Colombia’s Natural Gas Crisis and Strait of Hormuz Closure Explained

The Hidden Architecture of Energy Fragility: How Colombia's Gas System Was Set Up to Fail

Energy systems rarely collapse in a single moment. They fracture gradually, through years of underinvestment, policy choices that prioritise ideology over infrastructure, and a quiet assumption that supply chains will remain stable indefinitely. Colombia's unfolding natural gas crisis is a textbook illustration of this pattern, and the Colombia natural gas crisis and Strait of Hormuz closure now represent two converging stress vectors that the country's energy architecture was never designed to absorb simultaneously.

Understanding how this collision occurred requires examining the structural foundations first, before considering how a geopolitical shock thousands of kilometres away transformed a slow-moving domestic crisis into something considerably more acute.

Colombia's Gas Reserves: A Decade of Quiet Deterioration

The numbers that define Colombia's reserve position are stark. By the end of 2024, the country held proven natural gas reserves of approximately 2 trillion cubic feet, the lowest recorded figure in well over two decades. At prevailing extraction rates, this equates to roughly 5.9 years of remaining production capacity, a timeline that would concern any energy planner under normal circumstances.

What makes the situation more alarming is the trajectory rather than the absolute figure. Reserves contracted by 3.3% year-over-year in 2024 alone, indicating that depletion is accelerating rather than stabilising. Exploration drilling has fallen sharply, and no significant new field discoveries have offset the drawdown. The upstream pipeline, in short, is empty.

March 2026 natural gas production data reinforces this picture. Output reached 700 million cubic feet, representing a modest 0.7% month-over-month gain but a decline of nearly 15% year-over-year. Measured against the production levels recorded a decade earlier, Colombia's gas output has fallen by approximately 38%, one of the steepest sustained contractions in Latin America's energy sector.

The Associated Gas Complication Most Analysts Overlook

A dimension of Colombia's gas supply problem that receives insufficient attention is the structural linkage between oil production decline and gas availability. A significant share of Colombia's natural gas is associated gas, meaning it occurs alongside crude oil in the same reservoirs rather than in dedicated gas fields.

Technical Note: Associated natural gas is a byproduct of oil extraction. Its production volume is directly tied to oil output levels, meaning that as oil production declines, associated gas volumes fall in parallel. This creates a structural coupling between the petroleum and gas sectors that is often invisible in high-level supply analyses.

This linkage creates a compounding problem. As Colombia's oil fields age and production volumes decline, associated gas availability shrinks in proportion. Meanwhile, operators of the country's mature heavy oil fields are increasingly reinjecting associated gas back into reservoirs to maintain pressure and improve oil recovery rates, a technique known as enhanced recovery. This reinjection diverts gas away from commercial supply channels entirely.

Oil production in March 2026 averaged 740,497 barrels per day, down 1% year-over-year and well below the 917,210 barrels per day recorded in March 2016. Each barrel-per-day reduction in oil output carries a corresponding reduction in associated gas availability, tightening the domestic supply picture further. Furthermore, these geopolitical oil price tensions compound the financial pressure on operators already reluctant to invest in declining assets.

Policy Decisions That Turned a Slow Decline Into a Structural Emergency

Colombia's production decline is not solely the product of geological depletion. Government policy under President Gustavo Petro's administration has materially accelerated the trajectory through two primary mechanisms: a ban on awarding new exploration and production contracts, and significant tax increases on hydrocarbon producers.

The exploration contract ban removes the primary mechanism by which Colombia could replenish its reserve base. Even if the policy were reversed tomorrow, the multi-year lead time between exploration activity and commercial production means any supply response would arrive years too late to address the current shortfall. The tax increases, meanwhile, have reduced the economic incentive for existing operators to invest in maintaining or expanding production from fields that are already in decline.

The stated rationale for these policies is a managed transition away from fossil fuel dependence. The practical consequence, however, has been to accelerate the supply decline curve without establishing alternative energy infrastructure capable of filling the gap.

The Demand-Side Scissors Effect

Compounding the supply contraction is a simultaneous increase in natural gas demand driven by Colombia's electricity generation mix. Approximately 65% of the country's electricity is produced by hydroelectric facilities. The remainder comes increasingly from thermal power plants, many of which are transitioning away from coal toward natural gas as Bogota pursues a coal phase-out strategy.

El Niño-driven drought conditions have persistently reduced river flows and cut hydropower output across multiple consecutive seasons. When hydro output falls, thermal plants must compensate, and those thermal plants increasingly run on natural gas. The result is a demand-supply scissors effect: domestic gas supply is contracting while gas demand for power generation is structurally rising.

Without adequate gas to fuel thermal plants during periods of peak demand or low hydro output, grid stability becomes precarious. Brownouts and localised blackouts are already occurring across multiple Colombian cities and remote areas, a visible signal that the system is operating near its operational limits. The broader commodity market volatility affecting energy inputs across the region is further amplifying these pressures.

The Strait of Hormuz: How a Geopolitical Shock Became an LNG Price Transmission Event

Colombia began importing liquefied natural gas in December 2016 as the domestic supply shortfall first became apparent. What began as a modest supplementary supply source has grown into a structural dependency. By the end of 2025, LNG imports accounted for 18% of Colombia's total natural gas supply, with projections before the Hormuz disruption placing this figure at 26% through 2026.

The Strait of Hormuz carries approximately 20% of global natural gas shipments annually, making it the world's most critical energy transit corridor. Its closure, following escalating tensions after U.S. military strikes on Iran, immediately disrupted LNG supply chains serving markets across Asia, Europe, and Latin America. Iran's actions also disrupted roughly a fifth of Qatar's LNG production, removing a major source of globally traded LNG from the supply pool at a moment when markets were already tightening. The LNG supply outlook for 2025 and beyond had already flagged significant tightness before this disruption materialised.

