Colombia's Grid Connection Queue: Why Approved Solar Megawatts Are Not Operating Assets
Executive summary
Colombia has approximately 13.5 GW of approved solar in its development pipeline. It has roughly 2.2 GW of solar PV operating, with about 1.4 GW more in testing. Investors usually call that gap a financing gap, and a financing gap does exist. Many of the projects between those two numbers, though, are waiting on a transmission capacity assignment from UPME, Colombia's energy planning unit. That assignment is what turns a permitted project into a financeable one.
Two regulatory changes in 2026 moved this. In January, the Ministry of Mines and Energy convened the country's first long-term contracting mechanism under Decree 1091 of 2025, allowing energy contracts of up to 15 years. In May, UPME issued Resolution 000358 of 2026, which creates a faster route to a connection point for projects that have already cleared the environmental or contractual hurdles. A lender looking at a Colombian generation project asks two things: can it sell the power on a horizon that supports debt, and can it physically deliver the power. The two changes speak to one question each.
What follows covers how the queue works, what changed, and what a capital allocator should ask about connection status before treating a permitted megawatt as an investable one.
The approved-versus-operating gap
Colombia's approved pipeline number is large and gets quoted often. It counts projects that have cleared some combination of environmental licensing, land control, and registration with UPME. It does not tell you whether a project has a place to inject power.
The government target is more than 6 GW of new renewable capacity by August 2026. Against that, roughly 2.2 GW of solar PV is operational with about 1.4 GW under testing, so actual delivery is a bit over half the target as the deadline arrives. Developers failing to raise equity explain only part of the shortfall. Most of it comes from a queue that filled faster than the grid could absorb.
During the 2022 and 2023 allocation rounds, connection applications ran to multiples of what the National Interconnected System (SIN) could actually accommodate. On paper, available capacity was close to exhausted. Projects that were never going to get built held capacity reservations, while projects that were ready could not get a connection point or a date. Anyone who has watched interconnection queues in ERCOT or the UK has seen this. The difference is that Colombia's grid is smaller, so a few speculative applications tie up a much larger share of the available capacity.
What UPME controls
UPME receives and evaluates connection requests for projects connecting to the national transmission system (STN) and the regional transmission systems (STR), plus any project of 10 MW or more requesting connection to a local distribution system (SDL). Below that 10 MW threshold, and for distributed generation and self-generation with excess delivery, the distribution operator runs the process instead, on different timelines and with different ways to fail.
The threshold changes how an investor should read a portfolio. Utility-scale Colombian solar depends on the UPME queue. Residential and commercial rooftop portfolios, the segment covered in how solar financing works in Colombia, mostly never enter it. The two segments hit different bottlenecks, and a fund that describes both as carrying the same regulatory risk has not looked closely at either.
The cleanup: 5,000 MW recovered
Between 2022 and 2025, UPME cleared 101 stalled connection requests and recovered roughly 5,000 MW of transmission capacity. That is close to 25% of Colombia's installed generation capacity, freed up without building anything, just by removing reservations held by projects that were not advancing. By August 2024, 54 requests representing 3,155 MW had been cleared. A further 47 projects totaling more than 1,400 MW were removed in 2025 after technical review.
For an allocator, this says something about the quality of the pipeline number. If the equivalent of a quarter of the country's installed capacity sat in the queue attached to projects that could not advance, headline pipeline figures overstate near-term deliverable capacity by a wide margin. Diligence that uses approved MW as a proxy for buildable MW carries that overstatement straight into the model.
Resolution 000358 of 2026: the fast route
UPME issued Resolution 000358 on 20 May 2026. It sets a procedure and fixed deadlines for assigning transport capacity to projects that are further along, specifically those with energy supply obligations already contracted or environmental permitting already completed. It applies to Class 1 generation, cogeneration, and self-generation projects with delivery of excess to the system.
The resolution spells out the timelines. The applicant has five business days to file initial information and UPME has five business days to verify it. The applicant and the transmission operators then have 15 business days to submit proposals and responses. From the close of that window, UPME has 30 business days to return technical comments on how the project and its associated works affect the network.
The fixed deadlines are what matter. A sponsor negotiating with a lender can now point to a defined process with countable days instead of an open-ended review. The resolution guarantees no assignment and creates no transmission capacity where none exists. It does turn one of the least predictable parts of a Colombian development timeline into a bounded risk that a financial model can carry.
