Quick hello: What's brought you to this conversation today?

• Tell us in one sentence what pushed you to explore grid-integrated charging right now.
• How long have you been tracking elevated demand charges or responding to a DR solicitation? Options: Weeks, Months, 1-2 years, Over 2 years, Unsure
• Who first noticed the issue (role or team) and what happened when they did?
• On a practical timeline, how urgently do you feel this needs to be resolved? Options: Critical — within 3 months, High — 3–6 months, Medium — 6–12 months, Low — 12+ months
• When you think about this problem, what emotion comes up first (e.g., anxiety, frustration, opportunity)? Options: Anxiety, Frustration, Excitement/opportunity, Curiosity, Other

Who's steering the ship (and who needs convincing)?

• If this project stalls, whose day-to-day job will feel the biggest impact?
• Which of these stakeholder roles are involved in the decision (select all that apply)? Options: Fleet Energy Manager, Head of Fleet Operations, CFO / Finance, Facilities / Property Manager, Utility Relations / Regulatory, Grid Planning / Distribution Engineer, Procurement, IT / Cybersecurity, EV Program Manager, Other
• Who will have final sign-off on commercial terms or capital spend? Options: CFO / Finance, Procurement, Head of Fleet Ops, Facilities / Property Manager, Other
• Which stakeholder(s) are most likely to push back on bidirectional cycling due to battery warranty or degradation concerns? Options: Fleet Manager, Vehicle OEM liaison, Finance, Maintenance/Operations, Legal/Contracts, Other
• Please provide the primary project contact (name, role, email) for day-to-day coordination.

If we keep doing what we’re doing, what breaks next?

• Describe the worst recent incident that came from unmanaged charging (impact, date, consequence).
• By approximately what percentage have your peak demand costs grown since EV charging began at scale? Options: 0–10%, 10–30%, 30–50%, 50%+, Unsure
• Do you currently have an estimate for a utility service upgrade or transformer replacement if load growth continues unchecked? Options: Yes — <$50k, Yes — $50k–$200k, Yes — >$200k, No estimate yet, Not applicable
• How often have you received warnings or constraints from the utility about feeder/transformer capacity? Options: Never, Occasionally, Monthly, Weekly, Unsure
• What would happen operationally if you had to defer charging for 1–3 hours during a peak without alternative capacity?

What would success actually feel and look like here?

• If this project exceeded expectations, what unexpected wins would you celebrate six months after deployment?
• Which single outcome is most important for you to achieve with a grid-integrated charging platform? Options: Demand charge reduction, DR / grid services revenue, Avoided infrastructure upgrade, Uninterrupted fleet availability, Improved reliability / outage resilience, Data visibility and reporting, Emissions reduction, Other
• What specific, measurable target would represent success (e.g., % demand reduction or $ DR revenue per year)?
• What daily or monthly battery cycling limits would you consider acceptable for V2G participation? Options: No V2G (zero export), <=5% DoD daily, 5–15% DoD daily, 15–30% DoD daily, Unsure / need guidance
• Who on your team will be responsible for verifying that the project met the success metrics? Options: Fleet Manager, Finance, Facilities, Third-party M&V, Utility, Other

Show me what’s actually plugged in and available today

• If some chargers or vehicles can’t integrate with our stack, how constrained would that leave your operations?
• Please list charger makes/models on site and approximate counts (e.g., 20x VendorA OCPP 1.6).
• Which charging and EV protocols are present on site (select all that apply)? Options: OCPP 1.6, OCPP 2.0.1, ISO 15118, Proprietary vendor API, Modbus/other, Unknown
• Do your vehicles officially support bidirectional charging today? Options: All vehicles support V2G, Some vehicles support V2G, None support V2G, Unknown
• Which of these best describes your meter and site topology? Options: Single site utility meter, Multiple meters with submetering, Behind-the-meter generation present, Customer-owned transformer with limits, Unsure / need site assessment
• What historical electrical load data is available to share (format and granularity)? Options: 15-minute AMI data, Hourly meter data, Only monthly bills, No load data available, Other
• Who manages interconnection and meter ownership (customer, landlord, utility, third-party)? Options: Customer / building owner, Landlord, Utility, Third-party owner/operator

How real is the DR and revenue opportunity for your team?

