Start Here: Your Project in One Sentence

• Give the project a short name and a one-sentence description (generation type, size, and location).
• Which of these best describes the project owner or primary contact? Options: Independent Power Producer / Renewable Developer, Utility Resource Planner, State Energy Agency Director, IPP with merchant risk, Other
• Which RTO/ISO is the project located in? Options: MISO, PJM, SPP, CAISO, NYISO, ERCOT, Other / multiple
• What is the current contractual status with the offtaker/utility? Options: PPA fully executed, PPA conditional / contingent, Letter of intent / term sheet, No PPA yet, Other
• What single date should we be tracking as the must-meet timeline (PPA COD, PPA expiry, or contractual milestone)?
• Where is the project in the interconnection process today (select the best fit)? Options: Pre-application / scoping, Feasibility / cluster study, System impact study, Facilities study / cost allocation, Queued but awaiting upgrades, Other / multiple stages

If This Slips, Who Pays the Price?

• If your PPA delivery date slips or the project cannot interconnect on time, what worst-case outcome are you most concerned about?
• Who bears the immediate financial exposure if the project fails to meet the delivery date or interconnection milestone? Options: Developer, Offtaker / Buyer, Utility, State agency, Shared / depends on contract, Unknown
• Which contractual protections currently exist to mitigate timing or delivery risk? Options: Liquidated damages, Force majeure, Extension provisions, Performance guarantees, Insurance products, None / unknown
• Estimate the scale of the revenue or penalty exposure if delayed (ballpark $/year or % of project value).
• Beyond dollars, what reputational or strategic losses would a missed delivery create (relationships, future procurement, regulatory standing)?

Who Actually Decides — And Who Could Stop It?

• Tell us about the one person or committee with real veto power over continuing the project—what would make them say no?
• List the key internal and external stakeholders by role (example: Board, PSC, County Commissioners, Landowners, RTO planners).
• How aligned are these stakeholders on moving forward right now? Options: Fully aligned, Mostly aligned with minor objections, Divided with clear opposing camps, Actively opposed by key stakeholders, Unclear / unknown
• Which stakeholders face immovable timeline pressures that will drive decisions (select all that apply)? Options: PPA counterparty, Lenders / investors, State regulator (PSC), Local permitting authorities, Affected landowners / tribes, RTO selection deadlines, Other
• Who is accountable for cross-organizational coordination (name or role) and how frequently do they meet to resolve blockers? Options: Weekly, Biweekly, Monthly, Quarterly, Ad hoc / as needed

Is Transmission Really The Root Cause — Or a Symptom?

• If we assume transmission isn’t the true root cause, what alternative explanations would explain your delays or curtailment?
• What historical dispatch, curtailment, or availability data do you have that demonstrates the scale and timing of the issue? Options: Curtailment hours per year, MW curtailed annually, Seasonal or occasional peaks, No data / not collected, Other
• Which formal studies or analyses currently exist (name and stage), and who authored them?
• What operational or market actions have you already tried (and what were the outcomes)? Options: Redispatch agreements, Battery/storage deployment, Curtailment compensation arrangements, Re-contracting of offtake, No operational fixes tried, Other
• Which grid locations (nodes, substations, corridors) are consistently implicated in constraints, and what are the observed failure modes (thermal, voltage, stability, protection)?

What 'Good' Actually Looks Like — The Metrics That Must Be Met

• If the RTO were to pick a winner tomorrow, what single measurable outcome would most convince them to select this project?
• Which of these success signals are required versus optional for you? (select all that apply) Options: On-time PPA delivery date, Reduction in annual curtailment (%), Cost per MW-mile / $/MW, Benefit-cost ratio (B/C) threshold, Improved reliability indices (SAIFI/SAIDI), RTO technical compliance metrics, Speed to energization (months)
• From the list you selected, pick the top three and provide numeric targets or thresholds for each (e.g., reduce curtailment by X% or meet COD by mm/yyyy).
• What cost ceiling or cost-allocation approach would be politically and contractually acceptable? Options: Fully developer-funded with negotiated recovery, Participant-funded by beneficiaries, Traditional regulated rate recovery, Split allocation (shared), Unknown / conditional
• Who inside the RTO, utility, or regulator will validate these metrics during selection or review (name/role)?

