SPP MOPC July 2026 Meeting Overview
SPP MOPC met on July 14–15, to address a broad range of policy, tariff, transmission planning, generation interconnection, resource adequacy, and operational reliability matters. Consent-agenda items passed with unanimous or near-unanimous approval, and two revision requests pulled from consent (RR767 and RR768, both related to Conditional High Impact Large Loads (CHILLs) were separately approved by wide margins after standalone discussion. The meeting also featured continued planning updates tied to the Western RTO expansion, large-load integration, and long-range transmission strategy.
Interconnection & Generator-Related Items: RR786, RR767, & RR783
- GI Quarterly Update: SPP staff reported continued progress reducing the generator interconnection study backlog, executing a record number of Generation Interconnection Agreements, and advancing the DISIS 2024 Phase 1 restudy. Work also continues toward transitioning generator interconnection studies to the future Consolidated Planning Process (CPP) model framework.
- ITP Waiver approved (99% approval): The committee invalidated certain Local Generator Interconnection Model (L-GIM) stability requirements for the Future 2 Year-20 case in the 2026 ITP/CPP Transition Assessment, citing unrealistic underlying model assumptions and a need to limit distortion from extreme sub-regional export scenarios.
- RR786 – CPP Governing Language Clarifications (96% approval): Establishes separate regional/subregional Generalized Rates for Interconnection Development (GRID-C) contributions for the SPP East Region and sets a revenue distribution methodology to West subregions. Staff noted that without this change, CPP study timing could add roughly eight months to Generator Interconnection Agreement (GIA) timelines. A competing amendment to carve out treatment of the Eastern Interconnection portion of the LAP Zone failed (65% approval), so the original motion carried.
- RR783 – Modification Request Impact Study (MRIS) Methodology Tariff Alignment (GIAG) and RR755 – SPP GI EMT Study Process (RTWG) remained on the agenda under the Transmission Working Group for continued working-group development; no committee vote is reflected in this meeting’s minutes.
- Other interconnection/generator-facilities RRs tracked through committee: RR764 (Generating Facilities Modeling Requirements), RR765 (Provisional Load Process Improvements), RR775 (IEEE 2800 Phase 2 additions to Attachment AY), RR780 (Aggregate Transmission Service Study Improvements), and RR774 (POI Constraints and Clipping).
- RR767 – CHILL Clarifications (99% approval) and RR768 – CHILL Outage Criteria (99% approval): Both were pulled from the consent agenda for separate votes. RR767 clarifies how CHILL-related curtailment commitments must be defined, sequenced, and operationally feasible; RR768 accommodates planned generator outages that support a CHILL while preserving SPP’s ability to curtail for reliability.
Tariff, Cost, and Market Items
- RR784 – 2030 and 2032 Planning Reserve Margin (100% approval): Codifies the previously Board/RSC-approved PRM values of 17% (Summer) and 38% (Winter) into Section 4 of the Planning Criteria.
- RR763 – DPP Incentive Point Criteria (92% approval): Revises the Detailed Project Proposal incentive-point methodology in response to a high volume of proposals and an Order 1000 task force directive to improve the process.
- Redbud–Mathewson 345 kV project: Referred back to SPP staff after its estimated cost exceeded the established cost cap and in-service bandwidth; staff will further evaluate whether the project still delivers sufficient regional economic value within the 2026 ITP.
- TCR shortfall correction: Staff is pursuing an expedited FERC filing to fix a formulaic error (identified after the Western RTO expansion) that understated Day-Ahead congestion revenues and misallocated charges between TCR holders and other market participants; the fix restores the Board-approved calculation without changing underlying policy.
- Continued evaluation of a 765 kV backbone concept, with a specific project update on Crawfish Draw–Minco–Seminole 765 kV.
Large Loads and Emerging Policy
- FERC Show Cause Order (large loads): SPP staff outlined the Commission’s preliminary findings across four areas — transmission service provisions, cost/cost-shift transparency, co-location frameworks, and service options for flexible large loads — and how existing/planned SPP initiatives are intended to respond.
- Price Adaptive Load Service (PALS): A new market/transmission service concept in development for flexible, price-responsive loads, addressing participation model, transmission service framework, reliability safeguards, and resource adequacy treatment; being developed partly in response to large-load integration concerns and the FERC Show Cause Order.
Governance & Process
- Stakeholder Process Enhancement: The Corporate Governance Committee endorsed further work on (1) a fast-track framework for high-priority revision requests/policy initiatives, (2) streamlining the RR process while preserving stakeholder input, and (3) removing affiliate votes from committee decisions.
- 2027–2031 Strategic Plan: Board-approved plan centers on reliability/affordability, energy development, interregional connectivity, and organizational excellence; a new “Intermediate Planning” process was introduced to bridge near-term reliability needs and long-term transmission planning.
Industry Outlook
SPP’s evolving planning framework reflects rapid load growth, increasing interconnection activity, and expanding transmission needs.
For developers and IBR owners, evolving EMT, modeling, IEEE 2800, and CPP interconnection requirements will remain key considerations. Large-load customers will be impacted by emerging approaches to transmission service, cost allocation, co-location, CHILLs, and flexible load participation, while transmission stakeholders will continue to evaluate 765 kV expansion, interregional transfer capability, and cost-effective network solutions.
Stakeholders should closely monitor these developments as they will shape interconnection timelines, technical study requirements, transmission investment, and cost allocation across the SPP footprint.
As SPP continues advancing policies for large-load integration, generator interconnection, transmission planning, and market design, staying informed is critical for developers, utilities, investors, and other grid stakeholders. Zero-Emission Grid (ZEG) provides timely coverage and expert analysis of stakeholder meetings across ISOs, RTOs, utilities, and regulatory bodies throughout North America. Contact us for more information and subscribe to our newsletter to receive the latest meeting summaries, regulatory updates, and market insights delivered directly to your inbox.