Scenario Context: Qatar ranks among the world's largest LNG exporters. Any disruption to Qatari output has an outsized effect on global LNG spot prices and long-term contract availability, with cascading consequences for import-dependent nations operating in the spot market.

For Colombia, the price transmission mechanism works as follows. LNG imports already carry a substantial cost premium over domestically produced gas, incorporating liquefaction costs at the point of manufacture, shipping expenses across ocean routes, and regasification costs at the Colombian port of delivery. The average price of imported natural gas had already climbed 26%, from $14.64 to $18.39 per MBTU, before the Hormuz closure introduced additional upward pressure.

The Import Dependency Escalation Table

Each percentage point increase in import dependency translates directly into greater exposure to global LNG price volatility. The Hormuz closure has transformed what was a manageable and anticipated increase in import reliance into a potential supply security emergency, with revised estimates now suggesting Colombia's LNG dependency could reach 33% of total supply before the end of 2026.

The Economic Consequences Already Visible in the Data

The financial impact of escalating gas costs is not hypothetical. Industrial consumers in Colombia experienced a 69% increase in natural gas costs during 2025, while household consumers faced a 23% increase in the same period. These are not marginal adjustments; they represent material changes to operating economics for manufacturers and to household budget pressures for a population where nearly 32% live in poverty.

Natural gas serves dual roles in Colombia's economy. It is a primary industrial input for a manufacturing sector that contributes approximately 10% of GDP, and it remains the most widely accessible low-cost household fuel across the country. Price increases therefore transmit simultaneously through industrial cost structures and consumer cost-of-living measures.

Colombia's headline inflation reached 5.68% in April 2026, rising from 5.16% recorded a year earlier, with energy cost escalation identified as a primary contributing factor. GDP expanded by only 2.2% in the first quarter of 2026, a fragile growth base from which to absorb an accelerating energy cost shock. The country also operates under conditions of considerable sovereign debt and substantial fiscal deficits, limiting the government's capacity to deploy subsidies at the scale that would be required to meaningfully shield households and industry from further price increases.

Colombia Versus Other Vulnerable LNG-Dependent Economies

The trade war energy shocks reverberating across global supply chains have added further strain to nations already exposed to supply disruptions. The table below contextualises Colombia's vulnerability relative to comparable economies.

Colombia's combination of rapidly depleting reserves, accelerating import dependency, weak fiscal buffers, and high exposure to Hormuz-disrupted supply chains places it among the most structurally vulnerable emerging economies to the current global LNG supply shock. Analysis from the Atlantic Council further illustrates how this corridor's disruption reverberates far beyond the Middle East.

Strategic Options and Their Limitations

Colombia's response options are real but heavily constrained by structural and temporal realities.

Short-term pathways include redirecting LNG procurement toward U.S. Gulf Coast exporters or West African suppliers less exposed to Hormuz disruption, emergency spot market procurement at elevated prices, and demand-side management programs to reduce peak gas consumption from industrial users.

Medium-term structural responses involve more difficult trade-offs:

• Reversing or modifying the exploration contract ban to incentivise new upstream development, though commercial volumes would take years to materialise
• Accelerating solar and wind capacity additions to reduce gas demand for power generation
• Exploring pipeline supply arrangements with neighbouring Venezuela, which holds substantial gas reserves, though this carries significant geopolitical complexity given bilateral relationship dynamics

Long-term architecture would require developing a strategic gas reserve buffer, establishing long-term LNG supply contracts with non-Hormuz-exposed exporters, and investing in demand-side fuel switching for industrial users.

The core constraint across all timeframes is the multi-year lag between policy decisions and supply outcomes. Colombia cannot drill its way out of this crisis in months. It cannot build sufficient renewable capacity fast enough to eliminate thermal gas demand. Furthermore, it cannot easily insulate itself from global trade war impacts and the broader LNG price dynamics when purchasing in a spot market that is simultaneously tightening.

Frequently Asked Questions

What is driving Colombia's natural gas production decline?

Three factors are operating simultaneously: geological depletion of mature fields that reached peak production a decade or more ago, the diversion of associated gas into enhanced oil recovery operations rather than commercial supply, and government policies that have restricted new exploration activity and reduced investment incentives for existing operators.

Why does the Strait of Hormuz closure affect a South American country?

Colombia now relies on imported LNG for a growing share of its domestic gas supply. Global LNG prices are set by supply and demand across international markets. When the Hormuz corridor, through which approximately 20% of global gas shipments travel, is disrupted, global LNG supply tightens and prices rise. Those higher prices transmit directly to Colombian import costs regardless of geography.

How much has natural gas cost already increased for Colombian consumers?

Industrial consumers faced a 69% increase in natural gas costs during 2025. Household consumers experienced a 23% increase over the same period. The average imported LNG price rose 26%, from $14.64 to $18.39 per MBTU, before Hormuz disruption introduced further upward pressure.

Is Colombia at risk of power blackouts?

Brownouts and localised blackouts are already occurring in multiple Colombian cities and rural areas. The risk of broader grid disruptions escalates materially during periods when El Niño conditions reduce hydropower output and gas supply constraints limit thermal generation capacity simultaneously. The Colombia natural gas crisis and Strait of Hormuz closure together represent a stress scenario the country's grid was not engineered to withstand.

This article is intended for informational and educational purposes only. It does not constitute financial, investment, or legal advice. Statistics, forecasts, and projections referenced in this article are sourced from publicly available data and industry reporting. Forward-looking statements involve inherent uncertainty and actual outcomes may differ materially from those described. Readers should conduct independent research before making any investment or policy-related decisions.

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