Opening Insight
Colombia’s gas and power balance is changing in a way that matters operationally, not simply statistically. Domestic gas production and reserves are declining, hydropower remains exposed to drought and El Niño conditions, and LNG imports are assuming a larger role in keeping the system supplied. The important point is that this is no longer just a procurement problem. It reaches into dispatch, hedge effectiveness, liquidity, counterparty exposure, and the day-to-day coordination required across trading, fuel procurement, logistics, risk, credit, treasury, and operations.
This article argues that the central risk is not merely tighter supply, but failing to adapt quickly enough to a market where LNG timing, terminal concentration, and hydro volatility increasingly determine commercial and operational outcomes. Treating the situation as temporary invites avoidable cost and control failures. By contrast, stronger scenario planning and shared visibility improve resilience, while ETRM modernization, disciplined process design, and controlled AI support can strengthen execution without requiring a technology-first transformation. To make that operating and strategic challenge clear, the discussion begins in the next section, Context and Analysis .
The Cost of Delay
Treating this as a temporary imbalance leads, first, to planning errors. Teams continue to operate from assumptions shaped by stronger domestic gas supply and more normal hydro conditions, even as marketed gas production falls from 1,070 MMcf/d in 2022 to 772 MMcf/d in 2025 and averaged 673 MMcf/d from January through August 2026. When hydropower weakens, as it did when its share fell from 81% in 2025 to 55% in March 2024 , gas-fired generation has to close the gap. If leadership has not adjusted to that reality, procurement is pushed into a tighter market, replacement volumes are purchased later, and LNG timing, terminal availability, and short-term nominations begin to drive daily operations.
The financial and control consequences follow quickly. With LNG already reaching a record 31% of monthly gas supply in July 2026 and only one operating import terminal until new capacity is online reliably, any delay or disruption can convert operational stress into commercial damage. Procurement stress raises costs, rushed scheduling creates more exceptions, and slower responses to market tightening leave less optionality and weaker negotiating leverage. Poor coordination also distorts dispatch and weakens hedge effectiveness precisely as El Niño risk is rising and the government has already declared a national disaster ahead of expected drought conditions. The result is margin leakage, greater working-capital pressure, and organizations reacting only after infrastructure tightens and counterparties have already repriced risk.
Operating With More Control
Addressing this early does not remove the structural pressure of falling domestic gas supply or heavier LNG dependence. What it does is create more control over how an organization operates within those constraints. Procurement can happen earlier, guided by clearer scenarios that reflect domestic gas decline, LNG availability, hydropower variability, and gas-fired power demand rather than relying on normal-condition assumptions. That gives trading, fuel procurement, dispatch, logistics, risk, credit, and treasury a shared view of what is changing and what needs to happen next.
The result is a faster, more resilient operating model. Teams encounter fewer scheduling surprises, less manual rework, and a clearer separation between market exposure and operational exposure. When cargo timing shifts, infrastructure tightens, or hydropower underperforms, decisions can be made with better coordination and stronger support instead of under last-minute pressure. That also improves the ability to use new LNG capacity effectively as expansions and additional terminals come online, turning added supply access into genuine optionality. With clearer decision rights and better preparation, companies are better positioned to protect margins, respond to stress, and manage liquidity, collateral, and counterparty pressure more steadily.
Operating Control Under Stress
The most effective response is not a wholesale transformation or a technology-first replacement. It is a practical operating and resilience model built around better scenarios, tighter coordination, and faster decisions when domestic gas declines, hydropower weakens, LNG timing slips, or terminal concentration becomes a constraint. The core discipline is to connect the variables that now drive reliability and commercial performance together: domestic gas decline, LNG import availability, hydropower variability, and gas-fired power demand through 1Q2027.
That only works if trading, origination, fuel procurement, dispatch, logistics, risk, credit, and treasury are operating from shared visibility and clear decision rights. Leaders need common escalation rules, sharper distinctions between market and operational exposure, and playbooks for stressed procurement and dispatch windows. Technology matters here, but as support for forecast transparency, nomination visibility, exposure reporting, and cross-functional coordination. The organizations most likely to hold up well are the ones that rehearse these scenarios early, align around a handful of critical decisions, and move as one portfolio when hydro stress or LNG disruption begins to tighten the system.