Lines You Can’t Cross — Non-Negotiables and Red Lines

• What absolute constraints would immediately prevent you from accepting a proposed route or solution?
• Which routing exclusions must we honor (select all that apply)? Options: Protected/critical habitat, Tribal lands, Urban centers / municipal limits, Military / federal restricted zones, Existing ROW avoidance, Scenic / historic areas, None of the above
• Are there seasonal permitting or construction windows (e.g., nesting, migration) that are immovable for your approvals? Options: Yes — specify seasons in follow-up, Yes — fixed permit windows, No seasonal constraints, Unknown / needs assessment
• What are your minimum financing and credit requirements (collateral, LOCs, guarantees) to proceed with developer-led construction? Options: Full cash collateral, Letter of credit, Parent company guarantee, Performance milestones with draw triggers, No additional security required, Other
• Do any existing contracts (PPA, interconnection agreement, state law) explicitly rule out particular delivery or cost-allocation models? Options: Yes — cost allocation restrictions, Yes — delivery point or metering restrictions, Yes — timeline or penalty clauses, No, Unknown / need review

Imagine Energized — The Tangible Benefits and the Lingering Worries

• If a new transmission line were energized tomorrow, what would be the first three operational or commercial changes you’d expect to see?
• Quantify the expected improvements where possible (increase in capacity factor %, reduction in curtailment MW or %, revenue retained $/year).
• How will your offtaker or utility measure success post-energization (select all that apply)? Options: PPA milestones met, Reduced redispatch costs, Higher delivered MWh, Improved reliability metrics, Successful rate recovery, Other
• What strategic opportunities would a successful energization unlock for you (additional PPAs, expansion, market position)?
• After energization, what residual risks would you still consider high concern? Options: Regulatory reallocation of costs, Unforeseen operational limits, O&M cost escalation, Post-construction landowner litigation, Environmental mitigation obligations, Other

Ready, Set, Go — Decision Triggers and Immediate Next Steps

• What one concrete milestone, decision, or event would make you comfortable authorizing an RTO filing?
• Which deliverables must be in-hand before your executives sign off on moving to the next phase (select all that apply)? Options: Updated cost estimate / budget, Route feasibility / preliminary engineering, Environmental desktop assessment, Letters of support or NOIs, Financial commitments / LOIs from buyers or lenders, Technical RTO modeling ready for submission
• What partnering model would you prefer for the next phase? Options: Developer-led with negotiated service agreements, Utility partnership with transfer at COD, Joint venture with shared equity, Build-transfer-operate, Other
• What governance, reporting cadence, and decision gates do you require during development and pre-filing? Options: Weekly technical calls, Monthly executive updates, Quarterly board reviews, Milestone-based steering committee, Ad hoc / as needed
• List the immediate obstacles to starting the next phase and assign an owner for resolving each (name/role and expected resolution timeframe).

Quick Project Snapshot — help us get our bearings

• Project name and the legal entity that holds the PPA or interconnection queue position
• Which role best describes you for this submission? Options: Renewable energy developer, Utility resource planner, State energy agency director, Independent power producer (IPP), EPC / construction lead, Other
• Project location (state(s), county(ies) — list primary site of generation and nearest transmission hub)
• Primary offtake instrument and key contractual date you are working to (choose one) Options: Bilateral PPA (utility), Corporate VPPA / C&I PPA, Auction/RFP award, Merchant (no PPA), Other
• Contracted commercial operation date (COD) or PPA delivery date (MM/YYYY if applicable)
• How confident are you today that the current interconnection queue timing will allow you to meet that date? Options: Very confident, Somewhat confident, Uncertain, Unlikely to meet date

