MISO DPP Site Control Requirements: A Developer's Complete Guide

How MISO's DPP differs from other RTOs

If you have developed projects in PJM or CAISO and are expanding into MISO territory, the Definitive Planning Process (DPP) will feel familiar in broad strokes but different in critical details. MISO's interconnection queue — governed by its Generator Interconnection Procedures (GIP) as amended by FERC Order 2023 compliance filings — uses a graduated threshold model like other RTOs, but with several structural differences that catch developers off guard.

The first and most significant difference is the entry threshold. MISO requires 50% site control at application. Compare that to PJM, which now requires 100% at application under its post-Order 2023 rules, or CAISO, which jumps to 90% at its first cluster study phase. For developers, MISO's 50% entry point is one of the most accessible among FERC-jurisdictional RTOs — but that lower bar means the queue attracts more speculative projects, which increases competition for study slots and can extend DPP cycle timelines.

The second difference is dual-track site control. MISO requires developers to demonstrate site control over both the generating facility footprint and the gen-tie (interconnection transmission line) route independently. PJM combines these into a single coverage calculation. CAISO tracks them separately in practice but does not enforce independent thresholds with the same rigor. In MISO, if your facility site is at 95% coverage but your tie-line route is at 40%, you fail the threshold — even though your blended average might exceed the required percentage.

The third difference is stage nomenclature. MISO maps its Definitive Study Agreement (DSA) stage to what FERC calls "system impact study" in the generic interconnection procedures. This matters because tariff references, compliance filings, and internal MISO communications use DSA terminology, while cross-RTO comparison tools (including our threshold reference table) normalize to FERC's generic stage names. Know both vocabularies.

Stage-by-stage threshold walkthrough

The following table shows MISO's DPP site control thresholds at each queue stage, based on MISO's GIP Section 4.1 and its FERC Order 2023 compliance filing effective January 1, 2024.

Several details merit emphasis. At application and feasibility, options-to-lease count at full weight (1.0), meaning a developer can enter the queue with 50% of their acreage covered by options alone. This is intentional — MISO recognizes that executing full leases before receiving interconnection study results creates a financial chicken-and-egg problem for developers. However, encumbrances are flagged starting at application, which means MISO will note agricultural preservation restrictions, conservation easements, and other title issues even if they don't block coverage yet.

The jump from 50% to 90% between feasibility and system impact study is the steepest ramp in the DPP. Developers who enter at exactly 50% have a narrow window to secure an additional 40% of site control — often while negotiating with landowners who know the project has received a queue position and may increase their asking price.

At DSA execution, options are excluded entirely. Any acreage covered only by an option-to-lease drops out of the coverage calculation. This is consistent with every other FERC-jurisdictional RTO, but MISO's DSA-specific timeline creates unique conversion pressure that we cover below.

Facility vs. tie-line site control

This is where MISO's requirements diverge most sharply from other RTOs, and where the most costly mistakes happen. MISO requires developers to demonstrate site control over two distinct geographic areas: the generating facility footprint and the gen-tie route. Both must independently meet the threshold for the current stage.

The facility footprint is the project boundary itself — the parcels where turbines, panels, inverters, substations, access roads, and laydown areas will be sited. This is typically a contiguous or near-contiguous land assembly of 500 to 5,000+ acres depending on technology and capacity. Demonstrating facility site control involves the same lease/option/fee-simple instruments familiar to any utility-scale developer.

The gen-tie route is the transmission line connecting the project substation to the point of interconnection (POI) on the MISO transmission system. This route may span 5 to 30+ miles and cross 10 to 50+ individual parcels owned by different landowners. Site control over the gen-tie requires right-of-way (ROW) agreements, easements, or fee-simple ownership for every parcel the route crosses.

The independent threshold requirement means a developer can have 100% facility site control but still fail the overall DPP requirement if their gen-tie ROW coverage is below the stage threshold. In practice, gen-tie site control is often the binding constraint. Here is why:

• Parcel fragmentation. A 15-mile gen-tie route might cross 30 parcels. Missing ROW agreements on even two or three parcels can drop coverage below 90%.
• Holdout landowners. Unlike facility parcels where developers can sometimes route around a holdout, a gen-tie route is geometrically constrained. If one landowner in the middle of the route refuses to grant a ROW, the developer may need to re-route entirely, which triggers new environmental and engineering studies.
• County road crossings and railroad crossings. These require separate crossing agreements with county highway departments or railroad operators, which operate on their own timelines and are often slower than private landowner negotiations.
• Parallel infrastructure. If the gen-tie route parallels an existing transmission line or pipeline, the existing easement holder may have exclusive-use provisions that prevent a new ROW on the same parcels.

Developers entering the MISO queue should budget 12 to 18 months for gen-tie ROW assembly on routes longer than 10 miles. Starting gen-tie landowner outreach at the same time as facility leasing — not after — is essential.

Attachment E affidavit

MISO's site control attestation takes a specific form: the Attachment E affidavit, defined in the MISO tariff. This is not a generic self-certification or a simple cover letter. It is a structured sworn statement that the interconnection customer has obtained the required site control for the generating facility and gen-tie route.

