Solar incentives in Chile 2026: Market Guide and Incentives

Chile’s solar market has matured from a subsidy-driven experiment into one of Latin America’s most sophisticated incentive stacks. The country reached roughly 37.4 GW of total installed power capacity by early 2025, with renewables supplying about 25.5 GW of that total, according to U.S. Department of Commerce market intelligence (2025). Solar leads new renewable additions, yet the real story for installers and property owners in 2026 is not just falling module prices. It is how to layer Casa Solar, Net Billing, accelerated depreciation, VAT credits, CORFO green finance, and the PMGD stabilized-price regime without leaving money on the table.

This guide is written for solar professionals, EPCs, commercial property owners, and residential buyers who need a market-focused incentive manual. It covers the legal framework, every active 2026 incentive, the PMGD policy shift, and the sizing logic that determines whether a project pays back in three years or nine. For a deeper look at off-grid solar in Chilean mining, see our off-grid solar case study in Chile.

If you are designing systems or writing client proposals, a cloud solar design platform with Chilean tariffs and incentive scenarios can save hours on every project. Model payback, self-consumption ratios, and stacked incentives automatically, then generate professional proposals in minutes. Check pricing to see how SurgePV handles Chile.

Chile’s 2026 solar incentive stack can cut net commercial project cost by 45–55% when layered correctly. Active tools include Casa Solar for households, Net Billing for systems up to 300 kW, 100% accelerated depreciation and VAT credit for businesses, CORFO green finance, and the PMGD stabilized-price regime for projects up to 9 MW. The key is matching each incentive to the right customer segment and project size.

In this guide:

• Latest 2026 status of every active Chilean solar incentive
• The legal foundation: Law 20.571, Law 21.118, Net Billing, and PMGD
• Casa Solar residential subsidy — eligibility, coverage, and application rules
• Commercial incentives: accelerated depreciation, VAT credit, CORFO, and green bank credit
• PMGD stabilized prices and the 2026 shift to time-block pricing
• Regional payback differences across Chile
• Common mistakes and how to avoid them
• Practical checklist for installers and project owners

Latest Updates: Chile Solar Incentives 2026

The Chilean solar policy environment shifted in 2026. Net Billing remains the backbone for small and medium systems, but PMGD regulation is in flux. The government withdrew draft decrees DS 125 and DS 88 for review in early 2026, creating uncertainty for developers planning pure-injection projects.

Chile Solar Incentive Status — June 2026

Key Changes Since 2025

March 2026 — Draft DS 88 withdrawn: The new administration withdrew proposed amendments to Supreme Decree 88 for review. The amendments would introduce six time-block stabilized prices for new PMGD projects and allow hybridization with battery storage. The withdrawal delayed final rules and added regulatory uncertainty, according to BNamericas (2026).

February 2026 — PMGD/PMG capacity passes 3,900 MW: The combined PMGD and PMG segment reached more than 3,900 MW, with relevant investments in loss reduction and competition benefits, according to GIE data reported by BNamericas.

Ongoing — Casa Solar waiting lists: The second national Casa Solar call exhausted most of its quotas by May 2026. New applicants are placed on waiting lists for the next call.

Why Chile’s Incentive Stack Matters in 2026

Chile has some of the world’s best solar resources. The Atacama Desert in the north receives more than 2,700 equivalent peak sun hours per year, while the central metropolitan region still receives 1,900–2,200. The gap between solar potential and installed rooftop capacity is not technology or sunlight. It is administrative complexity, financing friction, and uncertainty about which incentives still apply.

Market Size and Targets

Chile’s total installed power capacity reached 37.4 GW by May 2025, with 25.5 GW from renewable sources, according to U.S. Department of Commerce market intelligence (2025). Solar power plants delivered 18.6 GWh of energy in 2024, making solar the fastest-growing renewable source. The country has set a target of 80% renewable electricity by 2030 and carbon neutrality by 2050 under Law 21.505.

The distributed generation segment remains small relative to utility-scale solar. Net billing installed capacity reached only about 108 MW by early 2022, or roughly 0.3% of national capacity, according to Nasirov et al. in Sustainability (2023). That share has grown since, but residential and commercial rooftops are still underdeveloped compared with the country’s solar potential.

