Oil & Gas in Colombia: Navigating Uncertainty in 2026

Colombia's oil and gas sector is in the most precarious position it has occupied in a generation. Proven reserves are on course for depletion by 2031. New exploration licences have not been awarded in over two years. The government's fracking moratorium remains in force. Exploratory investment has fallen more than 40% since 2022. Ecopetrol, the national oil company that accounts for the majority of production, faces a reserve replacement crisis of existential proportions.

And yet the story of Colombia's hydrocarbon sector in 2026 is not simply one of decline. It is one of transition — incomplete, contested, and charged with the possibility of reversal. The presidential election scheduled for May, with a likely runoff in June, represents the single most consequential variable for the sector in a decade. Understanding what is at stake, and how to position through it, is essential for any foreign company with Colombian energy operations or ambitions.

This analysis is written for the CFO, general counsel, or country manager of a foreign oil and gas company — whether a supermajor, an independent operator, a services company, or a mid-market explorer. It covers the current state of the sector, the fiscal and regulatory environment, the implications of recent departures, and the strategic posture that the evidence supports.

The Reserve Crisis: What the Numbers Mean

Colombia's proven oil reserves stood at approximately 2.04 billion barrels at end-2024, a figure that represents roughly 7.5 years of production at current rates. At 746,444 barrels per day, and with no new significant discoveries to replace depletion, the reserve horizon narrows to 2031 — a date now regularly cited by both government officials and industry analysts.

The reserve replacement ratio — the standard measure of a producer's ability to replenish what it extracts — has deteriorated sharply. Ecopetrol, which produces approximately 60 per cent of Colombia's oil, disclosed a reserve replacement ratio of 68 per cent in 2024, meaning the company is depleting faster than it is finding. Without new exploration activity, this trajectory is mathematically terminal.

Natural gas reserves present a more nuanced picture. Colombia holds approximately 3.7 trillion cubic feet of proven gas reserves, sufficient for roughly 12 years at current consumption rates. The domestic gas market has grown in importance as a transition fuel, and several companies — including Ecopetrol and Canacol Energy — have continued gas-focused operations with less regulatory friction than their oil counterparts.

The framing that matters for foreign investors is not whether Colombia's hydrocarbon sector is in decline — by certain metrics, it clearly is — but whether the policy environment that has accelerated that decline is itself subject to change. The evidence suggests it is.

Policy Paralysis: Four Years of Deliberate Restraint

The Petro government took office in August 2022 on an explicit platform of ending Colombia's dependence on fossil fuels. The administration's energy policy has been consistent with that platform: no new exploration contracts, a de facto fracking moratorium, and a tax regime that has made Colombian hydrocarbon operations among the most heavily taxed in the hemisphere.

The unconventional gas resources in the Llanos and Magdalena Valley basins — estimated at several hundred trillion cubic feet of shale gas equivalent — remain untouched. Colombia's unconventional resource base is one of the largest in South America, and its inaccessibility under current policy is among the sector's defining frustrations for operators who have spent years and capital on preliminary assessment work.

Contract insecurity has compounded the exploration freeze. Several foreign operators have cited the absence of clear contractual stability guarantees — a concern amplified by the government's use of emergency decree powers in December 2025 to implement fiscal measures that Congress had rejected. When the legal framework governing major long-term investments can be altered by executive action, the risk calculus for exploration changes materially.

"Colombia's unconventional gas reserves are among the largest in South America. The reserves exist. The policy framework to access them does not — yet."

The Fiscal Environment: Understanding the Tax Burden

The tax regime for hydrocarbon companies in Colombia is, by any international comparison, demanding. The standard corporate income tax rate of 35 per cent is supplemented by a 15 per cent surcharge specifically applicable to fossil fuel extraction companies, bringing the effective statutory rate to approximately 50 per cent. This surcharge, introduced through the 2022 tax reform, applies to companies engaged in coal, oil, and natural gas production and cannot be avoided through corporate restructuring alone.

Royalties represent an additional layer of fiscal obligation. Royalty rates vary by production volume and type, ranging from 8 per cent for small producers to 25 per cent for high-volume oil production. These royalties are paid to the national government and the producing regions, and they cannot be deducted for corporate income tax purposes — a structural feature that significantly increases the effective total government take relative to comparable regimes in Peru, Ecuador, or Brazil.

Transfer pricing is a particular area of scrutiny for oil and gas companies. DIAN has invested significantly in transfer pricing audit capacity, and the hydrocarbon sector is a priority target. Companies with intercompany transactions — including crude oil sales to related parties, shared services charges, and financing arrangements — face rigorous documentation requirements. Penalties for non-compliance are substantial, and DIAN's audit teams have become increasingly sophisticated in their understanding of industry-specific pricing mechanisms.

The December 2025 emergency decree introduced a new wealth tax with a lower threshold (approximately COP 2.09 billion in net worth), which affects a broader range of corporate entities than its predecessor. While the Constitutional Court is reviewing several provisions of the decree, companies should assume these obligations remain in force until definitive judicial resolution.

The Retreat of Exploration Capital: What It Signals — and What It Doesn't

No single corporate departure defines Colombia's position. The more revealing signal is aggregate: exploratory investment fell roughly 42% between 2022 and 2025, and exploratory activity is down close to 60% over three years, according to the Asociación Colombiana del Petróleo. Capital has not fled dramatically — it has quietly stopped arriving.