The Attachment E requires the following elements:

1. Project identification. Queue number, project name, POI, county, state, and nameplate capacity.
2. Facility site control summary. Total acreage of the project boundary, acreage under executed instruments, acreage under options, and the resulting coverage percentage. Each instrument type must be itemized.
3. Gen-tie route site control summary. Total number of parcels on the route, parcels with executed ROW/easement agreements, parcels with option agreements, and the resulting coverage percentage. Linear feet or miles of the route covered vs. total route length may also be required.
4. Instrument schedule. A table listing each instrument (lease, option, easement, ROW) with the parcel APN or legal description, landowner name, instrument type, execution date, expiration date, and recording status.
5. Sworn attestation. A notarized statement by an authorized officer of the interconnection customer that the information is true and correct to the best of their knowledge.

Common Attachment E errors that trigger MISO rejection or cure requests include:

• Mismatched acreage. The total acreage in the instrument schedule does not match the project boundary acreage filed in the interconnection request. This often happens when the project boundary is revised during studies but the Attachment E is prepared from the original boundary.
• Missing gen-tie parcels. The instrument schedule covers the facility site but omits one or more gen-tie route parcels. MISO checks both independently.
• Expired instruments listed as active. An option that expired between the time the schedule was prepared and the filing date is listed as active. MISO's review catches date mismatches.
• Unsigned or un-notarized attestation. The affidavit must be signed by an authorized officer and notarized. Draft or unsigned versions are rejected.
• Incorrect queue number. Projects with amended or reassigned queue numbers sometimes file under the old number.

Agricultural land risks in MISO territory

MISO's footprint spans some of the most productive agricultural land in the United States. Iowa, Minnesota, Illinois, and Indiana — the four states where MISO queues are most active for solar and wind — all have state-level agricultural protection laws that create site control complications.

Iowa

Iowa's Agricultural Areas law (Iowa Code Chapter 352) allows landowners to designate farmland for agricultural protection. While this does not create a right of first refusal (ROFR), it does trigger county board of supervisors notification requirements when the land use changes. Solar and wind developers must file a notice of proposed conversion with the county, and the county has a review period before the conversion can proceed. This adds 30 to 90 days to the site control timeline depending on the county.

Minnesota

Minnesota's Agricultural Preserve Program (Minn. Stat. §473H) and Green Acres Program (Minn. Stat. §273.111) both create encumbrances that affect site control. Agricultural Preserve land has a covenant that restricts non-agricultural use for 8 years after an owner files for withdrawal. Green Acres land has a tax recapture provision (3 years of deferred taxes) when converted to non-agricultural use. Neither creates a ROFR, but both create financial penalties and timeline delays that developers must factor into option-to-lease terms. An option that expires in 2 years on a parcel with a 3-year Green Acres recapture period may not be exercisable within the window.

Illinois

Illinois has county-level farmland protection ordinances rather than a uniform state law. Counties like McLean, DeWitt, Livingston, and Ford — all active MISO solar development areas — have adopted setback requirements, lot coverage limits, and conditional use permit processes for utility-scale solar. These do not directly affect site control coverage calculations, but conditional use permit denials can render a fully leased parcel unusable for the project, creating a de facto coverage gap even when the instrument is valid.

Indiana

Indiana's ROFR provisions under IC 32-31-6 apply to certain agricultural leases when the landowner receives an offer to purchase. While this is more relevant to fee-simple acquisitions than to leases, it can complicate site control if a developer's option-to-purchase is subject to a family member's ROFR. Additionally, Indiana counties have increasingly adopted solar ordinances with acreage caps and setback requirements that effectively reduce the usable project boundary — meaning the denominator in the coverage calculation changes after permitting.

Across all four states, the practical risk is the same: agricultural protection provisions extend timelines, create financial penalties, or reduce effective project acreage. Developers must diligence these encumbrances at the option stage, not after execution. An option on a parcel with a 8-year Agricultural Preserve covenant in Minnesota is worth substantially less than an option on an unencumbered parcel, even though both count the same in a raw acreage calculation. In MISO's DPP, encumbrances are flagged at application and disqualified at system impact study — so a parcel that counted at 50% entry may be excluded by the time you need 90%.

Wind and solar competition for land and capacity

MISO territory is unique among RTOs in that wind and solar projects compete directly for both interconnection capacity and land parcels in many regions. Iowa, Minnesota, and Illinois are top-5 states for both installed wind capacity and solar interconnection queue volume. This creates two forms of competition that affect site control strategy.

Land competition. A 200 MW solar project and a 300 MW wind project may seek options on overlapping parcels. Landowners who have already signed wind leases may have exclusivity clauses that prevent solar co-development, even on portions of the parcel not occupied by turbines. Developers must review existing wind lease terms during title due diligence — not just fee ownership and tax status.

Queue capacity competition. MISO's DPP cycle processes projects in batches. When multiple projects target the same POI or the same constrained transmission corridor, MISO's interconnection studies may identify network upgrade costs that make one or more projects uneconomic. A developer who has invested in 90% site control may withdraw from the queue after receiving study results showing $50M+ in network upgrades — but the competing project that caused those costs has already locked up alternative parcels in the area.