What the Distributed Gap Means for Incentives

The low rooftop penetration means installers who can explain the incentive stack clearly have a competitive advantage. Most Chilean households and businesses do not know that Net Billing credits can accumulate for five years, that accelerated depreciation applies to batteries, or that PMGD pricing is changing. Proposals that show gross savings and the full stacked net cost after grants, tax deductions, and finance win more often.

For installers, this means proposals must model both the bill savings and the tax/finance impact. A solar design platform with Chilean tariffs and incentive templates becomes a competitive tool.

The Legal Foundation: Net Billing and PMGD

Every Chilean solar incentive is built on the same legal base: the General Law of Electrical Services (LGSE), modified by Law 20.571 and Law 21.118 for distributed generation, and Supreme Decree 88 for PMGD market participation.

Law 20.571 and Law 21.118

Law 20.571, the original Net Billing law, was enacted in 2012 (Nasirov et al., 2023). It allowed renewable generation systems up to 100 kW connected to regulated customers to inject surplus energy into the grid and receive compensation.

Law 21.118, enacted in 2019, made three important changes (Solarity, 2026):

1. Raised the capacity limit from 100 kW to 300 kW.
2. Allowed surplus redistribution across multiple meters under the same RUT and distribution company.
3. Permitted collective self-consumption in communities or shared properties.

Net Billing vs. PMGD

Net Billing and PMGD are not the same. The table below explains the difference.

How Net Billing Works in Practice

Under Net Billing, a bidirectional meter records both energy consumed and energy injected. At the end of the billing period, the distribution company values injected kWh at the energy-only price and deducts the credit from the bill. If generation exceeds consumption, the credit can roll forward for up to five years. After five years, unused credits are forfeited to the benefit of all customers in the commune.

The energy-only price is lower than the full retail tariff. In practice, injected kWh may be valued at roughly 60–80 CLP/kWh, while retail consumption can cost 150–180 CLP/kWh, according to Leon Solar (2026). This ratio makes self-consumed solar roughly two to three times more valuable than exported solar.

Net Billing Bill-Credit Example

A small manufacturing plant in Santiago installs a 100 kWp system. In January, the system produces 17,500 kWh. The plant consumes 12,000 kWh directly during daytime hours and injects 5,500 kWh into the grid.

Without solar, the January bill would have been roughly 3,300,000 CLP for 20,000 kWh. With solar, the bill drops to 935,000 CLP. The direct self-consumption delivers 60% of the savings, while the exported surplus delivers only 12%. The remaining 28% is the solar energy that replaced grid imports beyond direct self-consumption during generation hours.

This example is simplified. Real bills include fixed charges, demand charges, and seasonal variations. The key point is that self-consumption dominates the economics.

For a deeper explanation of sizing logic, see our generation and financial tool.

Casa Solar and Residential Subsidies

Casa Solar is the flagship residential solar subsidy. It is administered by the Agencia de Sostenibilidad Energética (AgenciaSE) under the Ministry of Energy.

How Casa Solar Works

The program provides direct capital subsidies covering 40–60% of the installed cost of grid-connected rooftop solar systems, typically 1 kWp or 2 kWp, according to Casa Solar (2024). The exact percentage and system size depend on the technical assessment of the roof and the socioeconomic profile of the household.

The 2024–2025 call focused on 2,200 turnkey projects in the Antofagasta and O’Higgins regions. The second national call opened in 2025 and had largely exhausted its quotas by May 2026, according to Terralink (2026).

Who Qualifies

Casa Solar is aimed at:

• Residential homeowners.
• Micro, small, and medium enterprises.
• Specific vulnerable groups, such as low-income households and seniors in certain regions.

Applicants must:

• Own the property or have notarized authorization from the owner.
• Use an SEC-certified installer.
• Meet income and property-value thresholds set by each call.
• Attend an information session in most calls.

Application Process

1. Register on the Casa Solar or AgenciaSE portal.
2. Submit the electricity bill, property title, and identity documents.
3. Pass the technical feasibility visit.
4. Pay the required co-payment (for example, 100,000 CLP in Antofagasta or 50,000 CLP in O’Higgins for social calls).
5. Sign the installation contract with the assigned installer.
6. Receive the completed system and submit connection documents.

