Start with Your North Star

• What single business problem prompted you to explore utility-scale storage today? Options: Capacity shortfall in IRP, Defer distribution/transmission upgrade, Firm renewables (intermittency), Replace peaking gas units, Local resilience for critical load, Regulatory/mandate compliance, Cost reduction/energy arbitrage, Other
• How big is the issue in practical terms—MW/MWh gap or $/year impact—and how long has this been affecting planning?
• What are you doing right now to manage this problem, and what has or hasn’t worked? Options: Running peaker plants, Curtailment of renewables, Temporary upgrades, Demand response, No effective solution yet, Other
• How urgent is a solution on a scale from 'must be in-service within 12 months' to 'explore over several years'? Options: Must be in-service <12 months, Prefer 12–24 months, Acceptable 2–3 years, Exploratory/no hard date
• When you think about the status quo, what feelings come up—frustration, anxiety, pragmatic acceptance, or confidence? Can you give a brief example?

If We Could Only Solve One Thing, Would It Be This?

• What’s the one outcome you would judge this project a success on—even if other benefits fall short? Options: Firm capacity delivered (MW/MWh), Guaranteed reliability/availability, LCOE / cost per MWh reduction, Deferral of T&D capital spend, Firming renewables for off-take contracts, Public safety/community acceptance, Other
• List your top three prioritized outcomes in order and why each matters to your organization right now.
• What tradeoffs are unacceptable (for example: lower reliability for higher revenue, higher degradation for lower capex)?
• Has your organization prioritized similar projects before? What decision criteria were decisive then?
• If you had to pick a single metric that would kill the deal if not met, what is it and at what threshold?

Show Me the Signals That Prove It's Working

• Which measurable success signals would convince you this project is delivering its target outcomes? Options: Guaranteed MW capacity available during peak, Percent uptime/availability, Round-trip efficiency, Annual revenue targets ($/yr), Cost savings vs. peaker ($/MWh), Deferment of planned capital spend, Emission reductions (tons CO2), Other
• For the top three signals you selected, what numeric thresholds or ranges would you accept (e.g., availability > 98%, degradation < 2%/yr)?
• Who in your organization currently owns the data for each signal (title or team), and how confident are you in its accuracy? Options: Resource Planning, Grid Operations, Finance, Facility/Asset Owner, Third-party consultant, Unknown
• How often should we report these signals to you—real-time, daily, weekly, monthly—and who needs executive summaries? Options: Real-time/dashboard, Daily, Weekly, Monthly, Quarterly
• If an acceptance metric dips below threshold, what corrective steps would you expect and who must approve them?

What Would Make Lenders and CFOs Sleep Better?

• What are the non-negotiable financing or bankability criteria that this project must meet to proceed? Options: Minimum DSCR target, Minimum project IRR, Minimum contract length, Counterparty credit rating, Performance guarantees/warranties, Completion guarantees, Other
• What minimum contract length or revenue certainty do you require (for example, 10-year capacity contract, 15-year PPA-equivalent)? Options: <5 years, 5–10 years, 10–15 years, >15 years, No fixed contract required
• Which counterparty types would be considered creditworthy for capacity or energy contracts (select all that apply)? Options: State/municipal utility, Investor-owned utility (IOU), Corporate offtaker (investment grade), Retail aggregator, ISO/RTO capacity market, Merchant exposure only
• How much merchant exposure is acceptable versus contracted revenue (e.g., 0%, 25%, 50%)? Options: 0% (fully contracted), Up to 25%, 25–50%, 50–75%, >75% merchant acceptable
• Do you require third‑party independent modeling or credit opinion to underwrite the revenue stack? If yes, what type (technical, financial, legal)? Options: No third‑party needed, Independent revenue modeling, Third‑party technical due diligence, Legal/contract review, Credit opinion from rating agency

Show Me the Worst Case — We'll Design Around It

• If prices and revenues drop by 30% next year, would you still fund construction or pause—why? Options: Proceed (we can tolerate downturn), Pause and re-evaluate, Require additional guarantees, Cancel project
• Which revenue streams must be included in base-case modeling to convince your finance team (pick all that should be modeled)? Options: Capacity markets, Energy arbitrage, Frequency regulation/ancillary services, Spinning/reserves, Demand charge management, Transmission/distro deferral payments, Capacity contracts (bilateral)
• What conservative assumptions would you insist on for price forecasts, dispatch availability, and grid curtailment risk?
• How large a revenue stress-test do you expect (e.g., 10%, 25%, 50%), and who must sign off on the stress-case? Options: 10%, 25%, 50%, More than 50%
• Have you previously walked away from projects because of revenue modeling assumptions? Tell us briefly what broke trust.