• If DR revenue disappeared tomorrow, would the business case still stand — why or why not?
• Are you currently enrolled in any utility DR / grid services or time-of-use programs? Options: Yes — actively enrolled, Applied / enrollment pending, Exploring but not applied, Not eligible / unsure
• What annual DR revenue would you need to justify this investment? Options: <$10k, $10k–$50k, $50k–$200k, >$200k, Unsure
• Do you have records of past DR dispatch frequency, duration, and payments? Options: Detailed logs available, Some records available, No records available, Unsure
• Who will own program enrollment and incentive paperwork (internal team or third-party)? Options: Internal energy team, Facilities, Third-party consultant, Vendor to manage, Other
• Which modeling approach do you prefer for revenue forecasts? Options: Optimistic (upper-bound), Balanced (likely), Conservative (stress-tested)

What keeps you awake at night about moving forward?

• Which single scenario would make you pause the project (warranty claim, incentive change, failed interconnection, operational disruption)?
• Which of these risk areas concern you most right now (select all that apply)? Options: Utility program rule changes, Battery degradation / warranty risk, Interconnection delays, Hardware or vehicle firmware incompatibility, Operational disruption to fleet service, Revenue overestimation
• Have you discussed V2G impacts with vehicle OEMs or maintenance teams regarding warranty and lifecycle? Options: Yes — documented approval, Yes — informal conversation, No — planned, No — not planned
• Have you performed or requested a thermal/aging model to quantify battery degradation under projected cycling? Options: Yes — detailed model, Preliminary estimate only, No
• What specific mitigation (insurance, caps, guaranteed performance, fallback modes) would make you comfortable proceeding?

If we agreed to move forward today, what would success look like at each milestone?

• If we set a go-date now, what's the realistic window from start to first DR revenue for your team? Options: <3 months, 3–6 months, 6–9 months, 9–12+ months
• Which internal approvals must clear before any field work begins (select all that apply)? Options: Budget approval / CAPEX, Procurement, Site access / landlord sign-off, Utility interconnection approval, Safety / permits, IT / cybersecurity sign-off
• Who on your side will own integrations (meter data feeds, DERMS, fleet management) during deployment? Options: Energy / Grid engineer, Fleet IT, Facilities, Third-party integrator, Vendor-managed
• What meeting cadence and decision checkpoints do you prefer during discovery and deployment? Options: Weekly, Biweekly, Monthly, As needed / ad-hoc
• What would you need from us next week to keep momentum (data requests, executive briefing, pilot scope)?

How will we know we've won — your acceptance and verification needs

• If I handed you an acceptance checklist today, what items would absolutely have to be checked before you sign off?
• Select the acceptance criteria that must be satisfied (select all that apply). Options: Measured demand reduction hit target, DR event response within required time, Battery degradation within agreed limit, No impact to scheduled vehicle dispatch, Interconnection and utility approval received, Metering / data feeds validated, Proof of revenue for defined period
• What verification timeframe do you require to declare success after commissioning? Options: 30 days, 90 days, 6 months, Other
• Do you require third-party M&V or are internal analytics sufficient? Options: Third-party M&V required, Internal verification sufficient, Open to either
• Who will be the final signatory on the acceptance certificate? Options: Fleet Manager, Finance / CFO, Facilities Manager, Third-party verifier, Other

Start Here — a quick snapshot of this site

• Give a concise description of this site (site name, address or feeder area, facility type such as depot/garage/yard, and any immediate context we should know).
• How many total parking stalls and how many are currently used for EV charging? Options: 1–10, 11–25, 26–50, 51–100, 101–250, 251–500, 500+
• Tell us about the fleet that charges here (approx. number of vehicles, vehicle classes, and notable powertrain types).
• Which roles are directly responsible for day-to-day charging operations at this site? Options: Fleet Energy Manager, Facility Manager, Maintenance Supervisor, Third‑party operator, Utility contact, Other
• Has the size or usage pattern of the fleet changed in the last 12 months? If yes, briefly describe what changed and why. Options: No change, Moderate growth (10–50%), Rapid growth (50%+), Seasonal variation only, Fleet downsized, Other

What’s Actually Happening at Peak?

