There is a comfortable assumption worth dismantling before committing a dollar to solar energy: that the tropics, being hot, are automatically the best place on earth to make electricity from the sun. Panama (PA) is a good case for testing that intuition against the data. The country sits nine degrees off the equator, gets sun year-round, and has no winter to switch off generation for months at a stretch. But it also has a long rainy season, high humidity, and cloud cover that shades much of the isthmus. The right question for a business is not «is there a lot of sun?» but «how much energy per square metre is there, where, and what does the regulatory framework say I can do with it?» Those three answers each carry a source and a date — and that is what this analysis is about.
The solar resource: why you will see both 4.8 and 5.5 kWh/m², and which one matters
The first number a decision-maker looks for is irradiation: how much solar energy falls on a square metre per day. For Panama, two figures circulate that should not be averaged, because they describe different things. A common value is a mean daily irradiation of around 4.8 kWh/m² per day, while other sources cite up to 5.5 kWh/m² per day (PA). The reference that organises that spread is the World Bank’s Global Solar Atlas, whose solar potential maps for Panama let you read the resource by location rather than through a single national average (PA; source: World Bank / Global Solar Atlas, Panama solar irradiation and PV power potential maps).
The divergence is not an error: it depends on what is measured and where. A national average blends the cloudy Caribbean coast with the drier highlands. Above all it depends on the province. In the Pacific dry arc — provinces such as Chiriquí and Veraguas — the resource exceeds 5 kWh/m² per day, above the country mean (PA; secondary source pvknowhow, drawing on World Bank Solar Atlas-type irradiation data). Translated into decisions: a plant in Chiriquí and a commercial rooftop on the Caribbean side do not yield the same, and using the national number to size a local project can over- or under-estimate output by a margin that changes the return.
The practical lesson is simple. For a country-level analysis, 4.8–5.5 kWh/m² per day is a reasonable band that places Panama in the high tier of usable solar resource. For a project-level analysis — sizing a system, calculating annual output, projecting payback — you must drop down to the specific site figure, not the average. Irradiation should also be read together with its seasonality: the Pacific dry season concentrates the highest-yield months, while the rainy season cuts daily output. A financial model that applies the annual average month by month without adjusting for that seasonal curve will describe a cash flow the plant does not deliver in practice.
The thermal toll: why tropical heat is not a free gift
The tropical climate hands you sun hours, but charges a toll that rarely appears in the brochure: temperature. A silicon photovoltaic module’s efficiency falls as cell temperature rises — cell, not air. Under intense sun, a cell can operate tens of degrees above ambient, and every degree above the reference condition trims the power delivered. In a country where midday ambient temperatures frequently sit around 30–33 °C with high humidity, that thermal derating is not marginal: it is the gap between a panel’s nameplate rating and the real power a system injects at noon (PA; engineering observation, not a specific regulatory figure).
This has concrete design consequences. Ventilation behind the module — the gap between panel and roof surface — stops being a cosmetic detail and becomes a performance variable: a mounting that lets air circulate dissipates heat and recovers part of the loss. Technology choice matters too, because different module types have different temperature coefficients and therefore degrade their output unequally under the same heat. And inverter sizing must account for the fact that real peak output, once the thermal toll is deducted, does not match the arithmetic sum of the panels. None of these points cancels the appeal of Panama’s resource; what they do is move the analysis from the headline — «lots of sun» — to the plane where money is won or lost: system engineering and its behaviour in real heat and humidity.
How much solar is already installed: 695.55 MW and its place in the matrix
Resource is potential; installed capacity is measured reality. During 2024, Panama added 143.4 MW of new photovoltaic capacity, bringing its cumulative solar capacity to 695.55 MW by year-end (PA; as-of: December 2024; source: pv magazine, citing ASEP — the National Public Services Authority). The same source puts solar at 13.79% of the country’s installed generation capacity as of end-December 2024.