Queue Reality Check — if the queue were a countdown clock

• If the queue timeline were a five-year countdown, how many realistic years remain before you can expect energization under the current queue path? Options: <1 year, 1–2 years, 3–4 years, 5+ years, Unknown
• What is your current RTO/TO interconnection milestone? (select the single best match) Options: Pre-application / scoping, System Impact Study requested, System Impact Study issued, Facilities Study, Study complete, awaiting construction, In construction, Withdrawn/On hold, Other
• Please provide current queue ID(s) and position number(s) (comma-separated)
• Have you experienced one or more restudies that materially changed upgrade scope or cost? If yes, summarize timing and impact Options: No restudies, One restudy, Multiple restudies, Unknown / under RTO review
• Summary of the last formal RTO/TO response about project viability (attach a short excerpt or paraphrase)
• Are there identified network upgrades in the latest study? If so, who is assigned primary responsibility for funding/constructing each (project vs. TO)? Options: No upgrades identified, Upgrades allocated to project owner, Upgrades allocated to transmission owner, Shared allocation, Unknown / under dispute

Is the Queue Quietly Killing Your Revenue?

• Roughly what percentage of your expected annual generation was curtailed or at risk due to congestion in the past 12–24 months? Options: 0%, 1–5%, 6–15%, 16–30%, 31–50%, 51%+
• Which operating conditions drive the majority of curtailment or congestion for your project? Options: Daytime energy oversupply, Evening ramp/peak, Seasonal transmission constraints, RTO market congestion events, Local substation/load pocket limits, Other
• Do you have metered output / SCADA data we can reference to quantify lost MWh or revenue? If so, what level of access is available? Options: Full dataset available, Summarized reports available, Only high-level estimates, No quantitative data available
• What operational workarounds have you used to reduce curtailment (select all that apply)? Options: Dispatch changes/redispatch, Battery storage co-location, PPA re-dispatch clauses, Curtailment-only acceptance, Flexible delivery windows, None
• How does current curtailment risk make you feel about the contract’s viability and your investors’ appetite? Options: Very concerned / at risk, Moderately concerned, Cautiously optimistic, Confident

Where the Grid’s Bottlenecks Really Hurt — mapping dependencies

• Which specific transmission elements does your project depend on for deliverability (list substations, line names, voltages and critical switchyards)
• Are there queued projects upstream or downstream whose study outcomes materially change your required upgrades? Options: No queued projects affecting us, Yes — upstream, Yes — downstream, Yes — both upstream and downstream, Unknown
• Has the RTO identified any thermal, voltage, or stability contingencies that drive the size or type of upgrades required? Options: Thermal overloads, Voltage violations, Transient/stability issues, Protection/co-ordination issues, No critical contingencies identified, Unknown
• Which contingency (N-1, N-1-1, specific outage) is currently controlling upgrade scope for your project? Please name or describe.
• What is the single most fragile grid dependency — the element that, if not solved, prevents energization? Options: Local substation capacity, Nearby transmission line capacity, Interconnection transformer size, RTO market acceptance, Right-of-way availability, Other

The Permitting Trail — where did the process stall?

• Which permitting milestones have you completed for the transmission route (select all that apply)? Options: No permitting started, Scoping / pre-application, Environmental review started (EA/EIS), Permits filed with agencies, Primary permits approved, Permits challenged / in litigation
• Which regulatory jurisdictions and lead agencies will decide siting or permit approval for the transmission route?
• Have you encountered formal public opposition, petitions, or litigation tied to siting or permits? If yes, describe scale and current status Options: No opposition, Localized public opposition, Large-scale opposition / organized groups, Active litigation, Unknown
• What environmental or cultural constraints are present on the preferred route (wetlands, endangered species, cultural sites, critical habitat)? Options: Wetlands, Endangered species habitat, Cultural / historic sites, High-density residential, Protected lands / parks, None known, Other
• Historically, how many months of schedule slip have you experienced attributable to permitting or siting issues on this project or comparable projects? Options: 0–6 months, 7–12 months, 13–24 months, 25–36 months, 36+ months, Not applicable