• When you look at your electric bill or meter data, how often do you see a single EV‑related event push your site to a new monthly demand peak? Options: Almost every month, Several times a year, Occasionally (1–2x/year), Rarely, Never / Unsure
• How much higher is your typical monthly demand charge spend today compared with before significant EV charging began (estimate % or $)? Options: <10%, 10–30%, 30–50%, 50–100%, 100%+, Unsure
• What time(s) of day do your highest 15‑ or 30‑minute demand intervals tend to occur? Please list typical hours and any days of the week that matter. Options: Midnight–6am, 6am–10am, 10am–2pm, 2pm–6pm, 6pm–10pm, 10pm–Midnight, Weekday only, Weekend spikes
• Describe a recent incident when charging behavior created a costly peak or service disruption — what happened, and what was the operational impact?
• Have you tracked whether peaks are caused by clustered vehicle arrivals, simultaneous plug‑ins, charger faults, or something else? Options: Clustered arrivals, Simultaneous top‑ups, Charger hardware fault, Vehicle behavior (drivers), Other, Not tracked / Unsure

Could Your Electrical System Survive Scaling to 10x?

• If you added the next tranche of chargers (your planned growth), what is the most realistic single technical barrier that would force a utility service upgrade? Options: Main service capacity, Transformer rating, Metering/topology limits, Feeder overload risk, Utility interconnection rules, Other
• What is your site’s service entrance size and main breaker rating (or closest estimate)? Options: <200A, 200–600A, 601–1200A, 1201–2000A, >2000A, Unsure / need one‑line
• How many separate revenue meters or meter points serve the charging area (single meter, submetered stalls, per building, etc.)? Options: Single meter, 1 submeter + main, Multiple submeters (>1), Per‑stall metering, Unsure
• Do you have a recent electrical one‑line diagram and transformer/spec data available for review? Options: Yes — available, Yes — will request, No — can provide site photos, No / not available
• Are there other on‑site distributed energy resources (solar, batteries, CHP) or large flexible loads that interact with the chargers today? Options: Battery storage, Solar PV, Onsite generation (diesel/CHP), Large HVAC or industrial loads, None, Unsure

Who Pays the Bills—and Who Panics When They Spike?

• If demand charges rose by 30–50% next month because of EV charging, who in your organization would feel the operational pressure most acutely? Options: CFO/Finance, Fleet Director, Facility Manager, Operations/Route Planner, Utility Account Manager, Other
• Which utility rate schedule currently applies to the charging meter(s)? (If you don’t know, select 'Unsure'.) Options: General commercial/GS‑TOU, Demand‑ratchet / TOU demand, EV‑specific tariff, N/A - aggregated metering, Unsure
• What is the cadence and granularity of the billing meter data you can access (for example, 15‑minute AMI, hourly, monthly only)? Options: 15‑minute AMI, 30‑minute, Hourly, Daily/Monthly only, Third‑party metering, Unsure
• Roughly how much do demand charges contribute to your average monthly bill for the charging meter(s)? Options: <10%, 10–25%, 25–50%, 50–75%, >75%, Unsure
• Has your site been approached for or participated in any utility demand response (DR) or capacity programs in the last 24 months? If yes, which and what was the outcome? Options: Yes — enrolled, Yes — explored, not enrolled, No — invited but declined, No — never approached, Unsure

Where Do Things Break—and How Bad Is It When They Do?

• When charging reliability fails, is the most severe consequence operational (missed routes), financial (penalties/bills), or reputational (public service impact)? Options: Operational, Financial, Reputational, All three, Other
• Which failure modes occur most often at this site (select all that apply)? Options: Charger hardware fault, Network/communications outage, Grid service interruption / breaker trips, Vehicle‑charger compatibility issues, Metering inaccuracies, Other
• How frequently do these failures occur and what’s a typical time‑to‑repair or mitigation? Options: Daily, Weekly, Monthly, Quarterly, Rarely (yearly), Unsure
• Do you have formal uptime or response SLAs for chargers and charging services? If yes, what are the targets? Options: 99.9%+, 99%–99.9%, 95%–99%, No formal SLA, Unsure
• When a charger or meter fails, what sequence of teams or vendors get involved? (i.e., in‑house tech → third‑party vendor → utility → OEM)

What Would You Be Willing to Trade for Reliability or Revenue?

