Revolve’s CAD $7.63 Million Ontario Deal Puts a Public Price on Operating Commercial Behind-the-Meter Batteries

Six operating behind-the-meter batteries at commercial and industrial sites across Ontario changed hands on August 12 for CAD $7.63 million. The portfolio totals 14.2 MW and 24.3 MWh. That works out to roughly CAD $314 per kilowatt-hour of installed capacity for assets already built, already contracted, and already producing cash.

Revolve Renewable Power completed the purchase of Trillium Storage Limited Partnership. Stem, Inc. operates the portfolio under a master services agreement.

Transactions in this segment almost never print. Commercial behind-the-meter storage is sold building by building, financed privately, and held to term. A completed purchase of an operating portfolio, disclosed by a listed buyer, is the closest thing the segment has to a mark.

The multiple. Revolve guided the portfolio to annual revenue of CAD $2.12 million to CAD $2.97 million and EBITDA of CAD $1.62 million to CAD $2.79 million. Against a CAD $7.63 million purchase price, that is a range of 2.7 to 4.7 times EBITDA.

Residual-value assumptions in third-party-ownership models are ordinarily set by appraisal rather than by observed sales, because observed sales in this segment are scarce. One has now cleared at a low single-digit multiple, which is a data point any such assumption has to be reconciled against.

The margin. The disclosed guidance implies an EBITDA margin between 76 percent and 94 percent. That margin is consistent with avoided-cost revenue rather than energy sales.

Ontario’s Industrial Conservation Initiative bills Class A customers for Global Adjustment in proportion to their share of the province’s five highest system-demand hours of the year. A battery that discharges into those five hours reduces the host’s allocation for the following twelve months. There is no fuel cost and no market bid, and with Stem holding the operations contract, minimal operating overhead sits with the asset owner. The mechanism is a close analogue to a United States demand charge, settled on a twelve-month tail instead of a monthly one.

The financing. Revolve funded the deal with a USD $11 million bridge credit facility. The facility is larger than the purchase price in nominal terms, and bridge debt is short-dated by construction, which places a refinancing event ahead of the asset cash flows rather than alongside them. The CAD $314 per kilowatt-hour figure is therefore a transaction price observed under a specific and time-limited financing arrangement, not a settled market clearing level.

The tariff underneath. Everything in the EBITDA line traces back to how Ontario allocates Global Adjustment, and the province is reconsidering that allocation.

Ontario has opened a consultation on a proposed framework that would create a separate and higher electricity rate class for new data centers above 1 MW and would make those facilities ineligible for the Industrial Conservation Initiative. RTO Insider, which reported the proposal, put the consultation close at September 12, 2026. Roughly 100 to 200 MW of current data-center demand sits inside the program today, against more than 10,000 MW of cumulative connection applications.

The arithmetic is straightforward. Global Adjustment costs are allocated among Class A participants according to their share of the five peak hours. Adding hyperscale load to that pool spreads the same recoverable costs across a larger denominator and dilutes what any individual participant can save by shaving those hours. Excluding new data centers holds the denominator where it is.

Working in the other direction, the 14 percent Global Adjustment relief that Class A customers received from 2021 through 2025 begins phasing out in 2026. Relief withdrawal raises the Global Adjustment charge that Class A customers face, which raises what each avoided peak hour is worth. Both the exclusion proposal and the relief phase-out point the same way for the assets Revolve has just acquired, though neither is settled.

The duration. At 24.3 MWh across 14.2 MW, the portfolio runs at 1.7 hours.

The prevailing industry position holds that storage needs four hours to attract institutional capital, a view built on wholesale capacity accreditation and arbitrage spreads. A 1.7-hour fleet has now completed a disclosed sale to a listed buyer on the strength of contracted host revenue. Peak-allocation and demand-charge assets are being valued on what they do, which is to be available for a small number of expensive intervals rather than to shift bulk energy overnight.

The read-across. Ontario is not a United States market and the Industrial Conservation Initiative is not a United States tariff. The transferable content is structural rather than jurisdictional.

First, a public price now exists for operating commercial behind-the-meter storage, and it sits at a low single-digit EBITDA multiple. That is a discipline on residual-value assumptions wherever such assets are underwritten.

Second, the enterprise value of a portfolio like this one is a derivative of a rate mechanism the regulator controls. Ontario’s regulator is simultaneously weighing an action that would concentrate the benefit among existing participants and unwinding a legacy discount that has held Class A bills down for five years. Commissions in the United States are working through the same question about whether large flexible loads belong inside coincident-peak allocation, and the answer determines the revenue of every battery whose function is to discharge during the hours that set the bill.

The valuation of these assets rests on an avoided cost that a regulator can revise on a timetable unrelated to the buyer’s financing.

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