Read the eligibility rule carefully too. Priority goes to projects with contracted obligations or completed environmental permitting. A project with neither gets no acceleration, so the resolution sorts the existing pipeline without expanding it.
The other half: 15-year contracts
A connection point without a contract will not get financed either. In January 2026 the Ministry of Mines and Energy convened the first long-term electricity contracting mechanism under Decree 1091 of 2025, with contract terms of up to 15 years. The Bolsa Mercantil de Colombia acts as logistics operator, with technical support from the Inter-American Development Bank and the World Bank. The design integrates clean generation, battery storage, and differentiated hourly products.
Fifteen years is the number to focus on. Colombian renewable projects used to rely on shorter contracts or on the state auction mechanism. When the contract tenor is shorter than the debt amortization schedule, either the lender takes merchant tail risk or the sponsor accepts a shorter, more expensive debt structure. A 15-year contract lets a project carry long-tenor debt without the sponsor holding merchant exposure through the amortization period.
The market has started moving on bilateral terms without waiting for the state mechanism. Atlas Renewable Energy signed a PPA for the 128 MWp El Campano plant, with commercial operations expected by the end of 2027. When developers negotiate 15-year terms directly with off-takers, the contracting market is growing out of its dependence on auction rounds.
Contract tenor also bears on currency. For a USD investor, a 15-year COP-denominated revenue stream has a different risk profile than a 5-year one, and its escalation terms matter more over the longer horizon. Currency risk and the Colombian solar opportunity lays out how to reason about that.
What to diligence
Connection status is a specific fact about a project that you can verify. These questions separate a real asset from a pipeline entry.
Does the project hold an assigned connection point, or an application? An application is not an asset. Ask for the UPME assignment document and the substation named in it.
If assigned, what are the conditions and the expiry? Capacity assignments carry milestones. A missed milestone is how a project rejoins the back of the queue.
Does the project qualify for the Resolution 000358 route? That requires contracted energy obligations or completed environmental permitting. If neither is in hand, the accelerated timeline does not apply regardless of how the project is presented.
What network reinforcement works does the connection depend on, and who is building them? A connection point that requires a third-party transmission expansion carries that expansion's schedule risk.
Is the contracted tenor longer than the debt amortization schedule? If not, ask who holds the merchant tail.
For rooftop and C&I portfolios, does any of this apply? Below 10 MW on a distribution system, the counterparty is the distribution operator, not UPME.
Several of these tie into the broader economics in what drives Colombian solar returns, and into the fact that Law 1715 benefits attach to a project only once it reaches the stages that trigger them.
What to watch
For the rest of 2026, I am watching three things. First, whether UPME meets its own statutory deadlines for the first cohort of Resolution 000358 applications, which will show whether the process is faster in practice or only on paper. Second, whether the long-term contracting mechanism clears volume at prices that support project finance. Third, how the new government, which took office on August 7, 2026, treats both. A contracting mechanism convened by one administration is a policy commitment the next one inherits, and it has none of the standing of a statute.
The structural case for Colombian solar never depended on any of this. Irradiation of 5.5 kWh/m2/day on the Caribbean coast and some of the highest electricity prices in Latin America are facts about the resource and the market. The 2026 rule changes affect how many permitted projects become operating assets, and that conversion rate decides whether the pipeline number means anything.
Nuentero is software for the full solar project lifecycle, from planning and underwriting through capitalization and execution, in Colombia and the United States. Contact john.crye@nuentero.com or visit app.nuentero.com.
Disclaimer. This article is for general informational and educational purposes only. It does not constitute investment, legal, tax, or financial advice, and it does not take into account the objectives or circumstances of any particular person. Nothing here is an offer to sell or a solicitation of an offer to buy any security or interest in any fund, and no such offer or solicitation will be made except through definitive offering documents (such as a private placement memorandum) to qualified investors in jurisdictions where permitted. Any examples are illustrative of how solar project economics work and are not projections, forecasts, or guarantees of performance. Past or modeled performance is not indicative of future results, and no return is promised or guaranteed. Investments of this kind involve significant risk, including currency risk, regulatory risk, and possible loss of capital. Readers should consult their own professional advisers before making any investment decision.