Who Will Block the Route — land and ROW realities

• What percent of required right-of-way (ROW) has been secured to date? Options: 0%, 1–25%, 26–50%, 51–75%, 76–99%, 100%
• How many unique landowners or parcels remain where access or easement agreements are unresolved?
• Have you faced holdouts, eminent domain proceedings, or threats that slowed acquisition? Select all that apply Options: No issues to date, Negotiation holdouts, Threats of litigation, Eminent domain initiated, Eminent domain avoided, Other
• What tactics or incentives have proven effective in your ROW negotiations (payment structure, community benefits, alternative routing)?
• Realistically, under current staffing and approach, how many months to complete remaining ROW? Options: <6 months, 6–12 months, 13–18 months, 19–24 months, 24+ months, Unknown

Money, Contracts, and What Breaks First

• What is the current funding status for development and construction (select best match)? Options: Fully funded through COD, Partially funded (need construction financing), Equity committed only, Looking for investors/partners, Dependent on utility rate recovery, Other
• Does project economics rely on regulated cost recovery or negotiated commercial arrangements to proceed? Options: Regulated rate recovery (TO/utility), Negotiated service agreements / customer funding, Merchant financing, Mix of the above, Unknown
• Which commercial contingency would most likely halt the project if it materialized? Options: Major PPA counterparty withdrawal, Failure to secure construction finance, Cost allocation dispute, Regulatory denial with conditions, Severe ROW loss
• Are there contractual COD liquidated damages, termination rights, or cure periods we should be aware of? If yes, summarize key triggers. Options: No material LDs or termination rights, Yes — monetary LDs, Yes — PPA termination rights, Yes — cure periods/extension clauses, Unknown
• How many months of schedule slippage can your financing/PPAs absorb before lenders or counterparties demand remediation? Options: 0 months (no tolerance), 1–6 months, 7–12 months, 12+ months, Unknown

Failure Modes — what would make this project stop?

• If you had to name the single most likely project failure mode today, what is it and why?
• From the following categories, select the top three failure modes that concern you most Options: Regulatory denial / permit conditions, ROW acquisition failure, RTO study re-allocation/increase, Construction cost escalation, Loss of PPA counterparty, Financing collapse, Environmental litigation, Other
• For each selected failure mode, do you have a formal mitigation plan or contingency playbook? Options: Yes — documented playbooks, Partial — informal plans, No mitigation documented, Unknown
• Who are the decision owners and escalation contacts for each gate or trigger that would force a stop-work decision? Provide names and roles or describe the governance path
• What support would you most value from a transmission developer partner to reduce the probability of these failure modes? Options: Accelerate permitting, ROW negotiation support, RTO study coordination, Bridge financing, Public relations / stakeholder outreach, All of the above, Other

If Transmission Arrived — measurable signs you’d call success

• If a new transmission solution were delivered on an accelerated path, which measurable outcome would change your view that the project is saved? (pick up to three) Options: PPA delivery met by COD, Curtailment reduced by X% (specify), Queue position advanced by Y years, RTO selection probability increased, Operational reliability metrics met, Cost allocation capped / predictable
• What non-negotiable constraints must any transmission solution meet (e.g., maximum allowable customer cost, route exclusion zones, in-service date)?
• What is your target in-service window for a transmission fix to protect the PPA (select one) Options: Within 12 months, 12–24 months, 24–36 months, 36+ months, No firm target / flexible
• Would you accept a phased energization approach (partial deliverability earlier, full deliverability later)? Options: Yes — phased acceptable, Prefer single in-service date, Depends on terms, No
• What level of visibility into studies, permitting milestones, and cost estimates would you require to be confident in progress (select all that apply) Options: Monthly program dashboard, Weekly technical calls, Access to raw study files, Quarterly executive reviews, Ad hoc escalation process

Next Steps & Where We Can Help — closing the mapping

• Which of these support areas would you prioritize from a transmission development partner right now? Options: RTO study strategy and filings, Permitting and environmental management, Right-of-way acquisition, Financing or credit support, Construction delivery capability, Stakeholder & public engagement, All of the above
• Are there documents you can share immediately to accelerate our assessment (e.g., latest SIS/FS, PPA excerpts, ROW maps)? Please list available items
• Who are the internal and external decision-makers we should include in early alignment meetings (names, roles, preferred contact method)?
• Realistically, how soon are you ready to begin a joint discovery program to model transmission options (select one) Options: Immediately, Within 2 weeks, Within 1–2 months, Later — >2 months, Unsure
• Any last critical context, red lines, or recent events we should know about that haven't been covered?

