMC Raffles shipyard in Yantai, China, with commercial operations targeted for end-2028.
3. VMOS: Clearing the Crude Bottleneck to the Atlantic
The Vaca Muerta Oil Sur pipeline (VMOS) is a more than $2.5 billion crude export project led by YPF and strategic partners, now 58% complete as of end of March 2026. The 437-kilometer pipeline, managed by SACDE, an engineering and construction subsidiary of the Techint Group, will carry Neuquén Basin crude to a new export terminal at Punta Colorada in Río Negro province.
The project recently completed a major engineering milestone: the crossing of the Río Negro river via horizontal directional drilling (HDD), preserving environmental and operational integrity across one of the route's most complex sections. The current schedule targets first exports in December 2026 at an initial capacity of 180,000 bbl/d, with full ramp to 390,000 bbl/d by mid-2027. The Atlantic terminal will feature single-point mooring buoys designed to load large-draft vessels, enabling Argentina to supply crude to refiners in Europe and Asia without routing through either of the world's two principal maritime chokepoints. Projected export revenues once operational exceed $15 billion.
4. TGS NGL Project: Monetizing Gas Liquids at Scale
Transportadora de Gas del Sur (TGS), Argentina's main southern gas pipeline operator and the company behind the Vaca Muerta gas processing complex at Tratayén, confirmed at Argentina Week a $3 billion capital commitment to expand its natural gas liquids (NGLs) processing and transport capacity. The project targets separation of the highest-value components of Vaca Muerta gas (ethane, propane, and butane) before export, maximizing per-unit export value. It is structured around three sequential workstreams.
The first involves expansion at Tratayén, Neuquén province, through the addition of two new conditioning modules to the existing two, lifting total processing capacity to 43 MMm³/d from the 28 MMm³/d level reached between December 2024 and February 2025.
The second calls for construction of a 573-kilometer, 20-inch polyduct from Tratayén running south through Neuquén, Río Negro, La Pampa, and Buenos Aires provinces to TGS's General Cerri complex at Bahía Blanca, Buenos Aires province, Argentina's main industrial port and hub of its petrochemical and NGL export complex.
The third comprises a new fractionation plant at Bahía Blanca with a capacity of 2.7 million tonnes per annum of propane, butane, and natural gasoline, alongside an overhaul of TGS's existing marine terminal, to be equipped with segregated storage tanks for each NGL fraction and optimized for international dispatch. TGS projects the full program will generate 19,000 jobs — 4,000 direct and 15,000 indirect — across four provinces. The company plans to apply for the RIGI.
5. LNG del Plata: Seasonal Surplus, Existing Infrastructure, No New Patagonian Pipelines
LNG del Plata is the first large-scale LNG project based in Buenos Aires province and the one in the current cohort that requires the least new trunk infrastructure. Promoted by Camuzzi Gas Inversora, Argentina's largest natural gas distribution company, the project is built around a seasonal surplus model: purchasing natural gas in Neuquén when domestic demand falls during summer months, transporting it via existing national pipeline infrastructure to Buenos Aires, liquefying it offshore, and exporting it. Unlike Argentina LNG, which requires dedicated large-scale pipeline construction across Patagonia, LNG del Plata routes gas through the existing national network, requiring only a short extension from the Buchanan compressor station, operated by TGS, to the Ensenada export hub at Puerto La Plata in Buenos Aires province.
The project's technical workstreams include that Buchanan-to-Ensenada pipeline; a 10-kilometer underwater pipeline connecting the coast to an offshore platform in the Río de la Plata; the mooring of a floating liquefaction vessel; and onshore gas conditioning facilities. The design also provides winter-demand flexibility: the vessel can regasify imported or stored LNG and deliver it directly to the Greater Buenos Aires consumption hub (home to roughly 15 million people and Argentina's largest gas demand concentration) when domestic demand peaks. Total projected investment is $3.9 billion over 20 years, with 500 direct jobs forecast. RIGI accreditation is being sought.
6. Compañía Mega: $650 Million to Expand NGL Throughput and Lock In RIGI Benefits
Compañía Mega S.A., Argentina's largest NGL exporter, operates a gas separation plant at Loma La Lata in Neuquén province, connected via a 600-kilometer polyduct through four provinces to its fractionation plant at the Bahía Blanca Petrochemical Complex, one of South America's largest integrated petrochemical and export hubs. The company recently announced plans to apply for RIGI status for a $360 million investment tranche, part of a broader $650 million integrated program running from 2023 to 2028, with three years of construction (2026–2028) spanning Neuquén, Río Negro, La Pampa, and Buenos Aires provinces.
The investment program encompasses two new pumping stations at General Roca, Río Negro province, and La Adela, La Pampa province, to expand NGL transport capacity on the polyduct to Bahía Blanca; new conditioning infrastructure for natural gas and oil-associated gas at the Loma La Lata separation plant; and complementary upgrades at the Bahía Blanca fractionation plant. The program is projected to increase total NGL output by approximately 27%, with more than 80% of incremental volumes directed to export markets.
7. Oldelval's Duplicar Norte: Filling the Crude Transport Gap Before VMOS Arrives
Oldelval, the Vaca Muerta crude oil pipeline operator, recently broke ground on Duplicar Norte, a new 24-inch, 207-kilometer pipeline connecting the Auca Mahuida pumping station in Neuquén province to Allen, a pipeline hub in Río Negro province where Oldelval's trunk system delivers crude for onward transport to the Atlantic coast. The line will add 74,000 m³/d (approximately 465,000 bbl/d) of capacity from the Northern Hub of Vaca Muerta.
The timing is driven by a specific constraint: Duplicar+, the $1.4 billion expansion Oldelval commissioned in 2025, is expected to reach technical saturation by mid-2026, before VMOS comes online. Duplicar Norte fills that gap. The project carries an estimated investment of $380 million and has been submitted for RIGI accreditation. Construction has been awarded to Techint E&C, an engineering and construction subsidiary of the Techint Group. Early commissioning is targeted for December 2026 at an initial capacity of 220,000 bbl/d; full certification is scheduled for the first quarter of 2027. Duplicar Norte will operate in conjunction with VMOS to ensure combined transport capacity keeps pace with rising Vaca Muerta output through the export ramp.