• If enabling vehicle‑to‑grid or deeper dispatching could materially reduce your demand charges, what operational constraint would you find unacceptable to change? Options: Reducing available SOC at departure, Allowing V2G export from certain vehicles, Changing charging windows, Adding third‑party control, None — open to tradeoffs, Other
• What minimum state‑of‑charge (SOC) must be guaranteed at scheduled departure for routed vehicles (pick a single typical requirement)? Options: 100% or full charge, 90%, 80%, 70%, Depends on route, Unsure
• How many vehicles must be reserved from any dispatch or export event to guarantee operations on an average day? Options: None (full flexibility), 1–5, 6–20, 21–50, 50+, Unsure
• What level of battery cycling/throughput do you consider acceptable per vehicle per year from a warranty/degradation perspective? Options: Minimal (reserve for emergency only), Low (under 100 cycles equivalent), Moderate (100–300 cycles), High (300+ cycles), Unsure / need OEM guidance
• Would you prefer a solution that prioritizes guaranteed SOC by time, revenue maximization, or a defined hybrid policy (explain your preference briefly)? Options: Guarantee SOC by time, Maximize revenue from DR/V2G, Hybrid — specify rules, Unsure

Data & Integration Reality Check — are we ready to connect?

• If we asked your team to provide live meter and charger telemetry for a 30‑day test window, how ready would you be to share it? Options: Ready now — APIs/credentials available, Can prepare within 2 weeks, Need 2–8 weeks, Longer than 8 weeks, Not able / policy restricts
• What communications protocols and systems support your chargers/meters today (select all that apply)? Options: OCPP 1.6/2.0, Modbus/RTU/TCP, SunSpec, Proprietary OEM API, AMI/utility API, No digital telemetry, Other
• Which fleet management, telematics, or energy platforms must we integrate with for scheduling or driver assignments? Options: Geotab, Samsara, Fleetio, Custom/ERP, We have none, Other
• Do you have IT/security or vendor onboarding requirements (certs, pen tests, VPN) that could slow integration? If yes, note the top blockers. Options: Yes — security approvals required, Yes — procurement/vendor onboarding, No major blockers, Unsure
• Are there upcoming firmware updates or vehicle OEM firmware changes planned in the next 6 months that we should know about? Options: Yes — scheduled, Possible/unscheduled, No, Unsure

If This Fails, What’s the Worst That Happens — and What’s an Acceptable Next Step?

• What is the single worst operational or financial outcome you fear if charging remains unmanaged over the next 12–24 months? Options: Mandatory utility service upgrade cost, Severe route disruptions, Loss of revenue from service delays, Regulatory/permit denial, Significant battery warranty claims, Other
• What is your target timeframe to decide on a managed/grid‑integrated charging approach (choose the closest option)? Options: Immediately / within 30 days, Within 2–3 months, 3–6 months, 6–12 months, No timeline / exploratory
• Who ultimately signs off on capex or program enrollment for this site, and who are the internal blockers we should engage early?
• What would you consider a successful small‑scale pilot at this site (define 2–3 measurable outcomes we must achieve)?
• If we proposed a next step (metering study, short pilot, or financial model), which of these would you prefer to start with? Options: 30‑day metering + load profile analysis, Financial model using existing bills, Small pilot on 5–10 chargers, Utility program pre‑qualification, Other

Quick Check: Can We Start Field Work?

• What earliest date window would you prefer for on-site field work to begin? Options: Within 2 weeks, 2–4 weeks, 1–3 months, 3–6 months, TBD
• Who should our field team call or badge in with on arrival at the site? Please provide name, role, and best phone/email.
• Are there site access constraints we should know about (security escort, limited hours, PPE requirements)? Options: 24/7 access, Business hours only, Appointment required, Security escort required, Special PPE required, Other
• Is any concurrent construction, electrical work, or scheduled outage planned during the expected deployment window? Options: Yes — construction/outage scheduled, Yes — possible but not scheduled, No known work, Unsure

Are We Accidentally Betting on Hope?

• Which parts of this deployment are we assuming will 'just work' without verification?
• Which of these integrations do you currently believe are already available and reachable for testing? Options: Site utility meter (interval data), Building EMS/SCADA, Charger telemetry API, Vehicle telematics/SOC feed, DERMS endpoint, None of the above
• For each integration you selected above, can you point to the concrete evidence (API docs, test endpoint URL, contact with IT) that it’s ready?
• What recent surprises in similar projects have forced last-minute rework or schedule slips?

Who Actually Owns Each Piece of This Puzzle?