Turning Stress Into Action
Arcelian’s role is not to impose a technology-first fix. It is to help leaders turn Colombia’s changing gas and power balance into a practical operating response. In this market, the right architecture starts with a control point that gives teams the same view of forecast changes, nominations, exposure, and operating stress as conditions shift through 1Q2027. That matters because the risk is no longer abstract. Domestic gas output fell from 1,070 MMcf/d in 2022 to 772 MMcf/d in 2025 , then averaged 673 MMcf/d from January through August 2026. At the same time, hydropower supplied 81% of electricity in 2025 but dropped to 55% in March 2024 , while gas rose to 22% of generation . In a system with one active LNG import terminal and stressed conditions shaped by domestic decline, hydropower variability, and LNG timing, forecast transparency and nomination visibility become operating necessities.
In practice, that means connecting the market view to execution. ETRM and adjacent operating processes need to support scenario-based planning, exposure reporting, and cross-functional coordination rather than sit apart from dispatch, logistics, and fuel procurement decisions. The useful architecture is the one that helps teams distinguish market exposure from operational exposure, see when cargo timing or terminal availability changes assumptions, and carry those changes through procurement, scheduling, and risk response. Arcelian helps define the data and reporting discipline around those decisions using the article’s existing pressure points: domestic gas decline, LNG import availability, hydropower variability, gas-fired demand, counterparty implications, and liquidity strain during stressed procurement windows.
The roadmap should remain disciplined. It begins with a cross-functional stress test through first quarter 2027 built around the conditions already in view: a greater than 83% chance of a strong to very strong El Niño, concentrated LNG infrastructure, uncertainty around new capacity timing, and tighter thermal dependence when hydro underperforms. From there, leaders can sequence improvements around the handful of decisions that matter most: how much supply to lock in, how much flexibility to preserve, when to escalate supply adequacy concerns, and how to tighten dispatch triggers and contingency actions on high-risk days. The point is not to over-engineer a future-state platform. It is to build clearer scenarios, sharper reporting, and more reliable execution under stress.
That also requires explicit operating-model changes. The CIO’s role is to ensure systems and data flows improve transparency rather than add another layer of complexity. The COO must align scheduling, logistics, dispatch, and operations to commercial reality when conditions tighten. The CFO must stay close to working-capital buffers, liquidity pressure, and the cost of late replacement volumes when procurement windows narrow. Across those roles, decision rights need to be defined early, escalation rules need to be shared, and governance has to align commercial speed with operational reality.
The harder shift is cultural. Traders, operations, risk, treasury, and executives cannot continue acting from separate assumptions about optionality, bottlenecks, exposure, or infrastructure timing. The organizations that hold up best are the ones that rehearse stress cases before the market forces them to, build common KPIs around responsiveness and exposure clarity, and make sure rule governance supports faster action without losing control. That is where Arcelian helps most: not by promising to remove structural pressure, but by helping the organization respond as one portfolio when procurement, dispatch, and reliability are all under strain.
Reliability Is Now Strategic
Colombia’s gas challenge is no longer a temporary market imbalance. With domestic production down from 1,070 MMcf/d in 2022 to 673 MMcf/d on average through January to August 2026, and hydropower still highly exposed to drought, LNG imports have become central to power reliability, trading performance, and risk control. For leadership teams, the issue is not just securing supply. It is making faster, better-coordinated decisions across procurement, dispatch, risk, and liquidity before system stress forces them. The organizations that adapt early will be better positioned to protect margins, maintain resilience, and operate with more discipline as import dependence grows.
Act Before Conditions Tighten
Arcelian helps energy and commodity leaders turn Colombia’s gas and power stress into a practical operating response by connecting market structure, fuel procurement, risk, operations, and decision governance.
- Assess how declining domestic gas supply and rising LNG dependence change portfolio exposure, operating assumptions, and planning horizons.
- Redesign workflows across trading, scheduling, risk, treasury, and operations for stressed procurement and dispatch conditions.
- Improve scenario analysis, exposure reporting, and decision support tied to weather risk, supply adequacy, and infrastructure concentration.
- Strengthen controls around nominations, logistics dependencies, and counterparty or liquidity exposure during volatile procurement periods.
- Build a practical roadmap for process, data, and system improvements without forcing a technology-first transformation.
Review your Colombia gas and power exposure against an El Niño stress case through 1Q2027 now, then test whether your current commercial, operational, and risk processes are ready for a market where LNG imports play a much larger role.
Operational Resilience Under Volatility Requires Integrated Commercial Control
As market stress intensifies, resilience depends less on isolated heroics in trading or operations and more on how quickly the enterprise can convert changing supply conditions into coordinated commercial action. In practical terms, that means prioritizing a modernization strategy that strengthens cross-functional control before pursuing broad platform replacement: shared position visibility across gas, power, logistics, and treasury; clearer decision rights for curtailment, replacement supply, and credit usage; and workflow discipline around nominations, dispatch changes, and exception handling. This reinforces the broader thesis of the article: worsening supply and power market conditions expose operating weaknesses not in one system, but across the full chain of commercial and operational execution.