How Much Risk Can You Sleep With at Night?

• When you picture operations five years in, what operational failure keeps you up at night? Options: Thermal runaway/fire, Unexpected degradation/lost capacity, Interconnection curtailment, Inadequate O&M response, Warranty disputes, Cybersecurity/EMS failure, Other
• What absolute minimum availability or uptime metric do you require for commercial acceptance (e.g., 95%, 98%)? Options: >99%, 98–99%, 95–98%, <95%
• What warranty terms would you expect to see on battery and inverter systems to feel comfortable (select all that apply)? Options: Performance guarantee (MWh delivered), Capacity retention guarantee (% over time), Cell-level replacement warranty, 10+ year warranty, Financial remedies for underperformance, Vendor performance bonds
• Who will own ongoing operations and maintenance—your team, the developer, or a third-party—and why? Options: Host owns O&M, Developer retains O&M, Third-party O&M, Hybrid/shared model
• If we proposed an enhanced safety design (fire suppression, separation, monitoring), what gap would that need to close for you to be confident?

The People Who Will Say Yes — Tell Us About Them

• Who are the decision-makers and their roles (titles) who must be convinced for this project to move forward?
• Which stakeholders are likely to raise the toughest objections (finance, operations, safety, community, regulators)? Options: Finance, Grid Operations, Safety/Fire Marshal, Legal/Compliance, Community/Local Government, Procurement, Other
• What are the political or reputational sensitivities we should know about (e.g., project near residences, past failures, high-visibility procurement)?
• How do internal stakeholders prefer to see risk communicated—detailed technical reports, executive summaries, scenario tables, or live dashboards? Options: Technical reports, Executive summaries, Scenario/financial tables, Real-time dashboards, Workshops/briefings
• Who would be the internal champion for this project and what authority do they have to shape commercial terms or budgets?

If We Built It — When Would You Want It Online?

• What is your target commercial operation date (COD) and how firm is that target? Options: Within 6 months (firm), 6–12 months (preferred), 12–24 months (target), 2+ years (exploratory)
• What are the non-negotiable schedule milestones or external deadlines driving that COD (e.g., IRP compliance date, capacity auction, contract start)?
• Which of these items are already in place: site control, interconnection window, preliminary permitting, preliminary engineering, funding commitment? Options: Site control, Interconnection application filed, Preliminary permitting started, Preliminary engineering complete, Funding commitment in place, None of the above
• If an interconnection delay of 12 months occurred, what would you want us to do—redesign, accelerate other paths, renegotiate contracts, or pause? Options: Redesign to reduce upgrades, Accelerate procurement/long-lead, Renegotiate commercial terms, Pause and re-evaluate, Other
• What are your preferred decision points (dates or trigger events) where you need a go/no-go recommendation from us?

How We’ll Prove Value Together — Modeling & Verification

• Which inputs and scenarios do you want included in our financial and dispatch model to feel confident (historical load, high/low wholesale price, forced outage scenarios)? Options: Historical load profiles, High/low wholesale price scenarios, Forced outage scenarios, Interconnection curtailment scenarios, Battery degradation sensitivity, Regulatory/market rule changes
• Do you prefer results communicated as conservative base-case plus upside scenarios, or a probabilistic forecast with confidence intervals? Options: Conservative base-case + upside, Probabilistic forecast (confidence intervals), Both
• Would you require third-party validation of the model outputs (technical modeler, market consultant, or auditor)? If so, which type? Options: No third-party validation, Independent technical modeler, Market/revenue auditor, Financial audit for lenders
• How would you like to see model transparency—detailed assumptions workbook, executive summary, interactive dashboard, or workshop walk-through? Options: Assumptions workbook, Executive summary, Interactive dashboard, Workshop walk-through
• Who will be our primary point of contact for validating inputs and approving the final model?

