MISO-SPP IPSAC 05/14 Meeting Key Takeaways
MISO-SPP IPSAC Overview
The May 14, 2026 MISO-SPP Interregional Planning Stakeholder Advisory Committee meeting focused on two major topics: the 2024–25 Coordinated System Plan study and MISO-SPP’s compliance approach for FERC Order 1920/1920-A. The agenda included a CSP Studies Update followed by a FERC Order 1920 Compliance Update.
The meeting showed that MISO and SPP are continuing to strengthen their interregional planning process while largely relying on the existing Joint Operating Agreement framework. The main objective is to complete the current CSP study, justify recommended interregional transmission solutions, and prepare required Tariff and JOA updates for FERC Order 1920 compliance.
Coordinated System Plan Study Update
The 2024–25 Coordinated System Plan study is focused on the southern MISO-SPP seam. The study evaluated reliability, transfer capability, and congestion issues using 2034 and 2039 study models. MISO and SPP reviewed 70 proposed solutions and identified three key corridors along the seam. The draft Core and Core+ portfolios showed performance improvements across reliability, economic, and transfer capability screening metrics.
The study is now in the solution justification phase. MISO and SPP are evaluating endpoint feasibility, cost estimates, and adjusted production cost savings before finalizing recommendations. The RTOs plan to share results, request stakeholder feedback, and then determine the path forward for approval during Q3 and Q4 2026.
Interregional Project Benefits and Cost Allocation
MISO and SPP explained that interregional project benefits are evaluated using JOA Section 9.3 criteria. The three primary benefit categories are adjusted production cost savings, avoided or deferred reliability projects, and public policy benefits. For a project to qualify as an interregional project, it must provide benefits to both regions, meet JOA criteria and go through cost allocation based on benefits received.
The cost allocation process is benefit-based. First, MISO and SPP determine whether a proposed project produces qualifying benefits. Then the cost split between the two RTOs is calculated based on proportional benefits. After that, each RTO applies its own regional tariff to allocate costs within its footprint. This structure is intended to ensure that each region pays in proportion to the value it receives.
The RTOs also discussed additional benefit analyses beyond traditional production cost savings. These include avoided reliability investment and mitigation of extreme weather impacts. These additional metrics are intended to support a more complete business case for major interregional transmission investments.
Stakeholder Feedback
Stakeholders provided significant feedback on portfolio selection, voltage options, business-case development, methodology, cost allocation, and schedule. Some stakeholders supported the Core portfolio, while others requested additional portfolio variations or stronger consideration of 765 kV alternatives. There was also interest in grid-enhancing technologies and non-wires alternatives.
A major stakeholder concern was that screening-level results are not enough to justify large transmission portfolios. Stakeholders requested a transparent and comprehensive business case before final recommendations are selected. In response, MISO and SPP stated that they are developing analyses based on production cost savings, avoided reliability investment, and extreme weather resilience benefits.
Stakeholders also requested more clarity on cost allocation before decisions are made. MISO and SPP responded that interregional cost allocation will follow the JOA, while regional cost allocation will follow each RTO’s tariff. The RTOs plan to explain these details further in upcoming IPSAC meetings.
FERC Order 1920 Compliance
The second major topic was FERC Order 1920/1920-A compliance. The order requires neighboring transmission planning regions to improve coordination on long-term interregional transmission planning. MISO and SPP stated that their existing long-term planning processes are generally well-positioned for compliance, but updates are still needed to reflect new transparency and coordination requirements.
The compliance process has two phases. Regional planning compliance is due June 12, 2026, while interregional planning compliance is due December 12, 2026. MISO and SPP may pursue an extension to February 12, 2027, but intend to submit earlier if they are prepared.
The RTOs’ initial assessment is that their current processes are generally compliant. However, they need to revise interregional coordination procedures to explicitly cover long-term transmission needs, interregional facilities, joint evaluation of cost-effective solutions, and public posting of additional information.
Next Steps
MISO and SPP have started drafting governing document updates, coordinating with neighboring planning regions, and preparing stakeholder review activities. Redline reviews are expected in July and August 2026, followed by regional review through MISO PAC and SPP stakeholder forums in October. Executive review and filing preparation will occur in October and November, ahead of the December 2026 filing deadline.
For the CSP process, the immediate priority is completing the 2024–25 study recommendations. The 2026 CSP study is expected to begin in late Q3 or early Q4 2026 after assumptions are refined and the final issue set is confirmed.
Key Takeaway
The meeting shows that MISO and SPP are moving from technical screening toward project justification, stakeholder review, and compliance filing. The central challenge will be demonstrating that recommended interregional projects provide clear reliability, economic, public policy, and resilience benefits while ensuring that cost allocation remains transparent and aligned with benefits received.
As interregional transmission planning and FERC Order 1920 compliance efforts continue evolving across MISO and SPP, Zero-Emission Grid (ZEG) helps developers, utilities, and large load customers navigate transmission planning, interconnection strategy, grid modeling, and long-term infrastructure planning across North America’s evolving power markets. Contact us to get started today.