The strategic implication: in regions with high wind-solar overlap (particularly western Iowa, southwestern Minnesota, and central Illinois), developers should secure options with longer terms (3+ years) and negotiate exclusivity provisions that cover both wind and solar use, even if they only intend to develop one technology. This protects against the scenario where a competing project locks up your fallback parcels while you wait for study results.

Option conversion timeline

Like all FERC-jurisdictional RTOs, MISO excludes options from coverage at DSA execution. The conversion timeline — the window during which a developer must convert options to executed leases — is defined by the gap between the developer's current stage and DSA execution.

For a typical DPP cycle, the timeline looks like this:

• Application to feasibility study results: 6 to 12 months. Options count at full weight throughout.
• Feasibility to system impact study results: 12 to 18 months. Threshold jumps to 90%, but options still count. This is the primary conversion window.
• System impact to facilities study results: 6 to 12 months. Threshold stays at 90%. Final conversion opportunity.
• Facilities to DSA execution: 3 to 6 months. Options are excluded. Any unconverted options cause a coverage deficiency.

MISO's DSA has a specific consideration that other RTOs lack: the DSA itself is a bilateral agreement between the interconnection customer and MISO, and its execution deadline is a hard gate. Unlike PJM's Interconnection Service Agreement (ISA), which has a more structured negotiation period, MISO's DSA execution deadline is tied to the DPP cycle timeline and is not easily extended. Missing the deadline can result in queue withdrawal.

A conversion deadline alert should fire at least 90 days before DSA execution for any project containing unconverted options. At that point, the developer has three paths: exercise the options, negotiate replacement instruments on the same parcels, or restructure the project boundary to exclude uncontrolled parcels (which requires re-running the coverage calculation and may trigger study amendments). For a deeper dive on option expiration mechanics, see Option-to-Lease Expiration and Interconnection Milestones.

Common mistakes in MISO DPP site control

Based on patterns observed across hundreds of MISO interconnection applications, these are the most frequent and costly site control errors:

1. Missing tie-line parcels

The single most common cause of Attachment E rejections. Developers focus on facility site control and treat the gen-tie as an afterthought. A 20-mile gen-tie route crossing 35 parcels with ROW agreements on only 28 of them yields 80% tie-line coverage — which fails the 90% threshold at system impact study. The fix is expensive: either negotiate the remaining 7 ROW agreements under time pressure (landowners know they have leverage) or re-route the gen-tie (which may trigger new environmental review).

2. Attachment E format errors

The Attachment E has a specific format defined in the MISO tariff. Submitting a generic site control letter, a spreadsheet without the sworn attestation, or an affidavit that does not separately itemize facility and gen-tie coverage will trigger a cure request. Cure periods are typically 10 to 15 business days, but the clock on the DPP cycle does not stop. Developers who burn their cure period on formatting issues lose time they could have spent resolving substantive coverage gaps.

3. Option expiration before DSA

A 2-year option executed at the time of application may expire before DSA execution if the DPP cycle runs long. MISO DPP cycles have historically taken 30 to 42 months from application to DSA execution. An option with a 24-month term that was executed 6 months before application has only 18 months of remaining life at application — likely insufficient to reach DSA. Developers should negotiate option terms of at least 36 months, with extension provisions tied to queue milestones.

4. Ignoring agricultural encumbrances until system impact

Encumbrances are flagged at application but disqualified at system impact. A developer who enters the queue at 55% coverage with several encumbered parcels may calculate that they are comfortably above the 50% threshold. But at system impact, those encumbered parcels are removed from the numerator, potentially dropping coverage below 90% even if total acreage under instrument exceeds the threshold. Diligence encumbrances before signing options, not after.

5. Treating MISO thresholds like PJM thresholds

Developers who operate primarily in PJM sometimes assume that MISO's 100%-at-IA-execution rule means they need 100% at application. They over-invest in early-stage site control, executing leases on parcels that may not be needed if the project boundary changes during studies. Conversely, developers who know MISO's 50% application threshold sometimes under-invest, entering with exactly 50% and scrambling to reach 90% by system impact. The right approach is to enter at 60-70% and have a clear path to 90%+ with identified parcels and option agreements already in negotiation.

Sources

• MISO Generator Interconnection Procedures (GIP)
• FERC Order 2023 — Interconnection Final Rule Explainer
• MISO GIP Effective 2024-01-01 (PDF)
• LBNL Queued Up 2025 — Characteristics of Power Plants Seeking Transmission Interconnection
• Iowa Code Chapter 352 — Agricultural Areas
• Minnesota Statutes §473H — Agricultural Preserves

Related articles

• FERC Order 2023 Site Control Coverage Thresholds by RTO and Stage — The cross-RTO reference table comparing thresholds, option weights, and encumbrance policies across all seven markets.
• Option-to-Lease Expiration and Interconnection Milestones — How option expirations interact with queue milestones and the conversion timeline that determines whether your coverage holds.
• FERC Order 2023 Site Control FAQ — Eligible instruments, option weights, the 5-filter audit, and SNDA requirements.