Context and synthesis
Cross-Cutting View: Where Each Institution Stands#
The matrix runs across two tables because eight columns will not fit legibly on one page. The first covers FERC, NERC and the three regions with the most developed large-load programmes; the second covers the remaining four jurisdictional operators, all of which are now working to the same August 17 deadline. The split is presentational, not analytical — since June 18 all six regions have been answering the same set of questions.
The same eight problems, read across the institutions. The first table covers FERC, NERC, ERCOT, PJM and MISO; the second covers SPP, NYISO, ISO-NE and CAISO. No institution leads on all six. ERCOT — the one grid outside FERC's jurisdiction — leads on the operational rules and trails on cost allocation, while PJM inverts that pattern.
| Issue | FERC | NERC | ERCOT | PJM | MISO |
|---|---|---|---|---|---|
| 1. Queue / speculative load | Category 1 showcause; readiness screens | Registration criteria (indirect) | Batch Zero (in force 7/11/26); $50k/MW; SB6 gating | CIFP-LLA loadforecast reform | Queue cap; largeload study reform |
| 2. Resource adequacy gap | RA reports due 7/20/26 | Reserve sizing for clustered load loss | BYOG; ~23 GW added 2024–25 | Backstop procurement (capped $555/MW-day); EIT | ERAS (~27 GW, 90day GIA); MTEP EPR |
| 3. Cost allocation | Category 2; anticost-shift mechanisms | Out of scope | $50k/MW security; state-led | “But-for” assignment; loadbilled backstop | ERAS upgrade costs to the customer |
| 4. Ride-through / dynamics | Defers to NERC | Level 3 Alert (5/4/26); Project 2026-02 standard by YE2026 | NOGRR282 / NPRR1308 — ahead of NERC | Modeling and telemetry work | Load modeling and telemetry reform |
| 5. Co-location / BTM | Dec 2025 §206 order; rehearing 6/18/26; Categories 3 & 5 | Guideline-level only | WLPUN / PCLR; Form X due 7/10/26 | Firm & Non-Firm Contract Demand; CIR adjustment | Show-cause response pending |
| 6. Flexible load | Category 4 | Flexibility credited in 2026 guideline | Controllable Load Resource; ramp-rate rules | Non-firm service; DR expansion | “Speed-to-reliablepower” workstream |
| 7. Jurisdiction / non-RTO | Transmission-only baseline; §205 invitation to nonRTO TOs | Registration binds loads across the jurisdictional line | Outside FERC jurisdiction; PUCT is the sole authority | 13-state governors’ principles; state tariffs (Ohio, Virginia, Pennsylvania) | Multi-state footprint; tariffs set state by state |
| 8. Off-grid / islandable | Categories 3–4 reach BTM and flexible load service | Registration + coordinated islanding; BTM modeled explicitly | WLPUN one-minute leash; ramp-rate rules | Standby/exit-fee tariffs; stranded-cost exposure (AEP) | BTM resources in resource-adequacy modeling |
Table X1 — The eight problems against the five bodies furthest along. Reading down a column gives an institution's whole agenda; reading across a row shows how differently the same problem is being answered. The blank and thin cells are as informative as the full ones.
Sources: FERC; NERC; ERCOT; PJM; MISO, from the filings listed in the Catalog.
| Issue | SPP | NYISO | ISO-NE | CAISO |
|---|---|---|---|---|
| 1. Queue / speculative load | HILL and HILLGA study processes in force since 15 Jan 2026 — the most developed gating of the six. | Load interconnection procedures above 10 MW at 115 kV or higher, or 80 MW below; own reform to a Dec 2026 board filing. | No express large-load provisions; FERC recorded a less urgent concern. ISO-NE and the New England transmission owners have said they will seek a 90-day abeyance. | No traditional Order 888 service, so the study framework differs structurally. |
| 2. Resource adequacy gap | CHILLS conditions long-term service on curtailability rather than on new supply. | Generation-adequacy informational report due 20 Jul 2026. | Same informational report; existing capacity auction unchanged for large load. | Jul 20 report: no systemic adequacy shortfall, attributed to integrated CEC/CPUC/CAISO planning rather than to tariff terms. Adequacy runs through the CPUC programme. |
| 3. Cost allocation | HILL allocates study and upgrade cost to the requesting load. | FERC flagged cost shifting through the Transmission Service Charge when speculative requests drive local planning. | Not separately addressed; falls within the general show-cause findings. | Not separately addressed; falls within the general show-cause findings. |
| 4. Ride-through / dynamics | Defers to NERC. | Defers to NERC. | Defers to NERC. | Defers to NERC; inverter-based resource experience is the most extensive of the four. |
| 5. Co-location / BTM | Addressed through the conditional-service framework rather than a separate co-location rule. | FERC found no co-location terms in the tariff — a named deficiency. | No express provisions. | No express provisions; behind-the-meter generation is prevalent but governed by state rules. |
| 6. Flexible load | CHILLS, accepted 5 Jun 2026 — the closest instrument in force to a bounded curtailment product. | Special Case Resources, an established aggregator programme built for smaller commercial load. | Active Demand Capacity Resources, likewise aggregator-mediated. | Proxy Demand Resource and the Demand Response Auction Mechanism. |
| 7. Jurisdiction / non-RTO | Multi-state footprint; terms set state by state below the tariff. | Single-state footprint; the NY Department of Public Service runs a parallel state initiative. | Six-state footprint with six commissions and no single state counterpart. | Largely single-state; the CPUC holds the retail lane and the state has its own large-load proceedings. |
| 8. Off-grid / islandable | Telemetry and curtailability conditions apply to conditional service. | Show-cause response pending. | Show-cause response pending. | Show-cause response pending. |
Table X2 — The remaining four jurisdictional operators. Read alongside the table above. The pattern across both is that depth of programme tracks how early a region began rather than how much load it faces: SPP, with a fraction of PJM’s data-center interest, has the most complete set of instruments in force, while ISO-NE and CAISO are largely answering the show-cause orders from a standing start.
Sources: FERC show-cause orders of June 18, 2026, and the tariff materials of SPP, NYISO, ISO-NE and CAISO.
Three observations hold across the twelve columns. Ride-through is the one row where every operator except ERCOT defers to NERC, which is why the December 31, 2026 filing carries the weight it does — no region is building an alternative. Flexible load is the row with the most activity and the least standardisation: five different instruments, none interoperable, and the two that reach gigawatt-scale customers (SPP’s CHILLS and PJM’s Non-Firm Contract Demand) postdate the others by a decade. And cost allocation is the row where the RTOs have the least room, because the terms that decide it are retail terms held by the states (Section 7), which is why the FERC column is fuller than any regional one.
The near-term watch list that appeared here has been consolidated into Upcoming Dates and Events: A 12–18 Month Watchlist, which now sits before Section 1 and extends the horizon to mid-2028.