• Do you have named owners for these critical items: utility interconnection, meter owner, IT/security, fleet operations, and on-site facilities? Options: All owners named, Some owners named, Owners unclear, No owners assigned
• Please list the person and contact for the owner of: utility interconnection (company, name, phone/email).
• Who will be the day‑to‑day owner for coordinating firmware updates and commissioning tests on-site? Options: Fleet operations, Site facilities, IT/OT team, 3rd-party integrator, We need to assign
• If an approval or test fails, who has the authority to sign off on a corrective action and what is the escalation path?

Can We Trust the Data We'll Be Using?

• How confident are you that existing meter and charger telemetry accurately reflect baseline load and will be available for real‑time control? Options: Very confident (validated feeds), Somewhat confident (partial feeds), Low confidence (limited or poor-quality data), Not confident / unknown
• Which historical and live data feeds are available today? Select all that apply. Options: 1‑minute interval meter data, 5‑15 minute interval meter data, Hourly meter summaries, Charger session logs (per-plug), Charger power telemetry (real-time), Vehicle SOC/telemetry, None
• For the meter data you have, what is the typical latency and retention (e.g., 15min latency / 12 months retention)?
• Have you seen data quality problems (gaps, timezone shifts, mis-labeled meters) in historical files we should plan for? Options: No problems, Occasional gaps or errors, Frequent issues, Unknown—haven't reviewed
• Would you be able to provide a recent sample (CSV or API test token) for our data engineers to validate before deployment? Options: Yes — CSV available, Yes — API token available, No — need assistance to extract, Unsure

What If a Vehicle Vendor Changes the Rules?

• If a vehicle OEM issues a firmware update that affects bidirectional charging mid‑deployment, how comfortable are you freezing vehicle firmware to preserve commissioning results? Options: Comfortable freezing firmware, Prefer controlled updates only, Not comfortable — fleet policy prohibits freezing, Unsure / need to check
• How many distinct vehicle makes/models and firmware families are in the fleet at this site? Options: 1–2, 3–5, 6–10, More than 10, Unsure
• Do you have direct contacts at the vehicle OEMs or up‑fitter who can support testing and firmware coordination if needed? Options: Yes — named contacts, Yes — OEM helpdesk only, No — we rely on dealers, Unsure
• Are there warranty or fleet policies limiting allowable depth or frequency of bidirectional cycles we must observe during commissioning? Options: Yes — strict limits, Yes — guidelines exist, No formal limits, Unsure
• If vehicle firmware variability prevents a test, what temporary operational mode would you accept to preserve DR enrollment or avoid utility upgrade? Options: Unidirectional smart charge, Time-of-use scheduling only, Reduced power cap per charger, Temporary manual control, Other

Is the Utility on Our Side — Really?

• Have we validated the utility’s current interconnection and DR program rules against our project assumptions within the last 30 days? Options: Yes — fully validated, Partially validated, No — relying on older info, Unknown
• Which utility program(s) and tariff(s) will this site rely on for demand response and demand charge reduction?
• What is the current status of the interconnection application and expected approval date? Options: Approved, Pending — submitted, Not submitted, Under review with questions, Unsure
• Will the utility require meter replacement, reprogramming, or a revenue-grade CT install prior to enrollment? Options: Meter replacement required, Meter reprogramming required, CT/install required, No changes required, Unsure
• Are there fees or deposits the utility charges that could impact the deployment budget or schedule? Options: Yes — known fees, Possible fees — unknown amount, No fees expected, Unsure

How Will We Verify Success On Site?

• What concrete, testable acceptance criteria must we achieve during commissioning for you to consider deployment successful?
• Which of these commissioning tests do you require as formal pass/fail criteria? Options: Load modulation (kW change), DR signal latency & response, V2G export validation, Meter reconciliation (energy & demand), Battery degradation monitoring baseline
• What minimum DR response latency and duration would you expect (e.g., respond within X seconds and sustain for Y minutes)?
• What are acceptable thresholds for variance between our measured savings and your meter/metered bill reconciliation? Options: Within 2%, Within 5%, Within 10%, TBD / negotiate
• Who will sign final acceptance after commissioning (name, role), and what documentation do they require?

If Things Slip, What’s Our Backup Plan?

