California’s Largest Convention Hotel Signed 20 Years of Gas Cogeneration for 94 Percent of Its Load, With a Claimed 40 Percent Tax Credit

A 3 MW natural gas combined-heat-and-power microgrid will carry up to 94 percent of the electric load at the Gaylord Pacific Resort and Convention Center in Chula Vista, inside San Diego Gas and Electric territory.

Unison Energy will build the microgrid. Developer RIDA Chula Vista signed a 20-year energy-as-a-service agreement, announced August 3, 2026, with the 94 percent sizing confirmed by Unison on September 17.

First-year savings come to $1.09 million, an 18.5 percent reduction, and $35.9 million across the contract term. Waste heat feeds domestic hot water, and the plant can island during grid outages. The project claims a 40 percent investment tax credit: a 30 percent base plus a 10 percent energy community adder tied to the brownfield South Bay Power Plant site.

The contract form. The energy-as-a-service structure moved the capital requirement off the hospitality owner’s balance sheet. What the owner signed was a two-decade obligation to buy energy from a third party building generation equipment on its site.

That is the same procurement form the behind-the-meter storage industry has worked to standardize, and it closed here for gas cogeneration at a large California property, in a utility territory where medium commercial summer demand charges reach $68.80 per kilowatt.

The credit question. The 30-plus-10 rate stack is common to both federal investment credits. The consequential question is which section the equipment qualifies under, and the answer determines whether the structure is repeatable.

Legacy Section 48 listed combined heat and power among eligible energy property, with a begin-construction cutoff. Section 48E, the technology-neutral successor, conditions electricity generation eligibility on an anticipated greenhouse gas emissions rate not greater than zero, and separately names energy storage technology as qualifying property without an emissions test attached.

Combustion of pipeline natural gas does not reach a zero emissions rate. A CHP project seeking 48E would need a fuel pathway, renewable natural gas or another qualifying low-carbon fuel, to clear the threshold. That leaves two possibilities for a 40 percent credit on a gas-fired plant announced in August 2026: a begin-construction position established under legacy Section 48, or a fuel and emissions pathway that satisfies 48E. Unison has not published a begin-construction date or named the credit section, and the statutory mechanics summarized here warrant independent confirmation against the code and current Treasury guidance before any party relies on them.

The asymmetry. For anyone pricing on-site energy at a large commercial building in 2027, the difference in how the two technologies reach the credit is the durable part of this transaction. Gas cogeneration has to qualify into the technology-neutral credit on an emissions test it does not meet on pipeline fuel. Storage is named in the statute directly. The Gaylord Pacific economics may rest on a credit position that new gas entrants cannot replicate, while the storage alternative keeps an eligibility that does not depend on a construction vintage.

The program calendars. State capital for commercial storage is arriving on a slower clock than the contract signed in Chula Vista.

The Maryland Energy Administration’s Residential and Commercial Energy Storage Program closed its application portal after requests consumed the full $2 million FY2026 budget drawn from the Strategic Energy Investment Fund. Seventy-six percent of funds were reserved by May 11, 2026, against an original June 5 deadline. The agency had anticipated an FY2027 launch in summer 2026. The portal remains closed, with no reopening date or FY2027 budget published.

Illinois is earlier still. The Illinois Power Agency is releasing written feedback questions for its Storage for All program this month with a virtual workshop in October, and the program as scoped incentivizes storage co-located with solar developed under Illinois Solar for All. The Energy Storage Procurement Plan that will govern final program design carries an Agency draft deadline of June 1, 2027.

A commercial building with no host solar array and a 2026 decision date has no Illinois program to underwrite against, and an oversubscribed Maryland program with no published reopening is thin anchoring for a pipeline. Projects in both states are left pricing against demand charges and the federal credit alone.

The genset commitment. The gas side of on-site commercial power is also where the quarter’s largest capital commitment landed. Amazon signed an agreement with Generac carrying an $8 billion ceiling, with $2.4 billion of deliveries actually scheduled across 2027 and 2028. Separately, the deal includes a warrant for 1,693,745 Generac shares at $200.9266, vesting in tranches tied to Amazon’s own payments.

Generac projected roughly $450 million of data-center revenue in 2026 and held a $1.6 billion data-center backlog before the deal, so the scheduled volume runs at several times the current rate. The company has disclosed no plant, shift pattern, engine supplier or unit count for the ramp, and no siting or permitting status for where the machines will run.

Both transactions closed in the same quarter and both are gas. One is a hospitality property buying twenty years of cogeneration on an energy-as-a-service contract under a credit position it has not disclosed. The other is a hyperscaler underwriting engine-generator capacity through 2028 at a supplier whose commercial and industrial line also sells into buildings.

The federal credit architecture has drawn a line between combustion and storage, placing one inside the technology-neutral credit by name and leaving the other to qualify on an emissions test. The contracts signed this quarter were priced before that distinction has been tested at scale.

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