Puerto Rico’s electricity customers must brace for higher bills beginning July 1, a development that may seem contradictory after the Puerto Rico Energy Bureau (PREB) approved lower revenue requirements in its landmark April 15 rate decision. The contradiction reflects the combination of past under‑collection, structural changes in rate design, the tapering of federal reconstruction funds, […]
Puerto Rico’s electricity customers must brace for higher bills beginning July 1, a development that may seem contradictory after the Puerto Rico Energy Bureau (PREB) approved lower revenue requirements in its landmark April 15 rate decision. The contradiction reflects the combination of past under‑collection, structural changes in rate design, the tapering of federal reconstruction funds, and new adjustments to fuel and subsidy riders that PREB finalized on June 30.
The most immediate driver of the July 1 increase is a deficit left over from Fiscal Year 2026. When PREB imposed temporary, provisional rates last July, those charges were intentionally conservative. Regulators were still auditing thousands of pages of filings from LUMA, Genera, and PREPA, and they did not want customers paying inflated amounts while the review was underway. Once PREB completed its analysis this spring, it determined that the provisional rates had not collected enough money to meet the FY26 revenue requirement. The shortfall was precisely calculated: the FY26 Total Reconciliation Amount is $98.7 million. Under Puerto Rico’s rate‑setting framework, that entire amount must be recovered over the next fiscal year. PREB ordered that the full $98.7 million be charged to customers between July 1, 2026, and June 30, 2027 in its April 25 rate decision. That alone guarantees an upward adjustment in rates, even though PREB approved lower revenue requirements going forward.
The April 15 decision itself reshaped Puerto Rico’s rate structure. PREB rejected the utilities’ request for a dramatic increase in base‑rate revenues and instead approved a three‑year revenue requirement of $1.779 billion for FY26, $1.782 billion for FY27, and $1.785 billion for FY28. Regulators slashed hundreds of millions of dollars in proposed capital spending, shifted projects to federal funding, and removed inflated cost assumptions. PREB emphasized affordability and insisted that ratepayers should not shoulder costs that could be covered by FEMA or the Department of Energy. But the decision also acknowledged the fragile state of Puerto Rico’s electrical system, noting widespread equipment failures, aging infrastructure, and the island’s lack of access to capital markets. PREB warned that federal funds are finite and that the island faces a tapering of FEMA and DOE reconstruction dollars as the 10‑year Hurricane María recovery window closes. Once federal funds diminish, capital projects that PREB shifted away from rates will eventually return to the rate base, creating upward pressure in future years.
Even with the lower revenue requirement, FY27’s baseline cost to operate the grid still rises slightly to $1.78 billion. When the $98.7 million reconciliation amount is added, the total revenue PREB must extract from ratepayers reaches $1.88 billion. Customers are therefore paying both for the coming year’s operations and for last year’s deficit. And beginning in FY27, PREB introduces revenue decoupling, a mechanism that automatically adjusts rates if electricity sales fall short of projections. With rooftop solar adoption accelerating and population declining, decoupling is likely to trigger upward adjustments to ensure the utilities meet their approved revenue targets.
The PREB issued a resolution on June 30 that adds another layer to the July 1 increase. PREB reviewed the quarterly fuel and purchased‑power adjustment factors and found that international oil markets had been unusually volatile due to geopolitical tensions in the Middle East, particularly the conflict involving Iran. After a ceasefire reduced pressure on global energy markets, PREB required LUMA to update its projections to reflect lower fuel prices. PREB also examined costs associated with natural gas supply shortfalls tied to alleged contractual breaches by New Fortress and Naturgy. Because those costs may ultimately be recovered through legal claims, PREB determined that passing them immediately to customers would be premature. Instead, the Bureau ordered the deferral of $13.2 million. These decisions lowered the fuel adjustment factor from 0.125935 ¢/kWh to 0.114070 ¢/kWh, offering some relief to customers even as other components of the bill rise.
PREB also finalized annual subsidy and CELI adjustment factors for FY27. The Bureau reconciled over‑ and under‑collections from the prior year and approved new annual factors for municipal tax offsets, social subsidies, and non‑social subsidies. Some riders will decrease due to over‑collection, while others will increase because revenues fell short of actual costs. These adjustments, though technical, directly affect the per‑kilowatt‑hour charges customers will see beginning July 1.
Structural changes in the rate design will also be felt immediately. PREB doubled the fixed monthly customer charge for standard residential customers from $4 to $8, a move intended to ensure that all grid‑connected users contribute to the system’s basic upkeep regardless of consumption. The Bureau also created a dedicated Pension Fund Rider to safeguard payments to PREPA’s Employees’ Retirement System. Although PREB intends to convert this into a flat monthly fee, LUMA’s legacy billing software cannot yet support that format, forcing regulators to temporarily collect pension costs through a volumetric charge on each kilowatt‑hour consumed.
Former Popular Democratic Party Secretary General Jorge Colberg Toro, who is now a consultant, said the latest one‑cent increase in the electricity rate reflects the quarterly fuel adjustment and the volatility in global oil markets, noting that “the price of the barrel can change overnight depending on what happens in the Middle East.”
He added that structural pressures will continue pushing rates upward, because federal reconstruction funds cover only about 40 percent of the electric grid and the remaining 60 percent must eventually be financed through local revenue.
Colberg emphasized that the Energy Bureau has refused to authorize increases for capital improvements while billions in federal funds remain unused, but he warned that long‑term factors — including the slow conversion of generation units to natural gas, delays in adding 1,200 megawatts of solar energy, and the future obligation to pay bondholders — will inevitably create upward pressure. Without those changes, he said, fuel costs and debt payments could drive the kilowatt‑hour price toward “38 or even 40 cents,” a level he described as economically unsustainable.
Taken together, these elements explain why customers may see higher bills starting July 1 despite PREB’s decision to lower the utilities’ revenue requests. The increase is not a contradiction; it is the mathematical consequence of reconciling last year’s under‑collection, implementing a new fiscal‑year revenue requirement, preparing for the tapering of federal reconstruction funds, adjusting fuel and subsidy riders, and restructuring fixed charges to stabilize the grid’s finances. PREB’s April 15 and June 30 decisions were designed to protect affordability, but they also made clear that Puerto Rico’s electrical system remains financially and operationally fragile.
