Voltus lowers peak demand rather than building new generation.
Important facts
PJM filed the Reliability Backstop Procurement on July 31, 2026. It is a one-time procurement aimed at the 6,831 MW shortfall left by the 2028/2029 Base Residual Auction, which cleared at the $325/MW-day cap across the entire footprint. PJM proposes to secure resources for terms of up to fifteen years, at a maximum willingness to pay equal to a MW-weighted average of $555/MW-day. Requested effective date is September 29, 2026. The central bid window opens September 30 and closes October 21. As of September 6, 2026, FERC has not acted on the filing.
The first Voltus issue concerns Qualifying RBP Offset UCAP MW, or QRBPO — the mechanism that reduces the volume PJM procures centrally and socializes across ratepayers. Proposed Tariff Attachment DD, section 18.2(b) lists six eligible resource categories. Five are generation or storage: new builds, uprates of existing capacity resources, incremental capacity from Surplus Interconnection Service, repowering of units deactivated before April 10, 2026, and incremental capacity from a fuel-type change to a more efficient fuel. The sixth and only demand-side category reads “Planned Demand Resource or Planned DER Capacity Aggregation Resources.” It is silent on whether incremental capacity at an existing registered location qualifies, and silent on whether a location that once participated and dropped out can return. On the generation side both are named explicitly.
The second issue concerns the Stage 1 gating criteria that a bid must clear to be evaluated. For generation and storage, section 18.5(f)(i)(1) through (8) asks for a critical path construction schedule, evidence of one hundred percent site control for a term of at least three years, financing and permitting plans, signed memoranda or other evidence that major equipment has been or will be procured, evidence of construction experience, a notice of intent or attestation for natural gas delivery infrastructure where applicable, and for resources outside PJM, a confirmed transmission service request with a completed system impact study. These are plans and evidence of seriousness, not executed commitments. For demand-side resources, section 18.5(f)(i)(10) requires executed customer agreements or binding commitments covering the proposed RBP UCAP MW, with identified locations, customer names, and expected curtailment or injection capability per site. Sections 18.5(c)(ii) and 18.5(d)(i) separately require identifying locations and associated participation contracts for the full length of the fixed term. Voltus reads the two together as a requirement to hold fifteen-year contracts with every underlying site before the October 21 bid deadline.
Voltus states plainly that it does not oppose approval of PJM’s filing. It argues that Bring Your Own New Capacity and related frameworks develop new capacity more efficiently than central procurement, and it credits PJM for including the demand side at all, which it says was not a foregone conclusion. Its position is that demand-side eligibility as written must at minimum survive into the final tariff, for precedential reasons as much as for this procurement.
What it asks for
Two redlines. The first appends a clause to section 18.2(b)(vi) making demand-side QRBPO eligible unless the resource relies on locations that supported a Demand Resource providing capacity in the 2026/2027 delivery year, and even then eligible for capacity resulting from investment in new generation or storage at that location. Voltus argues this closes the gaming door, because 2026/2027 registrations are already fixed and no location can retroactively sit out to qualify. It also asks that the same criteria define Bring Your Own New Capacity in the Interim Resource Adequacy Service docket, ER26-3515-000, so that a megawatt counted as QRBPO also reduces a large load’s IRAS exposure.
The second restructures the gating criteria into pre-auction and post-auction tests. Pre-auction evidence would reflect the investment made to reach auction readiness; post-auction evidence would reflect execution after a clearing price exists. Concretely, Voltus would strike the executed-customer-agreement requirement at 18.5(f)(i)(10) and replace it with a detailed description of the expected composition of the offered megawatts, plus evidence of arrangements with DER asset partners where relevant. It would add a criterion at (11) for an equipment procurement plan or evidence of deployed enabling infrastructure such as metering, telemetry, load control, and SCADA or dispatch systems. It would also strike the requirement at 18.5(c)(ii) and 18.5(d)(i) that participation contracts run the full length of the fixed term.
The underlying argument is that an aggregator can commit to fifteen years even when no individual retail customer will. Portfolio underperformance in one segment is balanced by overperformance in another, churn is priced in ahead of time, and committed UCAP can be refilled with other eligible sites as contracts lapse. A generator that shuts down mid-term cannot replace itself. RPM deficiency charges, Voltus notes, already penalize an aggregator that bids volumes it cannot deliver.
Author and credits
Submitted by Kimaya Abreu, Senior Manager, Regulatory Affairs, Voltus, Inc., 2443 Fillmore Street, San Francisco. Dated August 21, 2026.
Link
https://elibrary.ferc.gov/eLibrary/filelist?accession_number=20260821-5318
Summary
The filing is structured as two discrete complaints about asymmetry, each followed by proposed tariff text. It is not a protest. Voltus concedes the urgency, concedes PJM’s good faith, and concedes that the backstop will likely proceed. What it disputes is whether the demand-side eligibility PJM wrote into the tariff will produce any actual demand-side bids. Voltus’s answer is no: the gating criteria will function as a fence rather than a gate, and few if any aggregators will offer.
The argument complicates the prevailing story in both directions. Against the reading that PJM shut out demand response, the document shows PJM adding demand-side eligibility in response to stakeholder pressure and writing an uprate allowance into RBP supply eligibility at 18.5(c) that Voltus then uses as leverage. Against the reading that inclusion settles the matter, it shows how a facially neutral evidentiary standard — prove your resource will exist — produces sharply different burdens when applied to a construction project and to an aggregation of retail customers. The generation criteria are calibrated to a developer several years from commercial operation who has not yet signed final financing. The demand-side criteria are calibrated to nothing in particular.
One inconsistency deserves attention before the filing is cited. Voltus asks FERC to align QRBPO eligibility with PJM’s Bring Your Own New Capacity criteria, and its redline is the vehicle for that alignment. But PJM’s own BYONC framework, as set out in its July 27, 2026 CIFP executive summary, disqualifies demand-side locations registered in DR Hub for either the 2026/2027 or the 2027/2028 delivery year. The Voltus redline names only 2026/2027. Adopted verbatim, it would make QRBPO broader than BYONC rather than aligned with it, and would leave 2027/2028 registrations — which are not yet fixed — available as a qualifying pathway. That is the gaming concern Voltus says its language forecloses.
Conclusions
The document lands on a narrow ask, deliberately. PJM told the Commission it would accept discrete changes consistent with the filing’s objectives, and Voltus wrote to that opening rather than to the merits of central procurement, which it says elsewhere it considers the inferior tool. That choice is the filing’s central tactical fact and its main limitation as a source: it argues about eligibility mechanics and declines to argue about whether a fifteen-year socialized procurement at $555/MW-day is the right instrument.
It leaves unresolved who bears the cost. Voltus notes in passing that PJM does not propose, and may be jurisdictionally unable, to charge large loads directly for RBP costs, and that other ratepayer classes may end up exposed depending on retail rate design and large load default risk. That is stated as background to the QRBPO argument, not developed. It is also the single largest open question in the proceeding.
edited and authored by Dave with close collaboration by Claude