• Solution Experience Kickoff — Current State & Consequence Alignment
• Scenario Validation Workshop — Customer Data‑Driven Cases
• Dispatch Logic & Revenue Proof — Live Optimization
• Safety & Site Integration Experience — Fire Mitigation and Permitting
• Solution Confirmation & Acceptance Criteria — Diagnosis → Proof → Validation

• Assign owners and timelines for permitting and third‑party verification tasks.
• Developer to prepare live model environment and initial baseline runs for the Dispatch Proof session.
• Objectives & Constraints Reminder
• Prove with live runs that the dispatch achieves the stakeholder‑agreed future state metrics for representative scenarios.
• Demonstrate which EMS constraints drive any missed targets and propose fixes or trade-offs.
• Deliver a preliminary revenue and degradation sensitivity view to quantify downside risk.
• Obtain explicit customer validation (yes/no and comments) that the dispatch proof addresses their primary outcomes.
• Developer to deliver the dispatch run outputs and detailed explanation notes for each scenario.
• Customer to confirm whether outputs meet acceptance thresholds or document gaps and required changes.
• If gaps exist, developer to propose EMS parameter changes or system-size adjustments and schedule a follow-up verification run.
• One‑Sentence Safety Concern & Consequence
• Convince the customer that the safety design directly addresses their stated safety consequence.
• Agree the list of safety deliverables and verification milestones required for acceptance.
• Introductions & Meeting Objectives
• Developer to produce a site‑specific safety schematic and a mitigation cost/timeline estimate.
• Developer to list recommended third‑party certifiers and draft scope for verification tests.
• Customer to confirm any local community or fire authority concerns that must be incorporated into the permit package.
• Recap: One‑Sentence Current State, Consequence, Future State
• Obtain explicit customer validation that the Solution Experience proves the future state or capture a prioritized gap list.
• Lock acceptance criteria that will be passed to the Solution Scope and Technical Due Diligence stages.
• Agree owners and timelines for any remaining open risks required before commercial commitment.
• Developer to produce the Solution Experience report containing model outputs, safety schematics, revenue sensitivities, and a signed validation statement.
• Customer to provide formal validation (email or signed doc) or an ordered list of required changes with owners.
• Both parties to schedule the Solution Scope kickoff with the accepted acceptance criteria and any outstanding mitigation deliverables attached.
• Agree and document a single-sentence current state that all participants recognize as accurate.
• Surface and quantify the top 2–3 consequences (cost, reliability, timeline) tied to the current state.
• Agree a single-sentence future state that the solution experience must demonstrate.
• Confirm dataset completeness or assign owners to deliver missing data before the Scenario Workshop.
• Customer to upload verified interval load, interconnection study excerpt, and recent curtailment/outage logs within 48 hours.
• Developer to produce a short consequence memo (top-line $/MW/yr and risk statement) based on provided data.
• Schedule the Scenario Validation Workshop and confirm participants who can validate model inputs.
• Recap Current & Future State (1 sentence each)
• Achieve customer sign‑off on the exact scenario set to be used in live modeling.
• Confirm modeling constraints and failure modes to ensure runs reflect reality.
• Agree the success metrics and sensitivity axes that will prove the future state.
• Identify any remaining data gaps and owners with deadlines.
• Developer to ingest approved scenario datasets and produce a scenario manifest (definitions and timestamps).
• Customer to validate any ambiguous timestamps or control mode assumptions in the manifest.
• EMS Assumptions & Rules Mapping
• Consolidated Proof Package
• One‑Sentence Current State
• Site‑Specific Safety Design Walkthrough
• Walk Through Customer Scenarios
• Acceptance Criteria Review
• Concrete Consequence Quantification
• Live Dispatch Run — Representative Peak Week
• Verify Constraints & Fail Modes
• Operational Monitoring & Response Flow
• Live Dispatch Run — High Renewables / Curtailment Case
• Live Baseline vs. Storage Case Definitions
• Data Completeness Check
• Open Risks, Mitigations & Owners
• Permitting Path & Third‑Party Verification
• Validation & Acceptance Criteria for Safety
• Agree Sensitivity Sweep & Success Metrics
• Define One‑Sentence Future State
• Revenue Stack & Sensitivity Snapshot
• Customer Validation & Next Steps
• Validation Checkpoint
• Validation Check — Force Confirmation

• Procure battery cells and modules
• Fabricate and install site civil works and foundations
• Install battery enclosures and racking systems
• Install inverters, transformers, and MV switchgear
• Install HVAC, fire suppression, and thermal controls
• Install site SCADA, EMS, and market integration APIs
• Factory acceptance testing of batteries and inverters
• Commissioning: functional, performance, and safety testing
• Medium‑voltage interconnection commissioning and relay settings
• Deploy 24/7 remote monitoring and dispatch operations
• Execute capacity and ancillary services contract settlements
• Deliver 20‑year O&M, warranty, and degradation guarantees
• Replace failed modules and manage end‑of‑life recycling

