With the massive expansion of LNG carriers over the last decade, the market bet on a structural transformation: that natural gas, historically a regional commodity, would evolve into a truly global commodity, similar to oil. The economic logic was compelling: faced with price differences between regions, LNG would act as a floating arbitrage mechanism, redirecting shipments until any gap was closed.
But the reality has been more complex.
The global energy crisis of 2022, followed by the disruptive events of 2026, including geopolitical tensions, logistical disruptions and vulnerabilities in critical routes such as the Strait of Hormuz, have made it clear that LNG has connected markets… but has not unified them.
Today we do not observe a convergence between markets, but rather a system of incomplete interdependence. While Europe and Asia operate under a structural premium driven by their import dependence, security of supply, and constant inventory replenishment, the United States maintains a decoupled domestic market, supported by abundant shale gas, ample storage levels, and an export capacity that, while significant, still does not fully close the global gaps.
The numbers clearly demonstrate this: Markets can become completely disconnected despite existing infrastructure. Today we live in a fractured market with two opposing realities:
- The Henry Hub (USA): It is an island of low prices. At the beginning of 2026, the average price was between $3.50 and $3.70 per MMBtu (€10.6 – €11.2/MWh).
- The TTF (Europe) and JKM (Asia): These are highly volatile markets, where average prices have ranged between $11.00 and $21.00 per MMBtu, jumping with any panic news (€33.2 – €63.4/MWh).
This giant difference, which averaged ~$15/MMBtu in early 2026, is not a passing anomaly; it is a structural decoupling.
In this edition, we will delve into the reasons behind this persistent gap and, more importantly, why Latin America has managed to navigate this crisis with a relatively contained impact. We will analyze the physical and commercial limitations that prevent true global integration of gas, as well as the supply strategies that countries like Brazil, Chile, Panama, and the Dominican Republic have implemented, which have allowed them not only to guarantee energy supply and support for renewable energy, but also to maintain industrial competitiveness.
America’s secret: Shale gas
The decoupling begins in geology.
The United States is not only a major gas producer; it is a structurally oversupplied system. The shale gas revolution has transformed market logic: gas is no longer solely the result of dedicated drilling, but a byproduct of the oil boom, particularly in basins like the Permian.
- This creates a unique dynamic: even when gas prices fall, production continues because the economic value lies in oil. The result is a structural surplus that keeps the Henry Hub depressed.
- Added to this is a second critical layer: export capacity is limited. Although the United States is exporting record volumes of LNG (around 17 Bcf/d in 2026), its production exceeds that capacity. The surplus remains trapped in the domestic market, acting as a “pressure valve” that prevents prices from skyrocketing.
In short: The Henry Hub is not a global price. It’s a local price… with global influence.
The European drama: Paying for panic
Europe is experiencing exactly the opposite phenomenon.
After losing nearly 40% of its gas supply (mainly Russian) in 2022, the continent ceased to be a market supplied by relatively stable long-term contracts and became dependent on global LNG.
This has had profound implications:
- Europe no longer receives gas… it competes for it.
- The TTF ceased to be a benchmark of equilibrium… and became the global marginal price.
- Energy security has a direct cost in the price.
In this new context, Europe is paying for three things simultaneously:
- Structural dependence on imports
- Storage mandates (75%-90% before winter)
- Coverage against geopolitical risks
Every disruption — from attacks in the Middle East to restrictions on shipping routes — translates into a panic premium.
While the Henry Hub reacts marginally to global events, the TTF overreacts. This asymmetry is the essence of decoupling.
Asia: The price of flexibility… and dependence
If the United States represents structural abundance and Europe strategic urgency, Asia embodies a third dynamic: flexible dependence.
Asia, as a whole, is the world’s largest importer of LNG. Countries like Japan, South Korea, and increasingly, China, depend almost entirely on imports to meet their gas demand.
But unlike Europe, Asia has historically built its energy security on long-term contracts, many of them indexed to oil. This has led to a particular characteristic: Asia doesn’t always pay the highest price… but it does pay the most strategic one.
Under normal conditions, the Asian market operates with relative stability thanks to its contract portfolio. However, this stability has its limits. When demand increases, due to severe winters, heat waves, or supply disruptions, Asia enters the global spot market with force.
And when Asia buys… the market moves.
