Commercial solar power in the Philippines refers to grid-connected and behind-the-meter photovoltaic (PV) systems serving commercial, industrial, and institutional consumers. In the Philippines, the segment is shaped by the Renewable Energy Act of 2008 (Republic Act No. 9513),[1] the Energy Regulatory Commission’s (ERC) net metering rules,[2] DOE circulars on program enhancements,[3] and corporate procurement mechanisms such as Retail Competition and Open Access (RCOA) and the Green Energy Option Program (GEOP).[4] According to the DOE, cumulative net-metering capacity reached about 141 MW between 2015 and 2024, with an additional 252 MW registered as “own-use” renewable energy.[5] In 2025, the Institute for Climate and Sustainable Cities (ICSC) launched the SPECTRUM solar mapping tool, which detected roughly 1,846 MW of rooftop PV nationwide (widely reported as “over 1.8 GW”), indicating that many systems are not captured by official registration.[6][7] The disparity between official and detected capacity has been covered in national media as a regulatory challenge with implications for grid stability and long-term energy planning.[8]
Commercial solar encompasses on-site PV systems that offset a customer’s own consumption with or without export to the distribution grid. It excludes utility-scale, merchant solar plants built to sell into the Wholesale Electricity Spot Market (WESM) or under Green Energy Auction Program (GEAP) awards.
Notes on terminology
**Net-metering (NM):** ERC framework for ≤100 kW RE systems interconnected to a distribution utility, with peso-denominated bill credits for exported energy.[2]
**Distributed Energy Resources (DER):** ERC rules for 100 kW–1 MW systems, enabling limited export with partial compensation.
**Own-use RE:** DOE classification for customer-sited renewable generation not exporting to the grid.
**RCOA (Retail Competition and Open Access):** allows large “contestable” consumers to contract power supply directly from licensed Retail Electricity Suppliers.
**GEOP (Green Energy Option Program):** allows end-users with ≥100 kW demand to contract 100% renewable supply from authorized GEOP providers.[4]
Policy and regulation
Net-metering (≤100 kW)
The ERC’s Net-Metering Rules allow qualified end-users to interconnect RE systems up to 100 kW and receive bill credits for exported energy valued at the distribution utility’s blended generation cost.[2] The DOE’s 2020 circular broadened coverage and clarified annual net-generator expectations.[3]
2024 update
In August 2024, DOE issued Department Circular DC2024-08-0025, allowing unused Net-Metering Credits to be banked and removing the requirement for a separate REC meter once ERC issues a methodology for computation.[9]
Distributed Energy Resources (100 kW–1 MW)
ERC’s DER Rules, effective 14 December 2022, created an export pathway for systems larger than the 100 kW net-metering cap. Export energy is compensated at 75% of the utility’s blended generation rate for 100–500 kW systems and 60% for >500 kW up to 1 MW, with a 30% export cap on nameplate capacity (as described by the distribution utility).[10] DER projects require a Distribution Impact Study (DIS), a Distribution Asset Study (DAS), and compliance with the Philippine Electrical and Distribution Codes.[11]
Corporate procurement (RCOA and GEOP)
Under RCOA, contestable customers with average monthly peak demand ≥500 kW may contract with a licensed Retail Electricity Supplier (RES).[12] Under GEOP, end-users with demand ≥100 kW can source 100% renewable energy from authorized GEOP suppliers.[4]
Market development
Official DOE data reported cumulative net-metering capacity of about 141 MW between 2015 and 2024, alongside 252 MW of registered “own-use” renewable energy projects.[13] Independent assessments suggest the actual rooftop base is much larger. In July 2025, ICSC’s SPECTRUM mapping detected around 1,846 MW of rooftop PV nationwide, more than seven times the officially registered total.[14][15] This indicates that only about 21% of rooftop PV capacity is formally registered and regulated, leaving the majority untracked. Analysts warn that this disparity complicates distribution utility planning and may pose risks for grid stability and forecasting.[16] Independent estimates of delivered rooftop generation costs remain in the range of ₱2.50–₱5.30 per kWh, generally lower than fossil-fuel retail electricity rates.[17]
Interconnection and standards
Grid interconnection follows the Net-Metering Interconnection Standards (Annex to ERC’s 2013 rules) and references the Philippine Distribution and Electrical Codes for protection and safety.[2] DOE and utilities also publish technical manuals on testing, commissioning, and interconnection.[18]
Market participants
Several local and international firms operate in the Philippines’ commercial and industrial solar segment. Independent coverage has noted EPCs, multinational developers, and distribution utilities.[19]
Key participants
**TotalEnergies Philippines** – expanding into distributed solar.[20]
**Aboitiz Power Corporation** – via AboitizPower Distributed Energy.[21]
**Solaren Renewable Energy Solutions** – Central Luzon-based EPC with nationwide projects.[22]
**Solaric Corporation** – early rooftop solar installer in Metro Manila.[23]
**Philergy Solar** – German-Filipino solar EPC in Manila.[24]
**Buscovitz Energy** – independent provider in Luzon.[25]
**SolarNRG Philippines** – affiliate of Dutch SolarNRG.[26]
Corporate renewable suppliers (RCOA / GEOP)
The Department of Energy’s official GEOP supplier list (May 2024) confirms the following authorized suppliers relevant to commercial procurement:
The Philippines has seen rapid uptake of commercial solar installations, but several challenges remain:
**Grid interconnection and permitting** – lengthy approvals slow deployment.
**Capital intensity** – high upfront costs remain a barrier.
**Local government unit (LGU) involvement** – adds oversight and complexity to approvals and compliance.[28]
**Policy uncertainty** – changes in net-metering and incentives affect investor confidence.
**Unregistered rooftop systems** – the large number of untracked installations highlighted by SPECTRUM may pose risks to grid stability, demand forecasting, and long-term planning.[29]
Overall outlook remains positive, with growth expected from rooftop deployments and corporate procurement under RCOA and GEOP, though better alignment between registered and detected capacity is seen as important for stable integration.
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