Procure battery cells and modules

• What is the target system power (MW) and energy (MWh) to be supported by procured cells/modules?
• Which battery chemistry do you prefer or require? Options: LFP (Lithium Iron Phosphate), NMC (Nickel Manganese Cobalt), NCA (Nickel Cobalt Aluminum), Other
• Do you have preferred cell or module vendors (list vendors or indicate no preference)? Options: Specific vendors (list below), No preference, Require approved-list only, Open to developer recommendations
• What are the minimum lifecycle and end-of-warranty capacity retention requirements (e.g., cycles, % retention)?
• What is the maximum acceptable lead time from purchase order to site delivery for cells/modules? Options: <12 weeks, 12-20 weeks, 20-40 weeks, >40 weeks
• Do you require vendor-backed performance, degradation guarantees, or buyback clauses? Options: Yes - full warranty guarantees, Yes - partial/conditional guarantees, No - developer/owner assumes risk

Fabricate and install site civil works and foundations

• What is the site's existing topography and access condition? Options: Flat and accessible, Sloped/graded, Requires major earthworks, Unknown - need site visit
• Approximately how much contiguous footprint is available for civil works (acres or m2)?
• Is a geotechnical report available specifying soil type and bearing capacity? Options: Yes - report available, No - geotech required, Preliminary only
• Will foundations require special measures (piling, seismic anchors, high groundwater mitigation)? Options: Yes - piling/seismic, No - shallow foundations OK, Unknown - require assessment
• Are there on-site drainage, stormwater, or environmental constraints to incorporate into civil scope? Options: Yes - specific constraints, No, Unknown - need survey
• Do you want the contractor to include site restoration, fencing, and landscaping in the scope? Options: Yes - include, No - owner to handle, Partial - specify items

Install battery enclosures and racking systems

• Which enclosure/racking approach is preferred? Options: Containerized (ISO-style), Modular prefabricated enclosures, Building-integrated racks/skids, Open rack with weather protection
• What environmental rating and site exposure must enclosures meet (IP rating, wind/snow load)? Options: Standard outdoor, High wind/dust, High snow/ice, Indoor/climate-controlled
• Do enclosures need acoustic mitigation, aesthetic cladding, or neighborhood screening? Options: Yes - acoustic and cladding, No, Maybe - depend on AHJ/community
• Is integrated thermal management (cooling/heating) required at rack/enclosure level? Options: Yes - full integration, No - passive cooling, Partial - select racks only
• Do you require on-site module unpacking, staging, and inventory management services? Options: Yes - full staging, Vendor handles delivery to site, No - owner handles
• Are there specific cabling trays, grounding, or lightning protection requirements for racks/enclosures? Options: Yes - specify standards, No, Unknown - assess during detailed design

Install inverters, transformers, and MV switchgear

• What is the interconnection voltage at the POI (point of interconnection)? Options: <1 kV (low voltage), 1–35 kV, 35–69 kV, >69 kV
• Which inverter topology is preferred or required by the plant design? Options: Central inverter, String inverter, Modular/hybrid inverters, No preference - recommend
• Are step-up transformers required on-site or will utility provide step-up? Options: On-site step-up required, Utility provides, Decision dependent on study
• Who will own/operate the medium-voltage switchgear (utility or project)? Options: Utility-owned, Project-owned (customer), Shared/conditional
• Are specific protective relay settings or vendor relay models mandated by the utility? Options: Yes - utility spec provided, No - need coordination, Partial - some settings provided
• Do you require factory witness testing and site SAT for power electronic equipment? Options: Factory witness + SAT, SAT only, Factory witness only, No formal witness testing

Install HVAC, fire suppression, and thermal controls

• Which fire suppression approach is preferred or required by the AHJ? Options: Clean agent (e.g., Novec/Halon alternatives), Water-based deluge/sprinkler, Aspirating smoke detection + suppression, Unknown - AHJ review required
• Is active HVAC required inside enclosures/rooms or is passive ventilation acceptable? Options: Active HVAC (full), Local/partial cooling, Passive ventilation only
• Are there mandated separation distances, firewalls, or setback requirements to meet local fire codes? Options: Yes - specify distances, No, Unknown - need AHJ confirmation
• Do you require 24/7 fire/smoke monitoring with auto-alarm escalation to emergency services? Options: Yes - required, No - monitoring only, Optional - owner choice
• Should thermal monitoring and cell-level temperature sensors integrate with EMS/SCADA for automated mitigation? Options: Yes - full integration, No - separate system, Partial integration
• Is redundancy (e.g., N+1) required for HVAC and suppression systems? Options: Yes - N+1 required, No - single train acceptable, Recommended but not required