Quick Snapshot — The One Thing That Matters Today

• What single date, milestone, or deadline is currently driving your sense of urgency for this project?
• Which phrase best describes your project's current interconnection status? Options: Not submitted, Study submitted / earlier queue position, In queue (multi-year wait), Conditional approval / waiting on upgrades, Selected in RTO but awaiting FERC/regs, Other
• Where does this project sit in the interconnection queue and how confident are you in that position? Options: Top 10% of queue (confident), Mid-queue (some risk), Deep queue (high risk), Multiple applications for same point, Unclear / need to audit queue position
• Who on your team will be our primary day-to-day contact for readiness items (name, role, best contact method)?
• Which three outcomes would make you feel this stage is moving in the right direction? (select up to 3) Options: All permits on file, Land rights secured, Financing conditioned or closed, EPC contract signed, Insurance and bonds in place, Regulatory conditions cleared, Other

Who Really Feels the Heat If This Misses?

• If the project fails to start on schedule, whose professional or financial standing is most exposed? Options: Renewable developer (PPA counterparty risk), Utility resource planner / procurement team, Project lenders / investors, State energy agency / regulators, Offtaker / commercial buyer, Other
• How would your PPA counterparty likely respond if energization slips beyond the contract milestone? Options: Demand cure / extension, Seek damages, Terminate, Negotiate amendment, Unknown / need to check
• Which internal stakeholders must sign off before you can mobilize construction, and what are their biggest concerns?
• How long have timeline pressures (e.g., PPA expiry, financing covenants) been a known constraint for this project? Options: Less than 3 months, 3–6 months, 6–12 months, Over a year
• Which reputational or regulatory consequences would be most damaging if the project stalls? Options: Loss of PPA, Penalty from regulators, Investor litigation, Negative press / stakeholder backlash, Reduced likelihood of future approvals, Other

Where Is Land or Permitting Likely to Stop Us Cold?

• Which single permitting or land issue do you believe is the likeliest to require a major redesign or significant delay? Options: State siting denial, Major landowner opposition, Endangered species / habitat constraints, Cultural resources discovery, Wetlands / water crossings, Other
• What permits or siting approvals are outstanding and which agencies control them (list agency and status)?
• How many parcels still require executed land access agreements or easements, and what fraction are under active negotiation? Options: None, Few (<10%), Some (10–50%), Many (>50%), Unknown / need to audit
• What mitigation or permit-offset strategies have you already planned (e.g., habitat mitigation, route adjustments, co-location)?
• Which legal or local-government approvals have historically taken longer than expected in this geography? Options: County siting / zoning, State environmental approval, USACE / wetlands permits, Tribal consultations, Transmission corridor designation, Other

Is the Funding Line Actually There — or Just Optimism?

• If you had to fund the first construction draw tomorrow, how confident are you that cash would be available? Options: Fully confident (cash or committed loan), Confident but needs final approvals, Conditional (requires equity raise or guarantee), Not confident / funding gap exists
• What is the primary financing structure planned for construction? Options: Sponsor equity, Project finance loan, Tax equity + debt, Bridge financing, Utility rate recovery / negotiated service agreement, Other
• What lender or investor conditions must be satisfied before a draw trigger (select all that apply)? Options: All permits in hand, Land rights secured, Fixed-price EPC contract, Insurance and bonds bound, Interconnection study cleared, Other
• Are there financing covenants or PPA terms that create hard stop dates (e.g., drop-dead dates, milestones tied to funding)? If so, describe them.
• Who is the lead lender or syndicate point of contact for closing discussions (name, firm, role)?

Contracts & Construction — Who Holds the Levers?