This generates several key dynamics:
- The Asian spot price (JKM) often serves as a benchmark for global equilibrium during times of tension. Competition between Asia and Europe for spot cargoes defines interregional spreads. Geographic distance and long shipping routes increase costs and exposure to disruptions.
- Unlike in Europe, where price reflects immediate urgency, in Asia price combines long-term planning with episodes of high volatility in the short term.
The result is a hybrid market: structurally dependent, but tactically sophisticated.
In this context, Asia not only absorbs LNG… it also defines its marginal value in the global system. And in times of stress, it becomes the battleground where the prices that the rest of the world ultimately pays are determined.
The mathematics of transport: Why don’t ships match market prices?
While theory suggests that LNG should eliminate price differences between markets, the physics of this energy source points in the opposite direction.
LNG is not oil. It doesn’t flow freely; it is transformed, transported, and reconverted. Each stage introduces friction and cost.
- Liquefaction (Feedgas + Operation): consumes between 10% and 15% of the gas (~$2.0 – $4.5/MMBtu)
- Sea freight: ~$1.0 – $2.5/MMBtu
- Regasification and others: ~$0.5/MMBtu
Even under normal conditions, there is a structural “floor” for arbitrage. Gas cannot move from one market to another without incorporating a significant premium over the source price, which is further amplified on long routes such as those connecting Atlantic supply with Asian markets.
But the friction is not only technical; it is also structural.
These costs are compounded by restrictions that strain the economic equation and limit price convergence:
- Limited liquefaction capacity (shortage of cooling trains)
- Shortage of LNG carriers
- Congestion in strategic channels and geopolitical disruptions
- Fixed-term contracts that reduce flexibility
- High concentration of supply (US and Qatar dominate growth)
In this context, LNG doesn’t eliminate price differentials; it channels them within certain limits. And when those restrictions intensify, the spread ceases to reflect only logistical costs and begins to incorporate risk, availability, and urgency premiums—something particularly visible in Asia, where import dependence and geographical distance tend to amplify these differentials.
That’s why ships don’t equalize prices. They only connect markets that remain, in essence, profoundly different.
Latin America: Our geographic and strategic advantage
Our region doesn’t compete in the same game as Europe or Asia. It plays on a different playing field.
Not because it is isolated from the global system, but because its geographical position, its contractual architecture and its role within the LNG value chain place it in a privileged zone within a fragmented market.
1. Geographic Proximity: the “natural market” of the US Gulf.
Latin America is, by design, the most efficient destination for surplus US LNG.
A ship leaving Louisiana takes:
- Less than 5 days to the Caribbean and Central America
- Between 15 and 20 days to Europe
- Up to 25-30 days to Asia
This difference is not trivial. It reduces three critical risks:
- Logistics costs: lower fuel consumption and less exposure to volatile freight rates
- Risk of disruption: less transit through geopolitical chokepoints (Hormuz, Suez)
- Timing risk: greater capacity to react to changes in demand
In a market where time is valuable, proximity is a structural advantage.
Furthermore, this proximity makes the region the “balancing market” for the US. When Europe or Asia cannot absorb the entire volume, whether due to weather, high inventories, or demand shocks, Latin America becomes the natural recipient of those surpluses.
2. Long-Term Contracts indexed to the Henry Hub
If geography is the foundation, the contractual structure is the multiplier.
Unlike Europe and Asia, historically indexed to Brent, JKM, or spot prices, many Latin American countries have structured long-term contracts directly linked to the Henry Hub. This radically changes price formation.
In 2026:
- Europe was paying > $18/MMBtu during times of tension
- Latin America received LNG at costs < $8/MMBtu
A differential of more than $10/MMBtu.
This difference is not just a market fact. It has systemic implications:
- More stable electricity rates
- Lower tax pressure due to energy subsidies
- Greater industrial competitiveness
- Greater predictability for long-term investments
In essence, the region has built a kind of “price wall,” partially insulating itself from the extreme volatility of the global market. This has been possible, to a large extent, thanks to regulatory frameworks and public policy decisions that have allowed, and even incentivized, the advance contracting of long-term supply, ensuring stable access to this energy source under competitive conditions before cycles of scarcity and volatility materialize.
3. Operational flexibility and portfolio optimization
In addition to its privileged geography and long-term contracts, Latin America is developing a third layer of advantage: the capacity for optimization.
The combination of strategically located regasification terminals and hybrid gas-power portfolios allows certain players in the region to implement more efficient hedging strategies and, thereby, manage their risk exposure more actively and sophisticatedly.