Install site SCADA, EMS, and market integration APIs

• Do you have a preferred EMS/SCADA vendor or is selection required? Options: Preferred vendor specified, No preference - need recommendation, Open to integration with existing systems
• Which ISO/RTO or market integration APIs must the EMS support? Options: CAISO, PJM, ERCOT, MISO, Other/Local utility
• What telemetry granularity is required for market and operations (sub-minute, 1-5 min, 5-15 min)? Options: Sub-minute (real-time), 1-5 minutes, 5-15 minutes, 15+ minutes
• Are specific cybersecurity standards or certifications required (e.g., NIST, IEC 62443)? Options: Yes - specify standard, No, Prefer but not required
• Do you require both on-site HMI and cloud access or cloud-only remote operations? Options: On-site HMI + cloud, Cloud-only remote, On-site only
• Will the EMS need to perform multi-stream revenue stacking and automated optimization? Options: Yes - automatic multi-stream optimization required, Optional - manual/periodic optimization, No - simple dispatch rules

Factory acceptance testing of batteries and inverters

• Do you require factory acceptance tests (FAT) for batteries and inverters prior to shipment? Options: Yes - FAT required for both, Yes - partial (sample testing), No - rely on vendor QA
• Which FAT protocols must be executed (electrical, thermal, communication, cycle tests)? Options: Electrical, Thermal, Functional/communication, Cycle/accelerated testing
• Who will witness and sign off FATs (developer, owner, third-party inspector)? Options: Developer, Owner/Buyer, Independent third-party, Combination
• Do you require traceable serial numbers, detailed FAT reports, and BOM linkage for each shipped module? Options: Yes - full traceability, No - summary reports only, Partial - per-batch traceability
• Is accelerated capacity or cycle testing required on samples before shipment? Options: Yes - required, No, Conditional - for critical lots
• What remediation actions are acceptable if FAT reveals issues (repair at factory, rework on-site, reject)? Options: Repair at factory, Repair on-site after delivery, Reject shipment and replace, Escalate to vendor/insurer

Commissioning: functional, performance, and safety testing

• What commissioning acceptance criteria should be defined (e.g., availability %, MW/MWh delivered)?
• Should commissioning be staged (e.g., by battery block, inverter bank) or performed all-at-once? Options: Staged (block-by-block), All-at-once, Hybrid approach
• Do you require independent third-party commissioning agents or owner witness testing? Options: Independent third-party required, Owner witness only, Developer-led with owner review
• Which operational tests must be included (black-start, grid-following, max discharge, dynamic ramp)? Options: Black-start, Grid-following/response, Max continuous discharge, Dynamic ramp and primary frequency response
• Is witness testing by the utility, ISO/RTO, or other authority required during commissioning? Options: Yes - utility/ISO witness required, No, Maybe - dependent on interconnection agreement
• Should safety drills (fire response, containment, emergency isolation) be executed and documented as part of commissioning? Options: Yes - full drills and sign-off, No - tabletop only, Partial - AHJ-dependent

Medium‑voltage interconnection commissioning and relay settings

• Has a full interconnection study (facilities, system impact) been completed and approved? Options: Yes - full study approved, Preliminary study only, No study completed
• What is the target point-of-interconnection voltage and expected utility POI equipment? Options: 1–35 kV, 35–69 kV, >69 kV, Unknown - require study
• Has the utility provided relay setting requirements or specific relay models to be programmed? Options: Yes - full relay spec provided, No - need utility coordination, Partial info provided
• Do you require utility protection engineers to witness relay testing and commissioning? Options: Yes - witness required, No, Optional - depends on utility
• Are SCADA points, telemetry ranges, and telecontrol functions to the utility defined? Options: Yes - defined, No - need to define, Partial - need coordination
• Is fault current contribution analysis, transformer inrush, or anti-islanding testing required? Options: Yes - include in scope, No, Unknown - require engineering review

Deploy 24/7 remote monitoring and dispatch operations

• Do you want 24/7 remote monitoring and operator dispatch included in the scope? Options: Yes - full ops & dispatch, Yes - monitoring only, No - owner-operated
• What SLA for incident response and restore time do you require? Options: 15 minutes, 1 hour, 4 hours, Next business day
• Should the operator have authority to execute market bids and automated dispatch or only provide recommendations? Options: Operator executes bids, View-only with owner approval, Owner executes bids
• Do you require integrated incident management, escalation matrices, and post-incident reporting? Options: Yes - full incident management, No - alerts only, Partial - owner-defined
• Are there cybersecurity, VPN, or identity management requirements for remote access? Options: Yes - specify standard, No, Prefer but not mandatory
• Do you require developer-provided NOC staffing or third-party operations center services? Options: Developer NOC, Third-party NOC, Owner NOC

Start Here: What’s Driving This Opportunity?