For most firms, the immediate trade-off is not
new ETRM versus legacy
, but where to improve the ETRM architecture and integration roadmap first. The highest-value sequence is usually to stabilize critical data flows between contracts, scheduling, exposure, settlement, and cash forecasting; then introduce scenario-based control points for drought risk, LNG dependency, transport disruption, and gas-fired demand spikes. Measurable outcomes should include faster re-nomination cycles, fewer manual reconciliations, reduced imbalance costs, and tighter alignment between market exposure and working capital consumption.
Where AI or agentic AI is introduced, the priority should be controlled decision support rather than autonomous execution. Useful applications include:
- detecting breaks across nominations, logistics events, and position data before they become financial exposures
- generating contingency scenarios using front-, middle-, and back-office data with auditable assumptions
- routing operational exceptions to the right owners based on predefined control thresholds and governance rules
Used this way, AI strengthens resilience only when process ownership, data quality, and escalation controls are already defined.
Frequently Asked Questions
Why are LNG imports becoming critical for Colombia’s power reliability?
Domestic gas production and reserves are declining while the power system still depends heavily on hydropower, which can drop sharply during drought and El Niño conditions. When hydro underperforms, gas-fired generation has to fill more of the gap, making LNG imports a reliability requirement rather than just a supplemental supply source.
What operational risks come from relying on a single LNG import terminal?
With only one operating terminal, the market is more exposed to cargo delays, terminal availability issues, and tighter nomination and scheduling windows. In stressed periods, those constraints can raise procurement costs, create dispatch exceptions, reduce hedge effectiveness, and put more pressure on liquidity and counterparties.
How can utilities and generators improve resilience as gas supply tightens and hydro becomes less predictable?
The article points to a practical operating model built on earlier scenario planning, shared visibility across trading, procurement, dispatch, logistics, risk, credit, and treasury, and clear decision rights during stressed conditions. The goal is to connect forecasts, nominations, exposure reporting, and execution so teams can respond faster when LNG timing slips, hydro weakens, or thermal demand rises.
Trend Watch
What is emerging in Colombia is more than a supply squeeze. It is a structural shift toward integrated commercial control as a prerequisite for Colombia power reliability . The combination of Colombia gas supply decline , rising gas-fired power demand , and persistent hydropower variability means commercial teams can no longer treat fuel procurement, dispatch, treasury, and risk analytics as adjacent activities. In an El Niño energy risk environment, delay is expensive, but fragmentation is worse.
The real pressure point is operational: as domestic gas production Colombia continues to weaken, the market’s growing dependence on LNG imports Colombia and a single LNG import terminal Colombia turns timing risk into portfolio risk. A late cargo, a nomination mismatch, or a logistics exception can now ripple directly into imbalance costs, collateral needs, and weaker hedge performance. That is why scenario-based planning , ETRM modernization , and tighter commercial controls are becoming core resilience capabilities rather than back-office improvements.
Leaders that move early are not just buying supply. They are building an operating model that can separate market exposure from execution failure, route exceptions faster, and give traders, operators, and treasury a shared picture of stress as it develops. In this market, operational resilience will increasingly belong to firms that treat coordination, data transparency, and controlled AI decision support as sources of commercial edge.
Closing Insight
Colombia’s next competitive divide will not be defined by who sees volatility first, but by who can operationalize that signal faster across fuel procurement, dispatch, risk management, and liquidity decisions. As LNG dependence deepens and hydropower variability continues to challenge planning assumptions, modernization must center on integrated control, resilient workflows, and AI-enabled decision support that improves speed without weakening governance. The firms that outperform will be those that treat data transparency, scenario discipline, and cross-functional execution as strategic infrastructure, not incremental process improvement. In a market where reliability risk now translates directly into commercial exposure, resilience becomes the operating model—and a measurable source of margin protection, optionality, and long-term advantage.
Partner with Arcelian
As Colombia’s gas and power markets become more tightly linked through LNG dependence, hydropower volatility, and rising operational exposure, leadership teams need more than scenario awareness—they need an operating model that converts stress signals into coordinated commercial action. Arcelian works with energy and commodities organizations to strengthen ETRM architecture, risk visibility, and cross-functional control so procurement, dispatch, treasury, and operations can respond with greater speed, discipline, and margin protection. Connect with our team to explore how a practical modernization roadmap can improve resilience, decision quality, and execution under stressed market conditions.