This architecture enables dynamic decisions between fuels, contracts, and markets, generating an optimization capacity that an isolated agent can hardly replicate.
Some terminals are even beginning to evolve into micro-hubs, with regional re-export capabilities. This still-nascent flexibility introduces an additional layer of regional operational resilience that becomes especially relevant during times of system stress or disruptions in the global market.
https://www.aes.com/energy-solutions/technology/natural-gas-flexible-capacity
4. Gas as an enabler of the energy transition
Finally, there is an often underestimated element: the role of gas in the stability of the electrical system.
Latin America is accelerating its penetration of renewable energies, particularly solar and wind, but these technologies, due to their intermittent nature, require firm and flexible support.
In countries like Brazil, Chile, or Panama, gas does not compete with renewables… it makes them viable on a large scale.
Ultimately, rather than a transition fuel, gas is positioned as an accelerator of the transition , by allowing increasingly cleaner energy systems to remain both reliable and economically sustainable.
Specific Regional Success Stories
The true validation of this structural advantage is seen in how some countries in the region have managed to translate geography, contracts, regulatory vision and private initiatives into concrete results.
Brazil, Chile, Panama, and the Dominican Republic have not only adopted LNG; they have strategically integrated it into their energy systems.
🇧🇷 Brazil: resilience in a hydrologically vulnerable system
Brazil represents the clearest case of how LNG can transform a structural risk into an operational strength.
With a historically hydroelectric power matrix, the country was exposed to drought cycles that forced the dispatch of diesel generation, which was highly expensive and polluting.
Access to LNG, particularly under schemes linked to the Henry Hub, has changed that equation:
- It allows for the activation of thermal generation at significantly lower costs.
- It reduces price volatility in dry years.
- It reduces dependence on liquid fuels
Today, gas acts as a hydrological insurance , providing flexibility and stability to a system increasingly exposed to climate variability.
🇨🇱 Chile: stability through contracts and diversification
Chile is perhaps the most sophisticated example in terms of market design.
With a high dependence on energy imports, the country opted for long-term contracts and a diversification of sources that have allowed it to partially decouple from global volatility.
LNG has been key to:
- Replace coal in your energy mix
- Support the accelerated expansion of renewables
- Maintain predictability in energy costs
Furthermore, its relatively efficient access to LNG from the US, via the Panama Canal, strengthens its logistical competitiveness against more distant markets.
Chile did not eliminate its dependency… it transformed it into a manageable, predictable and resilient system .
🇵🇦 Panama: Systemic stability and strategic positioning
Panama has evolved from a system with a high dependence on liquid fuels to one where natural gas plays a structural role.
Projects such as AES Colón and Generadora Gatún have been crucial for:
- Stabilize the spot price of the electricity system
- Reduce exposure to oil volatility
- Improve supply reliability
Additionally, Panama has a differentiating attribute:
“Its geographical location positions it as a natural logistics hub for LNG in the region.”
The combination of infrastructure, strategic location and regional demand opens the door to its consolidation as an energy hub for the Caribbean and Central America.
🇩🇴 Dominican Republic: Economic efficiency and accelerated transition
The Dominican Republic is one of the clearest cases of direct impact on the economy.
The transition from fuel oil to LNG has generated:
- Significant reduction in generation costs
- Improvement in the trade balance
- Reduction of polluting emissions
The use of long-term supply contracts has allowed the country to capture the benefits of the Henry Hub, stabilizing tariffs and reducing vulnerability to international shocks.
This is a clear example of how LNG not only transforms the energy system… it also strengthens the economy as a whole.
The real danger: an advantage that is not permanent.
Latin America’s position in this new energy order is clearly favorable.
But he is not invulnerable.
And, paradoxically, the greatest risk does not come from the global market… but from how the region interprets its own advantage.
The current stability can generate a dangerous sense of resilience. But that resilience, in many cases, is not structural… it’s contractual.
And the contracts expire.
Access to competitive LNG in Latin America has been made possible by proactive decisions: long-term contracts negotiated before the market entered cycles of scarcity and volatility. This is the main reason behind the “price wall” that protects the region today.
The problem is that that window doesn’t stay open indefinitely.