• Which single contractual gap would cause the biggest mobilization delay: EPC execution, materials procurement, land easements, or insurance/bonds? Options: EPC contract not executed, Critical long-lead procurements unresolved, Land easements incomplete, Insurance / performance bonds not in place, Other
• What is the status of the EPC or prime construction agreement and what commercial risks remain (e.g., open scope, no-price items)?
• Which critical long‑lead items are ordered or under contract (select all that apply)? Options: Transformers, Towers/poles, Conductor, Substation equipment (breakers, relays), Foundations / piling, None ordered yet
• How will scope changes and cost escalation be managed—who has approval authority and what gates are in place?
• What inspection, QA/QC, and commissioning roles will you retain versus delegate to contractors? Options: Retain all critical inspections, Joint inspections with EPC, Delegate to EPC with acceptance gate, Third-party inspector engaged, Other

Regulatory Conditions That Can Re-write the Plan

• Which regulatory decision or condition would force a substantial route, cost, or timing change if imposed? Options: RTO cost allocation outcome, State siting conditions, FERC order with changes, Environmental mitigation conditions, Interstate routing restrictions, Other
• What regulatory filings are upcoming and who will own preparation and responses?
• Have you identified any likely protestors or intervenors and what is your engagement plan with them? Options: Yes—active engagement plan, Yes—but limited outreach so far, No identified intervenors, Unknown / need analysis
• Are there recent precedent decisions in the RTO/state that materially affect expected approval odds for your preferred rate recovery path? Options: Yes—favorable, Yes—unfavorable, Mixed, No clear precedent, Unknown
• What regulatory contingencies would you accept as part of a go decision (e.g., conditional approvals, staged filings)?

What Exactly Is the 'Start' Gate?

• What single event or combination of events will make you press the button to start construction? Options: All permits issued, Financing closed, EPC contract signed and mobilized, Land rights secured, Insurance & bonds in place, Other
• Who in your governance structure has authority to approve the start (name, title, and decision process)?
• What are the acceptance criteria and key metrics you will use at the start gate (time, cost, scope thresholds)?
• Which contingency triggers would pause mobilization even after an apparent 'start' (e.g., new regulatory order, financing withdrawal)? Options: Regulatory condition with material route impact, Major financing covenant breach, Unresolved legal injunction, Unexpected environmental finding, Significant contractor default, Other
• How much schedule slack exists between the start gate and the first construction milestone (in weeks)? Options: >24 weeks, 12–24 weeks, 4–12 weeks, <4 weeks, No slack / critical path

If We Were Celebrating Six Months After Break Ground — What Would We Celebrate?

• List the three measurable success signals you would cite six months into construction that show we're on track for the customer's goals.
• What are the reliability or performance thresholds the Utility Resource Planner will use to accept the work (e.g., availability, fault rates, RTO metrics)?
• Which documentation or deliverables must be completed for customer acceptance and eventual rate recovery? Options: As-built drawings, Commissioning reports, Environmental compliance reports, Cost and schedule audit, Operational readiness plan, Other
• How should we keep you updated during deployment (frequency and format)—and who else needs those updates? Options: Weekly written report, Biweekly executive summary, Monthly governance review, Real-time dashboard access, Ad hoc by exception, Other
• What lessons from past projects do you want explicitly avoided or applied during this build?

Quick Introductions: Who are we solving this for?

• Which project are we discussing (project name, primary county/state, MW, and PPA counterparty)?
• What is your role and primary decision authority for this project? Options: Renewable Developer – Project Lead, Renewable Developer – Commercial/Contracts, Utility Resource Planner, State Energy Agency Director, Financier / Lender, Other
• Who else on your team must be involved in technical, permitting, commercial, and financing conversations (names/roles)?
• How urgent is finding a transmission solution on a scale from ‘nice to have’ to ‘existential’ for your PPA delivery? Options: Existential – PPA will fail without it, High priority – materially reduces risk, Important – improves commercial outcomes, Monitor only – not critical now
• What single outgoing action would you like from our first meeting (e.g., initial feasibility note, data request, intro to stakeholders)? Options: Feasibility summary, Detailed data request, Intro to permitting contacts, Commercial term checklist, Schedule technical workshop, Other

If This Doesn’t Get Fixed, What Breaks First?

