Dominican Energy Framework

1. Electricity market structure

Law 125-01 segmented the sector into three functionally separated activities: generation (competitive market, public and private agents), transmission (state monopoly under ETED) and distribution (three regional state companies: EDE Norte, EDE Sur, EDE Este). Regulated end users are served by EDEs, while non-regulated users (large consumers above the SIE threshold) can contract directly with generators or marketers.

The wholesale market operates under economic dispatch coordinated by the SENI Coordinating Body, which orders generation units by marginal cost and clears transactions. PPAs are the main hedging instrument.

2. Concession regime

Any generation project of meaningful size requires a concession to operate. The typical process has two stages: provisional concession (granted by CNE, enables studies and measurements at a site for a limited period) and definitive concession (authorizes construction and commercial operation, with binding investment and schedule commitments). For renewables, CNE handles the grant under Law 57-07; for other technologies, SIE is more actively involved.

3. Law 57-07 incentives

The Renewable Energy Incentive Law grants the concession holder a fiscal package that has been decisive for project financing: VAT exemption on local purchases and imports of equipment, income tax exemption on revenues during a defined period, tariff reductions for inputs not produced locally, and a tax credit on investment in self-production. Incentives require prior qualification, scheduling, milestone compliance and periodic reporting to CNE.

4. Grid access and tolls

Connecting a new project to SENI requires technical studies coordinated with ETED, allocation of available capacity and payment of regulated tolls. Evacuation capacity in main corridors —particularly south and east, where solar resource concentrates— has been a structural bottleneck. Regulation sets criteria for allocation order and re-powering, but grid expansion pace is among the most relevant factors in project due diligence.

5. Tariff regime

The regulated end-user tariff is computed from EDEs' average purchase cost plus recognized distribution and commercialization costs, in periodic SIE reviews. There are differentiated tariffs by consumption level and user type, plus targeted subsidy mechanisms. When the gap between technical tariff and applied tariff is negative, it translates into fiscal transfers to EDEs.

6. Contractual aspects for investors

A typical renewable generation project contemplates: PPA with counterparty (CDEEE / EDE in contracted projects or non-regulated user in bilateral projects) for 15-20 years, with fixed or indexed tariff; connection agreement with ETED; environmental licenses from the Ministry of Environment (including EIA where applicable); and municipal permits and land use. International financing (IDB Invest, IFC, commercial banks with multilateral coverage) is common and imposes ESG standards beyond local requirements.

7. Where the sector is heading

Three fronts will define regulatory evolution: storage integration (grid batteries and firmness for intermittent renewables), electric mobility (tariff regulation, charging points, incentives) and natural-gas conversion of the thermal mix. Any project beyond five years should factor these dynamics into regulatory risk analysis.