The consequence is now visible in the reserve base. Colombia closed 2025 with 1,717 gigacubic feet of proven gas — down 16.8% in a single year and 54.6% below the 2018 level, equivalent to 5.9 years at current production. Proven oil reserves of 2,020 million barrels represent 7.4 years, a marginal improvement on the prior year. The divergence matters: the oil position stabilised while the gas position deteriorated sharply.

The clearest expression of the shortfall came in July 2026, when Ecopetrol opened a competitive process to contract imported LNG for five years, with deliveries through Buenaventura beginning late in the year. Imported gas already accounts for roughly a quarter of the volume traded domestically. A country that once exported gas is now contracting to buy it.

For mid-market operators and services companies, however, conditions of retreat can create genuine opportunity. Assets change hands at prices reflecting exit premiums rather than long-term value. Service contract vacuums emerge. Local content requirements become easier to satisfy with less competition for qualified local partners. The companies that move carefully but decisively in these conditions are often those that establish the strongest long-term positions in a sector.

The 2026 Election: A Genuine Inflection Point

The May 2026 presidential election is not a peripheral consideration for the oil and gas sector. It is the central variable around which all medium-term strategy must be organised.

The March 2026 congressional elections confirmed that Petrismo has lost its legislative influence. No candidate from the governing coalition is leading presidential polls, and the field of credible contenders is dominated by figures who have explicitly committed to reopening hydrocarbon exploration, reviewing the fracking moratorium, and restoring contractual stability for foreign investors.

A change in government would not resolve all of the sector's structural challenges. The reserve depletion timeline is a geological reality, not a policy artefact. The labour reforms enacted under Law 2466 will remain substantially in place. Environmental regulations affecting water use and community consultation requirements reflect international standards that transcend any single administration.

But a pro-investment government could change the exploration environment fundamentally: new licensing rounds, fracking authorisation under controlled conditions, enhanced contractual stability guarantees, and a more predictable fiscal framework. The companies best positioned to benefit from this scenario are those that have maintained a presence through the difficult years — retaining local knowledge, regulatory relationships, and operational capacity — rather than those attempting to re-enter from scratch after the cycle turns.

Compliance Obligations: What Every Foreign Operator Must Know

Irrespective of the political cycle, the compliance obligations facing foreign oil and gas companies in Colombia are substantial. Several deserve specific attention from CFOs and compliance officers.

Transfer pricing. DIAN's transfer pricing scrutiny in the hydrocarbon sector is intensive and growing. Companies must maintain contemporaneous documentation for all intercompany transactions — crude oil sales, intercompany loans, management fees, and shared services. The arm's length standard is applied rigorously, and companies that cannot demonstrate the economic rationale for their intercompany pricing face significant audit exposure and potential reclassification of income.

Electronic invoicing and digital reporting. Colombia's digital tax administration infrastructure applies fully to the energy sector. All B2B transactions must be reported through DIAN's electronic invoicing system in real time. Payroll reporting through the nómina electrónica system is mandatory for all employers. Non-compliance carries penalties calculated as a percentage of unreported transactions, and DIAN's enforcement capacity has grown substantially in recent years.

Environmental and community obligations. Prior consultation (consulta previa) requirements with indigenous and Afro-Colombian communities remain a significant operational consideration for any company operating in or near protected territories. The process is complex, time-consuming, and not always predictable in outcome. Early engagement — ideally before operations commence — is essential and, where managed well, can become a source of competitive differentiation.

IFRS reporting. Colombian companies are required to report under IFRS as adopted in Colombia. For foreign-owned subsidiaries, this means ensuring alignment between local IFRS accounts and parent-company consolidation requirements. IFRS 18, which replaces IAS 1 for financial statement presentation, is effective from January 2027 — early adoption is available and merits consideration for companies with complex financial statement structures typical of energy sector operations.

Strategic Posture: Three Scenarios for Decision-Making

Foreign companies with Colombian energy operations or interests are navigating three possible scenarios over the next eighteen months.

Scenario A: Policy continuity. A government sympathetic to the current administration maintains the exploration freeze and fracking moratorium. Production continues to decline. Companies focused on long-term reserve development face a sustained adverse environment. Operational excellence and rigorous compliance become the primary value drivers — protecting what exists rather than building what could exist.

Scenario B: Policy reversal. A pro-investment government opens new licensing rounds, authorises fracking pilots, and signals fiscal reform. The sector enters a recovery phase, with significant first-mover advantages for companies already present with operational capacity and local relationships intact. Asset valuations recover. New capital deployment becomes viable for the first time since 2022.

Scenario C: Partial adjustment. A centrist government pursues measured reform — some new contracts, limited fracking authorisation — without full reversal of existing restrictions. The improvement is real but gradual. Companies that have positioned patiently benefit over a three-to-five-year horizon rather than immediately.

The evidence currently favours Scenarios B or C. But the prudent approach is not to bet exclusively on a single outcome. It is to maintain the operational and compliance foundation that allows rapid deployment under any favourable scenario, while managing costs carefully under an adverse one. In a sector defined by long time horizons and capital intensity, the companies that remain present, compliant, and strategically patient are the ones that capture the value when cycles turn.