• If critical approvals or integrations delay more than two weeks, which temporary operational strategy should we default to preserve revenue or avoid upgrades? Options: Schedule-based charging, Power capping of chargers, Staggered start times, Manual operator control, Pause V2G and run unidirectional only
• Do you have an operational priority list for charging vs. mission needs (e.g., emergency vehicles first, then route vehicles, then others)? Options: Yes — formal priority list, Informal priority guidance, No priorities defined, Unsure
• What communications cadence and channels do you prefer for schedule slips and technical blockers (daily standup, weekly summary, Slack/email)? Options: Daily standup, Twice weekly check-in, Weekly summary, Ad-hoc as needed, Slack/Teams channel, Email
• What budget or resource flex is available to accelerate stuck items (expedited interconnection review, contractor overtime, temporary meters)? Options: Contingency funds available, Limited flex with approval, No contingency available, Unsure

Next Small Steps & Owner Commitments

• Based on this readiness check, which three actions should we prioritize in the next 7 days to keep the schedule intact?
• Please confirm the single point of contact we should use for daily coordination and their preferred method (name, role, phone/email, preferred channel).
• Which of the following best describes overall deployment readiness today? Options: Green — ready to proceed, Amber — minor gaps to close, Red — major gaps or approvals missing, Unsure
• When would you like a readiness re-check meeting with our team (pick one)? Options: Within 48 hours, In one week, In two weeks, When specific blockers are cleared, TBD

Let’s Start With Who You Are and What You Manage

• Which role best describes your primary responsibility for EV charging at this site? Options: Fleet energy manager, Facilities manager, Utility/grid planner, Operations director, CFO / finance, Third‑party EV operator, Site electrical engineer, Other
• How many vehicles and chargers do you currently operate, and how many do you expect in 12 months?
• Which charger models, EV makes, and charger vendors are currently deployed or planned at this site? Options: ABB, ChargePoint, Delta, FLO/Francisco, Nuvve, Tesla, Wallbox, Other
• How would you describe the primary business driver behind managing this fleet’s energy (cost containment, reliability, revenue from DR, regulatory/compliance, sustainability, other)? Options: Cost containment (lower demand charges), Avoiding utility upgrades, DR/ancillary revenue, Grid reliability, Sustainability/ESG goals, Regulatory compliance, Other
• What does this responsibility feel like day‑to‑day—calm and predictable, occasionally stressful, or consistently reactive? Options: Calm & predictable, Occasionally stressful, Consistently reactive, Depends on season/repairs

What Keeps You Up at Night About Scaling Charging?

• When you imagine growing from tens to hundreds of vehicles, how confident are you that your current approach won’t trigger a costly utility service upgrade? Options: Very confident, Somewhat confident, Unsure, Not confident at all
• Have you had any recent billing surprises, transformer overload warnings, or interconnection holdbacks from the utility? Describe the most recent example. Options: Yes — billing spike, Yes — transformer/feeder concern, Yes — interconnection delay, No
• How often do unmanaged charging patterns cause operational friction (missed dispatch, vehicle unavailable, or schedule conflicts)? Options: Daily, Weekly, Monthly, Rarely, Never
• Who at your organization feels this issue most acutely (operations, finance, maintenance, sustainability)? Tell us how it affects them. Options: Operations, Finance, Maintenance, Sustainability, Executive leadership, Other
• How long has this been a growing concern and what triggered it (fleet growth, new rate, utility program solicitations)? Options: <6 months, 6–12 months, 1–2 years, 2+ years

If We Could Remove One Big Risk, What Would It Unlock?

• Imagine a scenario with zero unexpected demand charges and steady DR revenue — what immediate decisions would that enable for your fleet?
• What percentage reduction in demand charges would make this project a clear win for you? Options: <10%, 10–20%, 20–30%, 30–50%, >50%
• What minimum monthly DR revenue or annual uplift do you need to justify investment (either dollar amount or % of operating expense)?
• Which operational KPIs would prove success within the first 12 months (examples: peak kW reduction, % of charging completed by dispatch time, DR event pass rate)? Options: Peak kW reduction, Percent charging completed by deadline, DR event response rate, Avoided upgrade capex, Reduced unplanned downtime, Other
• How emotionally important is predictability versus maximizing short‑term revenue? (Which matters more to stakeholders?) Options: Predictability > revenue, Revenue > predictability, Both equally, Undecided

What Trade‑Offs Are You Willing to Make?