The safest rule is to apply only during an open call and never start work before formal selection. Installing first usually voids the subsidy.

Commercial and Industrial Incentives

Large enterprises do not qualify for Casa Solar, but they have access to a more powerful set of tools. The four main commercial incentives are accelerated depreciation, VAT credit, CORFO financing, and BancoEstado’s green credit.

Accelerated Depreciation

Chilean tax law allows businesses to depreciate 100% of renewable energy assets in the first fiscal year (Terralink, 2026). This includes modules, inverters, mounting structures, batteries, and installation costs capitalized into the project.

Example: A company invests 120,000,000 CLP in a 100 kWp system. With the corporate tax rate at 27%, the first-year deduction creates a tax saving of 32,400,000 CLP. That is an implicit subsidy of 27% of the investment.

VAT Credit

Solar installations are capital investments, so the 19% VAT paid on equipment and installation is recoverable as a tax credit against VAT collected on sales. For a 100,000,000 CLP system, the credit is 19,000,000 CLP.

Combined with accelerated depreciation, a business can recover roughly 46% of the project cost in the first year through tax effects alone.

CORFO Green Finance

CORFO, Chile’s economic development agency, offers several green finance instruments that lower both the cost of capital and the equity required from the borrower:

• Energía Sostenible credit line: Up to 100% project financing channeled through commercial banks, with terms up to 20 years and preferential rates. This line is designed specifically for energy efficiency and renewable energy projects.
• Garantía Inversión Verde: Covers up to 60% of the collateral required by banks for SMEs that lack sufficient guarantees for conventional credit.
• Programa de Inversión y Financiamiento (PIF): Long-term credit for productive investment projects, including renewable generation installations, with grace periods during construction and installation.

The actual rate and term depend on the intermediary bank. BancoEstado, BCI, Banco de Chile, and Santander have all acted as CORFO intermediaries for green lines. The first step is to ask the company’s banking relationship manager whether the current CORFO green line is open.

BancoEstado Crédito Verde

BancoEstado offers the Crédito Verde directly, without CORFO intermediation. Terms include preferential rates compared with standard commercial credit, repayment up to 10 years, and grace periods up to six months. It finances PV systems, storage, and associated equipment. The main advantage is simplicity: the bank evaluates the company directly.

When Leasing or ESCO Models Make Sense

Not every business wants to own the asset. Leasing and energy service company (ESCO) contracts remain popular in Chile for companies with limited capital or uncertain long-term site tenure. In a typical solar lease, the lessor owns the system, claims the accelerated depreciation, and passes part of the benefit to the customer through lower monthly payments. In an ESCO contract, the provider installs, operates, and maintains the system and sells the energy to the host at a discount to the grid tariff.

The tradeoff is straightforward. Ownership captures the full tax benefit and the highest long-term savings. Leasing and ESCO models sacrifice some upside in exchange for zero upfront cost and lower risk. For a company with high debt or uncertain cash flow, leasing can be the rational choice even if ownership is mathematically better.

Commercial Stacking Example

Consider a 150 kWp commercial system in Santiago with a gross cost of 180,000,000 CLP net of VAT.

This example is illustrative. Actual savings depend on tariff, self-consumption ratio, and financing cost.

Case Study: A Distribution Warehouse in Quilicura

A 4,000-square-meter distribution warehouse in Quilicura, north of Santiago, installed a 200 kWp rooftop system in late 2024. The facility operated six days per week, with peak demand from refrigeration and conveyor belts between 10:00 and 16:00. The system was sized to cover roughly 75% of daytime consumption.

The gross investment was 240,000,000 CLP net of VAT. The company recovered 45,600,000 CLP through the VAT credit and 64,800,000 CLP through accelerated depreciation in the first fiscal year. The net effective cost after tax effects was approximately 129,600,000 CLP. Annual electricity savings under Net Billing reached 38,000,000 CLP, yielding a simple payback of roughly 3.4 years.

The project succeeded because the load profile matched solar generation. Weekend operation captured Saturday generation, and refrigeration baseload absorbed early-morning and late-afternoon production. A system 50% larger would have exported far more surplus at the lower energy-only price and would have extended payback.