• Which contractual or regulatory deadline threatens to terminate or materially reduce the value of the project if deliverability isn’t secured? Options: PPA expiration/termination date, Interconnection Withdrawal Deadline, Tax/credit eligibility deadline, Financing covenant date, None immediate
• When is that date (exact or estimated), and how firm is it?
• Quantify the commercial hit if you miss that date—lost revenue, penalties, or de-rating (annual $ or % of project economics).
• How would prolonged curtailment or delayed interconnection change your willingness to proceed (e.g., walk away, renegotiate PPA, accept reduced capacity)? Options: Walk away / terminate, Renegotiate PPA terms, Proceed with reduced capacity, Delay commissioning, Other
• On an emotional level, what does the prospect of losing this PPA or project do to your team? (stress points, morale, stakeholder pressure)
• Who outside your organization (investors, lenders, public officials, communities) will publicly react if the project fails or is delayed? List and describe expected reactions.

Where Exactly Is the Project on the Grid — and What’s Blocking It?

• At what interconnection queue stage is the project right now? Options: Feasibility/Screening, System Impact Study, Facilities Study, LGIA Negotiation, Awaiting Construction/To Be Assigned, Unknown
• What is your current queue position/cluster ID and any identified network constraints noted in the study reports?
• What patterns of curtailment or congestion have you observed (months/seasonality, % of offered energy lost)? Options: Daily/seasonal curtailment, Intermittent hours only, Frequent sustained curtailment, Minimal historical curtailment, Unknown
• Which transmission elements are implicated (substation capacity, thermal limits on corridor, voltage support, stability constraints)? Options: Substation transformer limits, Thermal corridor congestion, Voltage/reactive support, Stability/short-circuit issues, Inter-area transfer limits, Other
• Have any transmission solutions been proposed in prior RTO/planning cycles for this constraint? If yes, what and when? Options: Yes — incumbents proposed, Yes — merchant/third-party proposed, No proposals previously, Unknown
• Please attach or summarize the last study (SIS/Facilities) finding that is most relevant to interconnection risk.

Who Holds the Keys — Stakeholders Who Can Say No

• Which stakeholder(s) could veto or materially change the project outcome, and what would they need to feel satisfied? Options: RTO/ISO planning authority, Host Transmission Owner, PPA Offtaker, State siting/permitting authority, Major landowner groups, Financiers/lenders, Other
• For each primary stakeholder, what are their top acceptance metrics (cost per MW, timeline to energization, environmental impacts, reliability gains)?
• How do these stakeholders typically measure reliability or economic benefit (e.g., RTO benefit-cost metric thresholds, LMP reductions, loss-of-load expectation)? Options: RTO benefit-cost ratios, LMP reduction targets, Reliability metric thresholds (SAIDI/SAIFI), PPA delivery date assurances, Other
• Who in your organization has final sign-off authority for entering into a financing commitment or assigning land/permits to a third party? Options: CEO/Board, Head of Development, CFO/Finance Committee, Legal/Contracts, Other
• Are there public-facing stakeholder sensitivities we must plan for (e.g., environmental justice communities, indigenous lands, vocal landowner groups)? Please list and describe.
• Which of these stakeholders do you believe are most open to an external developer taking an integrated delivery role, and which will resist it? Options: Open to external developer, Neutral/conditional, Likely to resist, Unknown

What Would ‘Solved’ Actually Look Like — Measurable and Convincing

• If the transmission problem were solved, what are the three measurable outcomes you would point to as proof (pick or add): Options: PPA delivery by X date, Curtailment reduction by %, RTO economic selection achieved, LMP improvement of $/MWh, Interconnection queue advancement, Regulatory approval/granted permits
• Rank those outcomes in order of importance to you.
• For your top outcome, what is the minimum acceptable target (date, %, $/MWh, or other unit)?
• How will achievement of these outcomes change your commercial position (examples: keep PPA intact, enable commercial operation, unlock liquidity)?
• Which outcomes would justify a premium cost or accelerated timeline from your perspective? Options: Guaranteed energization date, Higher probability of RTO selection, Lower long-term congestion risk, Regulatory certainty for cost recovery, Other
• Which of these proof points would you want included in a commercial commitment or financing covenant? Options: Energization milestone, Performance against reliability metrics, Penalty for missed date, Regulatory approval trigger, Other