• Which of these best describes the immediate trigger for exploring battery storage on this site? Options: Capacity shortfall identified in IRP, Distribution upgrade deferral opportunity, Renewable intermittency/firming need, Reliability/ resiliency requirement, Commercial/industrial load participation, Other (please describe)
• Who on your team is leading the initiative today (role or department)? Options: Utility Resource Planner, Grid Operations Director, Corporate Energy Manager, Procurement/Contracts, Facilities/Asset Owner, Other — list name/role
• At what stage is this idea right now? Options: Concept / internal discussion, Feasibility modeling underway, Preparing RFP / sourcing, Vendor selection / negotiations, Ready for financial close / FID
• What timeline would feel realistic for a decision on moving to engineering or contracting? (If uncertain, give a range.) Options: < 3 months, 3–6 months, 6–12 months, 12–24 months, > 24 months
• Who owns the essential data we’ll need to model this opportunity (load profiles, tariffs, interconnection studies)? Please list names, roles, and preferred contact emails.

If Market Prices Move, Who Eats the Pain?

• How confident are you that the revenue streams you’re counting on today (capacity, energy arbitrage, ancillary services) will still be available and stable in year 5? Options: Very confident, Somewhat confident, Unsure, Not confident at all
• Which revenue streams do you currently expect this project to rely on? (Select all that apply.) Options: Capacity market / capacity contracts, Wholesale energy arbitrage, Frequency regulation / ancillary services, Distribution deferral / non-wires alternative payments, Congestion relief / nodal congestion revenue, Retail demand charge management, Other — specify
• Tell us about a past project or example where market volatility materially changed the expected returns—what happened and how did your team respond?
• What financial sensitivity thresholds matter to your decision-makers? (Choose the most relevant metrics.) Options: NPV at -10% revenue, NPV at -20% revenue, Minimum IRR target, Payback period (years), Max allowable CAPEX uplift due to interconnection
• Who internally signs off to accept market/revenue risk if model outcomes fall short? Name the role and the risk tolerance (qualitative).
• How transparent do you want our long‑term revenue modeling to be (e.g., full model access, model outputs only, executive summary)? Options: Full model access with assumptions, Model outputs + key assumptions, Executive summary and scenario overlays, High-level financials only

Would You Be Comfortable Having a Large Battery Next to Homes or Critical Facilities?

• How concerned are you—on a scale of practical to urgent—about battery safety risks such as thermal runaway, fire spread, or chemical release at this location? Options: Not very concerned, Moderately concerned, Concerned and engaged, Urgently concerned
• Which safety and mitigation features are considered non‑negotiable for your stakeholders? (Select all that apply) Options: Water deluge / sprinkler systems, Inert gas suppression, Passive compartmentalization / firewalls, Remote/automated shutdown controls, On‑site emergency response plan integration, Third‑party fire risk certification
• Have you encountered permitting or public opposition related to battery safety in this jurisdiction before? If yes, briefly describe what blocked progress and how it was resolved (or not). Options: Yes — describe below, No — not yet
• How quickly does your operations team expect an installed system to demonstrate safe, repeatable behavior before accepting handover (months / cycles / test metrics)? Options: Initial commissioning tests only, 3 months of operation, 6 months of monitored operation, 12 months demonstration
• What local stakeholder groups (fire department, neighborhood associations, regulators) must be satisfied before permitting can proceed? Please name and note any previous relationships or points of friction.
• What would make you sleep better about safety (specific evidence, vendor certifications, escrowed warranty, on‑site demonstrations)?

Show Me the Grid: Where Is the Pain Greatest?