This case is based on a representative project. Individual results vary with tariff, financing, and consumption pattern.

PMGD and the Stabilized Price Regime

PMGD is the regime for distributed generators above Net Billing scale. It has been the engine behind Chile’s solar boom in the north, but 2026 reforms are changing its economics.

What PMGD Is

PMGD covers generators up to 9 MW connected to distribution networks. PMG covers the same size range connected to transmission networks. Both can opt for a stabilized price set by the Comisión Nacional de Energía under Supreme Decree 88.

The regime was created to correct a market disadvantage. Small generators faced high transaction costs and price risk in the spot market. The stabilized price gave them a predictable revenue stream indexed to the node price, making project finance possible.

The stabilized price was originally a single flat rate matching the short-term node price. It guaranteed generators a predictable revenue stream regardless of hourly price volatility. This flat-rate structure triggered a boom in solar PMGDs, especially in the north where irradiance is highest and land is abundant.

The 2026 Shift to Time-Block Pricing

New PMGD projects in 2026 must accept six time-block prices instead of a single flat rate (Solarity, 2026). Daytime solar blocks, when PMGD PV plants generate the most, tend to have the lowest prices. Evening peak blocks have the highest prices.

This change hurts pure-injection projects that sell all generation at midday. It favors hybrid or self-consumption projects that can shift generation to peak hours or consume solar on site.

Grandfathering Until 2034

Existing PMGD projects that opted for the stabilized price before the reform keep the flat-rate regime until July 2034, according to Cuatrecasas (2026). However, any material change to connection or operating conditions — such as adding battery storage — can strip that protection and force the project into the new time-block regime.

FET Charge Debate

A proposed FET charge would have required PMGDs under the stabilized price to contribute to electricity subsidies. The charge was not approved by Congress in 2025, but the policy debate continues, according to Global Legal Insights (2025). The uncertainty alone has slowed PMGD investment.

Curtailment and Grid Congestion

The rapid growth of solar PMGDs in the north has created congestion. Record renewable energy curtailment reached 2,684 GWh in the first seven months of 2025, up 17% from the same period in 2024, according to Global Legal Insights (2025). The system coordinator has asked the Ministry of Energy to revise PMGD regulations to impose monitoring, forecasting, and curtailment requirements similar to larger generators.

If adopted, this would move PMGDs from a self-dispatch model to a more centrally coordinated model. For developers, that means lower capacity factors and more complex operations for pure-injection plants.

The Takeaway for Project Developers

PMGD is still attractive, but the easy arbitrage of the flat stabilized price is ending. Developers should model three scenarios: grandfathered flat pricing, time-block pricing, and hybridization with storage. Self-consumption PMGDs are structurally safer than pure-injection PMGDs under the new rules.

Hybridization is the most promising response. Adding batteries allows a PMGD to store midday solar and discharge during evening peak blocks, capturing higher time-block prices and reducing curtailment risk. However, as noted above, retrofitting storage can strip grandfathering. The decision to hybridize must be made with full knowledge of the regulatory consequences.

Regional Differences and Solar Resource

Chile’s geography creates three distinct solar markets.

Northern Chile: Atacama and Antofagasta

The Atacama Desert has among the highest solar irradiance on Earth. Commercial projects here achieve capacity factors above 30% and simple paybacks of 3–4 years with incentives. Mining and heavy industry dominate demand. Off-grid and behind-the-meter solar are common.

Central Chile: Metropolitan, Valparaíso, O’Higgins

Santiago and the central valley have good but lower irradiance. Capacity factors typically range from 18% to 24%. Higher retail tariffs and strong daytime commercial demand make Net Billing attractive. Residential payback without subsidies is 7–9 years; with Casa Solar or tax stacking, it falls to 4–6 years.

Southern Chile: Biobío to Magallanes

Irradiance drops further south, and cloud cover is more frequent. Solar still works, but paybacks are longer. Projects here rely more on self-consumption value than on export revenue. Agroindustry and distributed mini-grids are the main applications.

These ranges are industry-observed estimates. Actual results depend on tariff, system cost, financing, and self-consumption ratio.

