Summary

  • Deriva says $280 million of financing has closed for Frontier, a 302 MW, four-hour battery project that is to transfer to OG&E under a build-transfer agreement.
  • OG&E separately estimated $393.8 million in initial project cost, excluding taxes and construction-period financing costs. The two figures have different scopes; the difference does not disclose an equity need.

The headline is not a full funding map

Deriva’s 12 October announcement supplies one clear number: $280 million in financing to support construction of Frontier Energy Storage in Kay County, Oklahoma. The company names CIBC and KeyBanc Capital Markets as coordinating lead arrangers and joint bookrunners, with CIBC as administrative agent. It does not publish the borrower-level financing structure, interest rate, maturity, draw schedule, security, guarantees, covenants or debt-to-equity split.

The utility’s regulatory filing supplies a different number. OG&E estimated the project’s initial all-in cost at $393.8 million, excluding allowance for funds used during construction (AFUDC) and taxes. The estimate includes contract costs, OG&E’s own owner costs and contingencies. Some component amounts, including the purchase price under the build-transfer agreement (BTA), are redacted in the public testimony.

Putting $280 million beside $393.8 million can show scale, but it cannot establish a 71% loan-to-cost ratio or an $113.8 million equity gap. The financing scope is not disclosed, while the utility estimate includes owner and contingency items and excludes AFUDC and taxes. One is a financing announcement; the other is a utility cost estimate filed in December 2025.

Construction funding runs ahead of ownership

Frontier is a 302 MW battery with four hours of output and 1,208 MWh of energy capacity, according to OG&E testimony. The distinction matters: megawatts describe the rate at which the facility can discharge; megawatt-hours describe the energy it can store and deliver over time. Neither rating proves how much usable capacity the completed plant will provide under operating conditions.

The BTA, executed on 8 December 2025, puts Deriva in charge of building the project before OG&E buys the facility. OG&E told regulators it would not pay Deriva until mechanical completion, expected in late 2027. Deriva’s financing therefore supports the construction phase that precedes the utility’s payment and ownership handover. OG&E’s filing separately identified summer 2028 as the period when the project’s capacity would align with a utility need.

Those milestones are related but not interchangeable. Mechanical completion can trigger payment and transfer; it is not the same as a full operating record. OG&E’s testimony lists owner-engineering oversight and post-construction performance tests to check the facility against design and technical specifications. The public sources do not disclose the full acceptance checklist, lender remedies for delay or the detailed warranty package.

Tax credits shaped the contract form

Deriva offered OG&E both a tolling structure, under which the utility would buy capacity and net energy, and a BTA, under which it would buy the asset. OG&E’s filing says the larger tolling option initially ranked better in its comparison. After considering the federal investment tax credit available if OG&E owned the project, the 302 MW BTA ranked best in the utility’s evaluation.

That tax-credit timetable influenced construction choices. OG&E’s witness described a four-year safe-harbour requirement and said the parties changed to a different transformer with a 2024 start-of-construction date, giving the project until the end of 2028 to qualify. The witness said the credit could reduce overall cost by 30%; that is the utility’s filed assessment, not a guarantee of the final customer benefit. A schedule that slips can affect both the handover and the tax-credit economics.

Approval opens the route; it does not certify output

The Oklahoma Corporation Commission voted 2–1 on 6 August 2026 to approve the proposed final order in OG&E’s pre-approval case. The minutes record two votes in favour and one against. Deriva subsequently described the project as regulator-approved. That cleared a significant institutional gate before the October financing close.

It did not turn forecasts into results. OG&E’s filing said Frontier would cover only part of its projected capacity shortfall. The utility also identified the project as its first utility-scale battery to be owned and operated directly. The public record supports a defined development, contract and approval path; it does not yet show commissioning, output, availability or a final review of every dollar in the cost estimate.

Tariff exposure is shared, not erased

OG&E’s testimony says the BTA contains a change-in-tariff provision under which OG&E and Deriva share tariff risk. The public filing does not reveal the precise allocation. It also identifies construction contingency and post-build performance testing as separate cost and control points. This is a more useful description of risk than treating the $280 million close as proof that all execution risk has moved to lenders or to the future utility owner.

The transaction is best read as a sequence: financing is closed for construction; the developer is expected to reach mechanical completion; OG&E then pays for and owns the facility; testing and operating evidence follow. The public documents explain the sequence more clearly than they explain the financing’s price or protections. Those missing terms matter if the schedule, tariffs or acceptance tests change.

Sources