• If you had to put a priority pin on the grid map for where storage would create the most immediate value, where would it be and why?
• What interconnection stage is the site currently in? Options: Not in queue / site control only, Queue application submitted, Feasibility / system impact study in progress, Facilities study complete, Interconnection agreement executed
• What hosting capacity or substation constraints are you most worried about? (Select all that apply.) Options: Transformer capacity limits, Line thermal limits, Protection & relaying constraints, Metering / telemetry gaps, Distribution automation / control limits, Other — describe
• Have you modeled expected upgrade costs or timelines if certain grid reinforcements are required? If yes, what are the order‑of‑magnitude impacts? Options: No modeling yet, Preliminary estimate (low confidence), Detailed estimate available, Upgrades are show‑stoppers
• What failure modes worry you most operationally (e.g., single‑point of failure, vendor lock‑in, commissioning errors)? Please list and prioritize.
• What telemetry, control, and cyber requirements must the EMS meet to satisfy your grid operations team? Options: Real‑time telemetry (sub‑minute), Remote dispatch capability, API access to market/SCADA, Role‑based access controls, FIPS/ISO security compliance, Other — specify

What Would Success Make You Proud Of?

• If this project delivered exactly what you hoped for five years out, what three measurable outcomes would you point to with pride?
• Which of these measurable success signals are must‑haves versus nice‑to‑haves? (Select must‑haves only.) Options: Firm MW capacity available during peak, Targeted availability / uptime %, Demonstrable avoided T&D upgrade $, Achieved IRR / payback target, Ancillary service revenue realized, Reduced renewable curtailment by X%
• What minimum performance guarantee (e.g., availability %, capacity retention after X years) would make this bankable for your finance or procurement team? Options: Availability ≥ 98%, Availability ≥ 95%, Capacity retention guaranteed for 10 years, Capacity retention guaranteed for 15+ years, Custom metric — describe
• How important is developer/operator long‑term ownership and O&M (versus EPC handover) in your decision calculus? Options: Very important — prefer developer to operate long term, Somewhat important, Neutral, Prefer early handover to in‑house O&M
• Which combination of evidence would most persuade you we can deliver these outcomes? (Select up to three.) Options: Operating data from similar projects, Vendor warranty & bankability evidence, Third‑party engineering review, Live demonstration site visit, Independent risk assessment report

What Would Make Legal, Finance, or the Regulator Say No?

• What are your deal breakers—those conditions that would immediately halt progression? (Select all that apply.) Options: Unresolved interconnection costs, Insufficient warranty backing, Vendor lacking creditworthy sponsor, Unacceptable permitting setbacks / community opposition, Insurance/indemnity gaps, Regulatory barriers
• What warranty length and degradation guarantees are required by your procurement rules to consider awarding a contract? Options: 10 years, 12 years, 15 years, 20 years, Performance bond / escrow in lieu of longer warranty
• Which contract structure do you prefer for allocating technical & commercial risk? Options: Single‑point EPC + long‑term O&M with developer liability, Split EPC / O&M with vendor warranties, Turnkey build + availability guarantee, Merchant developer with performance incentives
• What financial assurances or sponsor credit metrics do you require (parent guarantee, minimum S&P rating, cash reserves)? Options: Parent company guarantee, Minimum investment grade rating, Performance bond / letter of credit, Escrowed funds for warranty claims, Other — specify
• Has your team walked away from storage deals before? If so, what specifically caused the decision and what would have changed your mind?

If We Were Partners, What’s the Smallest Win That Builds Trust?

• What is the single smallest milestone you’d need us to achieve to feel confident about proceeding (e.g., completed site feasibility, signed non‑binding term sheet)? Options: NDA & initial data share, Completed interconnection feasibility, Detailed financial model with scenarios, Governance meeting with stakeholders, Non‑binding term sheet
• What specific data or deliverables should we provide first to accelerate your internal review (select all that you want prioritized)? Options: Hourly load and generation profiles, Preliminary dispatch revenue model, Interconnection feasibility summary, Permitting pathway overview, Safety mitigation concept and fire plan
• Describe your preferred decision‑making cadence and who must be in the room at each milestone (names/roles if known).
• Which readiness items must be resolved before your team will sign a mutual commitment? (Select all that apply.) Options: Site control / lease, Interconnection agreement or defined costs, Permitting path with conditional approvals, Verified vendor warranty & bankability, Financing plan / investor interest
• Realistically, when could your organization be ready to enter mutual commitments if the milestones above are met? Options: Immediately, Within 3 months, 3–6 months, 6–12 months, Longer / need discussion
• What would be your single biggest remaining concern that we should address in our next technical or commercial session?