Mining and Heavy Industry: Off-Grid and Behind-the-Meter Solar

Mining is Chile’s largest electricity consumer. Many mines operate in remote areas with weak grid access or high retail tariffs. Solar-plus-storage systems have become a standard tool for reducing diesel consumption and stabilizing power supply.

The Off-Grid Business Case

A remote mine that runs on diesel generators pays a high effective cost per kWh once fuel transport, storage, and maintenance are included. A solar PV plant with a battery energy storage system (BESS) can displace diesel during daylight hours and store excess for early evening. The payback depends on the diesel replacement cost, but projects often reach 4–7 years when fuel logistics are expensive.

The regulatory framework for off-grid mining systems is different from Net Billing and PMGD. These projects are typically captive generation assets, not market participants. They do not receive the stabilized price, but they also avoid grid charges and distribution losses.

Behind-the-Meter Solar for Grid-Connected Mines

Grid-connected mines with large daytime loads use behind-the-meter solar to reduce wholesale or regulated procurement costs. Because their demand often exceeds 500 kW, they are free clients and do not use Net Billing. They typically negotiate direct power purchase agreements or build PMGD/PMG assets.

For a deeper dive into this segment, see the off-grid solar case study linked earlier.

Common Mistakes and How to Avoid Them

Mistake 1: Sizing for Maximum Generation

Because Net Billing pays the energy-only price, exporting large surpluses is less profitable than consuming solar on site. The optimal system size matches daytime load, not roof area.

Mistake 2: Ignoring the Five-Year Credit Limit

Unused Net Billing credits expire after five years. Systems that over-produce in summer may never use all credits before winter shortfalls, especially if the load profile is flat.

Mistake 3: Starting Work Before Subsidy Approval

Casa Solar requires selection before installation. Installing first usually voids the subsidy. Always confirm the call status on the official AgenciaSE portal.

Mistake 4: Mixing Regimes Without Advice

A project just above 300 kW cannot use Net Billing. It must use PMGD rules. The interconnection study, metering, and settlement are different. Choosing the wrong regime at design stage can cost months and money.

Mistake 5: Assuming PMGD Grandfathering Survives Any Change

Adding storage to a grandfathered PMGD may force the project into the new time-block regime. Always get a legal and technical opinion before modifying an existing PMGD.

What Most Installers Get Wrong About Chilean Incentives

The biggest misconception is that Chile’s solar market is “deregulated and cheap enough to sell itself.” It is not. The country has one of the most layered incentive systems in Latin America, and the layers interact in ways that are not obvious.

The contrarian view: For commercial customers, the highest-return project is often smaller than the customer expects. A 100 kWp system that covers 80% of daytime load and exports almost nothing will usually beat a 300 kWp system that exports 40% of generation, even though the larger system has more total kWh. The reason is the Net Billing energy-only price. Self-consumed kWh avoids 150–180 CLP of retail cost. Exported kWh earns only 60–80 CLP. The difference changes the entire economics.

This is why proposal software that models hourly self-consumption is not a nice-to-have in Chile. It is essential. A solar design platform that imports the client’s interval consumption and simulates Net Billing credits by month will produce more accurate payback numbers than a simple annual production estimate.

The second misconception is that PMGD is always better than Net Billing because it is “bigger.” For a regulated customer with 400 kW of daytime demand, a 300 kW Net Billing system can be simpler and more profitable than a 400 kW PMGD. PMGD requires market registration, specialized metering, and exposure to time-block prices. The exception is free clients with demand above 500 kW. They cannot use Net Billing and must use PMGD or direct PPAs.

Incentive Stack by Customer Segment

Not every incentive applies to every project. The table below maps the most relevant incentives to each customer type.

The boundaries are not rigid. A medium manufacturer with 400 kW of daytime demand might split the load across two meters to stay under Net Billing, or might choose a single PMGD. The optimal choice depends on tariff structure, tax position, and appetite for regulatory complexity.

Practical Checklist for 2026

Use this checklist before signing a contract or starting construction.