As these contracts near expiration, countries that have not secured supplies in advance will face a different market: more competitive, more volatile, and potentially more integrated and more expensive. In fact, recent analyses by the US Energy Information Administration show how the expansion of US LNG export capacity and growing global demand are reshaping trade flows, intensifying competition for supply and reducing the availability of marginal volumes in the market.
In energy, timing is everything. You don’t negotiate in the middle of a crisis… you negotiate before it happens.
In this context, access to relatively cheap gas can create the wrong incentives: postponing procurement decisions, depending excessively on the spot market, underestimating global competition for supply, or assuming that future availability will be the same as current availability.
It is the classic mistake of extrapolating from the present into the future.
But the LNG market doesn’t work that way.
It’s a market where supply takes years to develop, demand can change in months, and contracts are signed long before the gas flows. When a country enters late—without contracts, without hedging, without a position—it ceases to be a strategic buyer and becomes an opportunistic one.
And in that role, it doesn’t set prices… it receives them. It doesn’t ensure supply… it competes for it. It doesn’t optimize… it reacts.
The recent history of Europe is, to a large extent, a lesson in what happens when this dynamic is underestimated.
Added to this are structural risks that, although known, remain critical:
- Exposure to the Henry Hub means that volatility does not disappear, but rather shifts: extreme weather events or disruptions in US production can directly impact costs in the region.
- Furthermore, the strong dependence on the US introduces a geopolitical and regulatory component: changes in energy policy, delays in liquefaction projects or restrictions on exports can alter the current balance.
Meanwhile, global competition for shipments remains a determining factor. In times of scarcity, LNG flows to where it fetches the best price. Asia, with its greater purchasing power, can absorb available volumes, displacing less well-covered buyers. In this scenario, the “natural” market can quickly become a residual market.
Even infrastructure, one of the pillars of regional advantage, can become a limitation. Logistical constraints like those seen in the Panama Canal or extreme weather events can introduce unexpected frictions, reminding us that geography helps, but it doesn’t eliminate risk.
Ultimately, all these factors converge on the same point: the greatest risk is complacency.
Latin America’s current advantage is neither permanent nor automatic. It was built on foresight: contracts signed during times of plenty, infrastructure developed before systemic stress, and regulatory frameworks that enabled long-term decision-making.
The challenge now is not to discover a new advantage… it is not to lose the one that already exists.
Conclusion
In a world that aspired to energy convergence through natural gas, LNG has revealed a different reality: we are not yet facing a unified global market, but rather a fragmented system where geology, geopolitics, and infrastructure continue to define who wins and who loses. Latin America, through a rare combination of proximity, long-term contracts, and proactive decision-making, has managed to position itself on the right side of this fragmentation.
But this advantage is neither accidental nor permanent. It is the result of understanding something fundamental: in the LNG market, price is not defined solely by supply and demand, but also by access, timing, and strategy. Countries that acted before the crisis ensured a competitive supply; those that reacted during the crisis paid the global marginal price.
As the market evolves, with greater liquefaction capacity and more intense global competition for molecules, the region’s relative advantage will depend on its ability to maintain strategic discipline: renewing contracts on time, investing in infrastructure, and refining risk management.
Because in this new energy order, the difference is not made by who has access to gas… it is made by who ensures that access before everyone needs it.
References
LNG value shift as US exports price volatility https://timera-energy.com/blog/value-shift-as-us-exports-price-volatility/
US LNG developers sign highest volume of sale and purchase contracts since 2022 https://www.eia.gov/todayinenergy/detail.php?id=67264
North America’s LNG export capacity could more than double by 2029 https://www.eia.gov/todayinenergy/detail.php?id=66384
Gas Market Report, Q2-2026 https://iea.blob.core.windows.net/assets/8a1b93f9-d096-4dcd-b29a-77613f201ecc/GasMarketReport%2CQ2-2026.pdf
US exports of LNG to the Caribbean near record highs in 2025 https://www.eia.gov/todayinenergy/detail.php?id=67366
Expert Commentary – An overview of LNG imports in Latin America and the Caribbean and potential opportunities for further penetration in the region https://www.gecf.org/Portals/0/xBlog/uploads/2025/8/13/gecf-commentary—lng-imports-in-latam-and-the-caribbean1.pdf
Clearer Timeline Emerges for Next Wave of US LNG Projects as Buildout Hits Overdrive https://naturalgasintel.com/news/clearer-timeline-emerges-for-next-wave-of-us-lng-projects-as-buildout-hits-overdrive/