SPP's Western adequacy stop-gap draws protests, including from its own market monitor

The stop-gap SPP filed on Sept. 4 to carry its Western balancing area to mandatory adequacy rules is now contested at the Federal Energy Regulatory Commission, where three Western counterparties want it rewritten and SPP's own market monitoring unit wants it thrown out. The balancing area holds roughly 9.2 GW of nameplate capacity, but between April and August only 4.7 GW of it was available to the market, against the 6.5 GW the grid operator expected, and SPP's own reading of the summer is that supply problems came largely from market participants failing to bring enough energy into the market.

The monitor's objection goes to the mechanism: requiring every market participant to hold a physically balanced position in real time, it argues, interferes with the economic trade of energy between regions, penalizes participants unjustly, is gameable and leaves market participants without clarity. Read together, those charges amount to an argument that the region should trade its way out of its shortfall, and that the proposal forecloses the trade. Utility Dive first reported the monitor's position, along with the protests of the Western Area Power Administration, Basin Electric Power Cooperative and Guzman Energy, which contend that SPP's proposal for a Western region covering mainly parts of Colorado and Wyoming is flawed and requires changes.

What SPP proposed on Sept. 4 is a two-part position check for the hours just ahead of dispatch: a first evaluation would compare an asset owner's available energy in a day-ahead reliability unit commitment hour with its obligations for that same hour, and a second would run 20 minutes before the operating hour begins. The timing of the second suggests a participant learns it is short with almost no room left to answer for it, and neither check carries a payment for the capacity that would have avoided the shortfall.

Four and a half gigawatts of nameplate never appeared as available energy this summer, which put the Western BAA at just over half its installed capacity and 1.8 GW below SPP's own expectation. The nameplate suggests the equipment was there and the offers were not, on the operator's account, which is why the interim fix polices positions instead of pricing capacity; if a real-time balancing mandate does foreclose interregional trade, coverage of the gap will have to come from inside the footprint, from cooperatives, municipal utilities and WAPA units whose procurement runs through planning cycles and contracts rather than a traded market.

The operator's own market monitoring unit has lined up against the operator's filing, a sharper fact for FERC than any protestor's argument, after SPP determined that the summer's emergency alerts came largely from participants failing to bring enough energy into the market and its monitor argued the remedy would penalize participants, be gameable and leave the rules unclear. The commission has to weigh those two accounts, and whichever it prefers, the interim rule it approves is what participants trade under until June 2027.

The membership list is worth reading twice. SPP's expanded footprint includes Basin Electric, Colorado Springs Utilities, Deseret Generation and Transmission Cooperative, the Municipal Energy Agency of Nebraska, Platte River Power Authority, Tri-State Generation and Transmission Association, and three WAPA units—the Colorado River Storage Project Management Center, the Rocky Mountain Region and the Upper Great Plains Region—which puts WAPA and Basin Electric on both sides of the docket, as footprint members and as protestors, while the coverage does not place Guzman Energy inside the expanded footprint. The entities arguing over the terms of the region's adequacy obligation are largely the same ones that will have to satisfy it.

The docket exists because of a calendar gap. SPP expanded its regional transmission organization footprint into the Western Interconnection in April, and under the rules FERC approved, the Western balancing area has no resource adequacy requirement in effect until June 1, 2027. The interim months have not been quiet: SPP said in its Sept. 4 proposal that it issued three energy emergency alerts between April and August, plus other warnings, and that record is what the stop-gap answers.

Whatever FERC does with the stop-gap, the instrument that prices Western capacity is the mandatory rule arriving in June 2027, and the interim proposal creates no capacity payment, pays nothing for availability, and checks positions twice in the hours before dispatch. That leaves an asset with obligations in the Western BAA facing a test it must pass and, on these terms, no interim price at which passing it is rewarded; the design of the 2027 rule is therefore the thing for capital to underwrite, and the stop-gap is mainly a statement about how the region intends to hold participants to account in the meantime.

This publication has argued that grid access is the asset and generation a derivative of permission, and the SPP West docket is that argument as arithmetic: 9.2 GW of energized capacity yielding 4.7 GW of market supply, with the remedy under debate a position test rather than a contract. FERC has been willing to decide market access on procedure, as its procedural rejection of Oklo's 750 MW Virginia project out of PJM's queue showed this month, and the commission's order on the monitor's objection, and the adequacy rule it approves for June 2027, are where the next price signal for Western capacity gets written.