For residential and small commercial customers:

• Confirm Casa Solar call status at casasolar.cl or agenciase.org.
• Get at least two quotes from SEC-certified installers.
• Request a self-consumption ratio estimate, not just annual production.
• Confirm the distribution company and meter upgrade timeline.
• Verify that the proposed inverter and modules are SEC-certified.

For commercial and industrial customers:

• Confirm whether the client is regulated or free.
• Model accelerated depreciation and VAT credit with the company’s accountant.
• Request CORFO or BancoEstado financing quotes if needed.
• Size the system to maximize self-consumption, not roof coverage.
• For projects above 300 kW, compare Net Billing (capped) vs. PMGD scenarios.

For PMGD developers:

• Model grandfathered flat price, time-block price, and hybrid-with-storage cases.
• Review connection and operating conditions before adding storage.
• Monitor DS 88 and DS 125 amendments through the Ministry of Energy.
• Confirm environmental permitting requirements early.

FAQ

What solar incentives are available in Chile in 2026?

Chile’s 2026 solar incentives include the Casa Solar residential subsidy (40–60% of installation cost), Net Billing under Law 21.118 for systems up to 300 kW, 100% accelerated depreciation and VAT credit for businesses, CORFO green credit and guarantee lines, BancoEstado Crédito Verde, and the PMGD stabilized-price regime for distributed generators up to 9 MW.

How does Net Billing work in Chile?

Net Billing in Chile allows regulated customers with renewable systems up to 300 kW to inject surplus electricity into the grid and receive a monetary credit on their bill. The credit is valued at the energy-only price, not the full retail tariff, so maximizing self-consumed solar yields the best return. Credits can accumulate for up to five years.

What is the PMGD regime in Chile?

PMGD covers distributed generators up to 9 MW connected to distribution networks. Qualifying projects can opt for a stabilized price set every six months by the Comisión Nacional de Energía under Supreme Decree 88. In 2026, new projects must accept time-block pricing rather than a single flat rate.

Can businesses combine accelerated depreciation with Net Billing?

Yes. Accelerated depreciation is a tax deduction that reduces taxable income, while Net Billing reduces the monthly electricity bill. They are independent and can be combined with the VAT credit and CORFO financing to cut effective project cost by roughly 45–55%.

Who qualifies for the Casa Solar subsidy?

Casa Solar is aimed at residential households and micro, small, and medium enterprises. Applicants must own the property, use an SEC-certified installer, and meet the income and property-value thresholds set by each call. As of May 2026, the second national call was largely exhausted, with new applicants placed on a waiting list.

What is the payback period for solar in Chile?

Residential solar payback in Chile typically ranges from 6–9 years without subsidies and 4–7 years with Casa Solar. Commercial and industrial projects that stack accelerated depreciation, VAT credit, and Net Billing often reach payback in 3–5 years in the north and central regions.

What changed for PMGD projects in 2026?

New PMGD projects in 2026 must accept six time-block stabilized prices instead of the previous flat rate. Daytime solar blocks usually have lower values, which reduces revenue for pure injection projects. Existing projects under the transitional regime keep grandfathered flat pricing until July 2034 unless they materially change connection or operating conditions.

Does Chile offer financing for commercial solar?

Yes. CORFO’s Energía Sostenible credit line, channeled through commercial banks, can finance up to 100% of a project with terms up to 20 years. CORFO also provides a green investment guarantee covering up to 60% of required collateral. BancoEstado’s Crédito Verde offers preferential rates and terms up to 10 years.

What is the difference between Net Billing and PMGD?

Net Billing applies to regulated customers with systems up to 300 kW and settles surplus energy as a bill credit. PMGD applies to larger systems up to 9 MW and operates as a market participant with a stabilized-price option or spot-market settlement. Customers with demand above 500 kW are typically free clients and use PMGD rather than Net Billing.

What is the most common mistake when claiming Chilean solar incentives?

The most common mistake is sizing for maximum generation instead of maximum self-consumption. Because surplus energy is paid at the energy-only price, systems that over-produce relative to on-site demand earn far less per kWh than systems that offset retail consumption.

Ready to design and quote Chilean solar projects faster? SurgePV’s cloud solar design platform includes hourly self-consumption modeling, Net Billing credit estimates, and automated proposal generation. See how it works on the solar design software page, explore solar proposals, or book a demo.