It helps to place that 13.79% within the capacity matrix as a whole. Panama’s total installed capacity was around 5,045 MW at the end of 2024, with thermal as the largest block — roughly 2,166 MW, near 43% — followed by hydro — about 1,848 MW, around 37% — and wind, at some 336 MW (approximately 6.7%) (PA; as-of: 2024; secondary source citing ASEP). Read this way, photovoltaics is still the fourth piece on the board by installed capacity, but it is the fastest-growing one, and those 143.4 MW added in a single year confirm it. The figure a decision-maker should retain is not solar’s current position but its slope: a source that expands its fleet by a double-digit percentage in one year is changing its relative weight fast.
Capacity is not generation: the 97.66% month versus the 70.3% year
Here a caveat is needed that separates serious analysis from a headline, because it is the most common source of confusion about Panama’s matrix. Installed capacity is not the same as generation. In the capacity matrix, thermal and hydro weigh most; in actual generation, hydro — running as baseload in wet months — can push the renewable share well above its weight in capacity. That is why two figures circulate that seem to contradict each other and do not.
The first: renewable generation reached 97.66% of the total in a single month — November 2024, a monthly record reported on ETESA-CND data (PA; as-of: 11.2024; secondary source: press citing ETESA-CND). The second: taken over the full year 2024, renewable generation stood at around 70.3% (PA; as-of: 2024; secondary source: La Prensa). A month of peak hydrology does not describe the year, and the year does not erase the month’s record. These are two truths from different periods; anyone averaging them or using them without marking the time window is reporting badly.
For a company the lesson is direct. If your sustainability argument — Scope 2 reporting, ESG credentials — rests on «Panama generates almost 100% renewable,» you are quoting a monthly peak, not the annual reality, and an auditor will notice. The defensible figure is the annual one, near 70.3% in 2024, with the qualifier that solar is a minority but growing portion within that total. Honesty in the use of these two numbers is itself part of due diligence.
The national framework: the Plan Energético Nacional and its 70% target
No capacity figure makes sense without the policy pushing it. The long-term compass is the Plan Energético Nacional 2015–2050 (PES), from the Secretaría Nacional de Energía. The plan sets a target of 70% of installed capacity from renewable sources by 2050, and additionally contemplates a share of around 30% of non-conventional renewables — solar, wind and biomass — in the matrix by that same horizon (PA; as-of: 2015–2050 plan; source: SNE, referenced by the IEA in its policy repository).
The distinction between «renewable» and «non-conventional renewable» is not an empty technicality. Panama already has a matrix with heavy hydro weight; the plan’s stated challenge is to grow precisely in the sources that carry little today — sun and wind — to diversify and not depend on hydrology, which in dry years exposes the reliance on thermal generation. For a company reading the country as a platform, that nuance matters: the policy signal is not «more renewables, full stop,» but specifically more distributed solar and wind, which is where a private project can enter.
Resting on that framework is a more operational instrument: ENISIN (Estrategia Nacional de Innovación del Sistema Interconectado Nacional), from the SNE, which proposes installing between 1 and 1.6 GW of new solar and wind capacity over the decade (PA; as-of: 2024–2025; secondary source: Enerdata, citing the SNE). A gigawatt and a half of new clean power in ten years is a figure that reshapes the matrix: set against the 695.55 MW of cumulative solar at end-2024, it implies more than doubling — potentially tripling — the country’s solar and wind fleet. That is the order of magnitude that turns the PES from declaration into trajectory: without ENISIN, the 70%-by-2050 target would be a statement; with it, it is a concrete volume of megawatts that someone has to finance, permit and connect.
Sajalices: how a single project reshapes the scale
To grasp what «1 to 1.6 GW» means in tangible terms, it helps to look at one announced project. The case of Sajalices — a 530 MW photovoltaic plant arising from an agreement between PowerChina and Sajalices Energy — is the most telling example (PA; as-of: December 2024 announcement; secondary sources: pv magazine / Energía Estratégica). A single 530 MW project on its own approaches the 695.55 MW of all the country’s cumulative solar capacity at end-2024. Put another way: if Sajalices is energised as announced, it would almost double Panama’s photovoltaic fleet with one plant.