What Boundaries Can’t We Cross — Non-Negotiables and Deal Breakers

• Which elements are non-negotiable for you (select all that would stop the project if unmet)? Options: PPA delivery date, Maximum capital exposure ($/MW), Avoidance of certain land or habitats, State approval requirement, No third-party ownership change, Other
• If you have a maximum acceptable cost allocation (per MW or $ total) please specify the value or range.
• Are there routing or siting constraints that we must respect (e.g., distance from residences, protected habitat, state scenic corridor)? Please list specifics.
• Would you accept negotiated/contractual solutions (e.g., negotiated service agreement) versus regulated rate recovery to secure project viability? Options: Prefer negotiated agreements, Prefer regulated rate recovery, Open to either, Depends on cost allocation
• How flexible are your lenders/investors on changes to schedule, route, or cost allocation once construction financing is committed? Options: Very flexible, Somewhat flexible, Not flexible, Unsure
• Are there legal, political, or commercial precedents we must avoid or align with in the region?

What’s Been Tried — Honest Review of Past Remedies

• What mitigation measures have you already pursued to reduce curtailment or congestion (select all that apply)? Options: Redispatch agreements, Battery/storage co-location, DER aggregation, Network upgrades requested from TO, Curtailment compensation, No mitigation pursued
• Which RTO or planning cycle filings have been made on this project and what were the outcomes? Options: Economic transmission proposal filed, Reliability project filed, No filings yet, Unknown
• Who has led prior efforts (internal team, incumbent TO, third-party developer) and what broke down in their approach? Options: Internal team, Incumbent TO, Third-party developer, Consortium, Other
• Were there community or political objections in prior attempts that materially impacted route or permitting outcomes? Please summarize.
• What technical or commercial evidence did opponents or regulators cite against prior proposals (cost, environmental impact, insufficient benefits)?
• What lessons from those prior attempts would you insist we apply immediately if we pursue a new transmission solution?

If We Partner — Commitments, Proof, and First Steps

• What specific commitments or guarantees would you need from a developer to let them lead a competitive RTO filing on your behalf? Options: Financing commitment, Performance milestones, Public stakeholder engagement plan, Regulatory risk sharing, Data access and confidentiality agreement
• Would you be willing to provide the developer with privileged access to studies, landowner lists, or commercial data under NDA to accelerate a solution? Options: Yes – full access, Yes – limited access, Maybe under strict conditions, No
• What commercial structures would you consider (select all that might be acceptable)? Options: Merchant developer with tolling, Negotiated service agreement, Regulated rate recovery via TO, Public-private partnership, Hybrid structure
• Who in your organization would sign a Letter of Support, financial commitment, or exclusivity agreement and on what timeline?
• If we produced a clear RTO filing package within X weeks, what internal decision timeline could you commit to for a go/no-go? Options: Immediately (within 2 weeks), Short (2–6 weeks), Moderate (6–12 weeks), Longer (>12 weeks), Unsure
• What would constitute a fair risk-sharing arrangement if schedule or permitting slippage increases cost—examples: shared cost overrun pool, cap on developer exposure, contingent payments?

Practical Next Steps and What We’ll Deliver First

• What’s the single most valuable deliverable you want from us first (technical note, commercial term sheet, stakeholder map, or rough-order cost)? Options: Technical feasibility note, Commercial term sheet, Stakeholder & permitting map, Rough-order magnitude cost estimate, Preliminary RTO strategy
• What data or documents can you share immediately to accelerate that deliverable (studies, landowner lists, PPA contract excerpt, interconnection queue filings)? Options: SIS/Facilities reports, PPA key commercial terms, Landowner contact list, Environmental reports, None available right now
• Who will be our day-to-day contact for data requests and coordination, and their preferred communication channel?
• What concerns would you have about signing a short-term data access NDA so we can run preliminary economic/reliability models? Options: Confidentiality risk, Regulatory disclosure concerns, Competitive sensitivity, No concerns
• Realistically, when could you commit to an introductory workshop with internal stakeholders and a data handoff? Options: Within 1 week, 1–3 weeks, 3–6 weeks, More than 6 weeks, Unsure