• Statement of Work (SOW)
• Master Development Agreement (MDA)
• Power/Capacity Sales Agreement
• EPC Agreement
• Equipment Supply Agreement (Battery Vendor)
• Warranty Assignment & Performance Guarantees
• Operations & Maintenance (O&M) Agreement
• Acceptance Test Plan & Commissioning Criteria
• Interconnection & Permitting Conditions Schedule
• Financing Commitments & Security Documents
• Insurance, Indemnity & Liability Schedule
• Data Access, Cybersecurity & Remote Control Agreement
• Change Order & Scope Management Procedure
• Termination, Cure & Exit Rights
• Mutual Readiness & Close Checklist
• Spare Parts, Long-Term Supply & End-of-Life Plan

• Success Signals & Outcomes Review
• Operational Performance & Dispatch Validation
• Warranty, Reliability & Maintenance Readiness
• Safety, Compliance & Incident Review
• Continuous Improvement & Enhancement Roadmap

• Publish updated incident log with RCA, corrective actions, owner, and verification date.
• Agree on evidence and test protocols required to support any future warranty claim.
• Produce a warranty register showing remaining coverage, claim triggers, and contact escalation path for each vendor.
• Replenish critical spares to target levels and log procurement lead times against SLAs.
• Schedule a verified capacity test (date, protocol, owner) to establish baseline for any potential claims.
• Safety Incident Log & Near-Misses
• Confirm safety systems are functioning and that any incidents have been remediated to prevent recurrence.
• Ensure regulatory obligations are tracked and any changes are assigned owners and deadlines.
• Agree on a public-facing communications plan for the facility to manage community risk perception.
• Introductions & Meeting Objectives
• Schedule joint emergency drill with local fire/rescue and document lessons learned.
• File any required regulatory notices and update the compliance calendar with owners and reminders.
• Establish Shared Communication Channel & SLAs
• Create a single source of truth for issues and enhancements with clear SLAs and owners.
• Prioritize the enhancement backlog so near-term work directly improves unmet success signals or ROI.
• Agree a regular governance cadence and reporting package to maintain accountability and transparency.
• Provision the agreed shared channel (ticket queue + collaborative board) and onboard all stakeholders with roles and SLAs.
• Produce a prioritized 90-day enhancement roadmap mapped to expected improvement in specific success signals and estimated ROI.
• Schedule recurring governance cadence (monthly ops review, quarterly executive review) and distribute invites and report templates.
• Confirm which success signals are met, partially met, or unmet with evidence.
• Decide on remediation, financial reconciliation, or acceptance to proceed to steady-state governance.
• Document action owners and timelines for any gaps that threaten bankability or contractual obligations.
• Publish a variance report showing each success signal, current value, target, delta, root-cause, and recommended remediation owner.
• If revenue or availability gaps exceed thresholds, trigger commercial remediation workflow and notify finance and sponsors.
• Update the shared success dashboard and schedule follow-up review in X weeks (per remediation timeline).
• Data Integrity & Telemetry Sources
• Prove with telemetry that EMS behavior produces the future state outcomes agreed with the customer.
• Identify specific, testable optimization opportunities to increase revenue or reliability without increasing risk.
• Agree on the data improvements or additional instrumentation required for ongoing verification.
• Deliver a per-episode forensic report linking EMS decisions to financial outcome and highlight 3 immediate tuning experiments.
• Implement additional telemetry or data feeds identified as gaps and schedule re-validation after data capture.
• Schedule an A/B optimization window (dates, owner, success metric) to test proposed EMS tweaks.
• Warranty Status & Claims Triggers
• Ensure warranty coverage and vendor backing are sufficient to remediate observed degradation or failures.
• Validate that O&M processes and spares strategy minimize downtime and protect contracted capacity.
• Recap of Agreed Success Signals
• Scenario Walk-through (Proof Episodes)
• Backlog Triage & Prioritization Framework
• Degradation & Reliability Trend Review
• Fire-Safety System Performance
• Maintenance Events, Root Causes, and MTTR
• Roadmap & Release Cadence
• Revenue Stack Performance by Stream
• Regulatory & Permitting Updates
• KPI Dashboard Review
• Spare Parts, Vendor SLAs & Financial Recourse
• Financial Reconciliation vs Bankability Thresholds
• Governance, Metrics & Cadence
• Dispatch Edge Cases & Optimization Opportunities
• Emergency Response & Community Liaison
• Stakeholder Feedback & Decision Points
• Preventive Actions & Training
• Acceptance & Verification Tests for Future Claims