That contrast illustrates two things at once. First, the country’s utility-scale solar ambition is real and backed by agreements with heavyweight developers, not just paper targets. Second — and this is what a prudent decision-maker must not overlook — a 530 MW announcement is not the same as 530 MW dispatching energy. The distance between memorandum and commissioning is measured in years and depends on environmental permits, financial close, land acquisition and available connection capacity on ETESA’s grid. A project of that size also raises system-level questions: absorbing 530 MW of intermittent power demands transmission reinforcement and, eventually, firm capacity or storage so as not to compromise stability. Sajalices, therefore, reads better as a signal of the market’s direction and scale than as capacity already available.
What this tells a company evaluating Panama
With the figures on the table, the useful exercise is to translate them into decision variables. The first is resource by location: if the project is output-sensitive — an industrial plant, a logistics hub, a large commercial rooftop — the choice of province moves the needle. The Pacific dry arc yields more than the Caribbean side; ask for the site-specific irradiation figure before sizing, not the national average of 4.8–5.5 kWh/m² per day, and adjust for the thermal toll and rainy-season variability.
The second variable is market trajectory. A solar fleet that went from adding 143.4 MW in one year to 695.55 MW cumulative, underpinned by a national plan targeting 70% renewable by 2050 and a strategy (ENISIN) aiming at 1–1.6 GW of new sun and wind, describes an expanding market, not a niche. That has concrete implications: a maturing supply chain, installers gaining experience, and a regulatory signal that — on paper at least — points in one direction.
The third is the dollar economy. Panama uses the US dollar as legal tender, which means a solar system’s CAPEX and the savings it generates are calculated in the same currency, without the exchange-rate risk that complicates return analysis in other economies in the region. For a foreign investor or a corporation reporting in dollars, that monetary stability removes a layer of uncertainty from the business case (PA; context observation, not a specific figure).
The limits of enthusiasm: what the figures do not say
An honest analysis also marks what is not yet proven. First, solar generation is intermittent and sensitive to tropical cloud cover: a rooftop producing strongly at midday contributes nothing after dusk or during a prolonged rainy front. Solar does not replace the firmness of hydro or thermal; it complements it, and that complement is managed at system level — dispatch, storage — not at the level of a single panel.
Second, policy targets are just that: targets. The PES’s 70% renewable by 2050 and ENISIN’s 1–1.6 GW describe intention, not capacity already built. The distance between a project announcement — such as Sajalices’s 530 MW — and its effective energisation is measured in years and depends on permits, financing and grid connection. The prudent decision-maker reads these figures as the direction of the wind, not as electricity already available at their connection point.
Third, the economics of a commercial project are not settled by irradiation alone: they depend on the distributed-generation framework — net metering, capacity limits, ASEP’s technical regulation — that governs what a company may connect and under what rules. That framework has its own figures and its own debates — including the public discussion over possible charges on self-generation — and deserves a separate analysis, because that is where the tropical sun does, or does not, turn into a return on a company’s books.
Conclusions
Panama has a solid solar resource — between 4.8 and 5.5 kWh/m² per day depending on method and location, and above 5 in the Pacific dry arc — and a photovoltaic fleet that reached 695.55 MW by end-2024, still a minority of capacity but growing fast. The policy framework, with the Plan Energético Nacional 2015–2050 aiming at 70% renewable and ENISIN at 1–1.6 GW of new sun and wind, pushes in the same direction. And the dollar economy removes exchange-rate risk from the return calculation.
None of those signals, on its own, decides an investment. Together they describe a market in which the tropical sun is a real asset — provided it is measured by location, the thermal toll is accounted for, capacity is distinguished from generation (the 97.66% of a record month is not the 70.3% of the year), and the target is read as a trajectory rather than a done deal. For a company weighing whether to locate in Panama, the question is no longer whether there is sun, but how to turn a well-documented resource into a decision that withstands the detail of engineering and regulation.
This article is for general information only and does not constitute legal, tax or financial advice.