• Would you accept modest additional battery cycling if it significantly reduces demand charges and avoids a service upgrade? Options: Yes — within clear limits, Maybe — need quantification, No — battery warranty risk too high, Unsure
• What is the maximum incremental battery cycle count or degradation (%) you consider acceptable over 3 years? Options: <2% degradation, 2–5% degradation, 5–10% degradation, No additional degradation acceptable, Unsure — need vendor input
• Are there vehicle manufacturer warranty terms or procurement clauses that prohibit bidirectional energy export or specific cycle depths? Options: Yes — strict restrictions, Yes — conditional/negotiable, No known restrictions, Unsure
• Which internal stakeholders must sign off on battery cycling or warranty trade‑offs (operations, fleet OEM, legal, procurement, finance)? Options: Operations, Fleet OEM contact, Legal, Procurement, Finance, Executive sponsor, Other
• If DR dispatch frequency increased unexpectedly, how comfortable would you be with automatic additional cycles versus manual overrides? Options: Comfortable with automated controls, Prefer manual approval per event, Hybrid rules-based approach, Not comfortable

Who Needs to Connect to Whom — and What Data Matters?

• If a single missing data feed could block project approval, which would it be (meter interval data, utility tariffs, DERMS feed, vehicle SOC/telemetry)? Options: Meter interval data, Utility tariffs/rate details, Utility/DERMS dispatch signals, Vehicle SOC/telemetry, Charger OCPP telemetry, Other
• Which external systems must we integrate with for success (select all that apply)? Options: Utility DERMS/DR portal, Site meter (interval), Fleet management/telematics, Building EMS/BMS, Third‑party charging network, OCPP gateway, Other
• What meter and telemetry feeds do you already have access to (interval granularity: 1s/15s/1min/5min/15min/30min/60min)? Options: 1s, 15s, 1min, 5min, 15min, 30min, 60min, No interval data available
• Who will own credentials and API access for integrations, and who is the day‑to‑day technical contact?
• Are there network segmentation, firewall, or cybersecurity policies we must plan around for remote control and telemetry? Options: Yes — strict policies, Yes — manageable with IT support, No special policies, Unsure

How Do You Evaluate the Money Side — Realistically?

• If our model shows net savings but DR revenue is volatile, would you prioritize guaranteed capex avoidance or short‑term revenue? Options: Guaranteed capex avoidance, Short‑term revenue, Balance both equally, Need to see numbers
• What is the minimum annual net financial benefit (savings + DR revenue − costs) you need to greenlight a rollout?
• How do you currently value avoided utility upgrades or extended transformer life in your financial model? Options: Capex avoidance line item, Included in TCO, Not currently modeled, Unsure
• Do you require conservative 'stress test' modeling assumptions (e.g., 30% lower DR call frequency) as part of approval? Options: Yes — must stress test, Optional but preferred, No — baseline is fine, Unsure
• Are incentives, grants, or rate changes tied to your decision window that we should include in the financial case? Options: Yes — list available, Maybe — under review, No

Timing, Milestones, and What’s Non‑Negotiable

• If interconnection or utility approval stretches beyond your fleet expansion date, will you delay expansion, accept partial rollout, or cancel the project? Options: Delay expansion, Accept partial rollout, Cancel project, Decide case‑by‑case
• What are the absolute hard dates or windows (procurement cycles, grant deadlines, rate changes) we must hit?
• How long a pilot would you require before committing to site‑wide deployment (options in weeks/months)? Options: 2–4 weeks, 1–3 months, 3–6 months, No pilot required
• Who will coordinate on your side for installations, firmware updates, and scheduling commissioning tests? Options: Facilities/maintenance, IT, Fleet operations, Third‑party integrator, Other
• What timeline do you consider acceptable for end‑to‑end adoption (enrollment, hardware install, interconnection, commissioning)? Options: <3 months, 3–6 months, 6–9 months, >9 months

What Proof Will Make You Confident This Works?

• If the system can’t reliably respond to DR dispatch or modulate load in a repeatable way, would you accept it as 'working'? Options: No — must pass all tests, Yes — if critical KPIs met, Maybe — with remediation plan, Unsure
• Which commissioning tests are non‑negotiable for acceptance (choose all that apply)? Options: Load modulation tests, Utility DR signal response, V2G export validation, Battery degradation monitoring, Third‑party metering verification, Schedule compliance tests
• For each selected test, what pass/fail criteria or thresholds must be met (e.g., % of events successfully executed, allowable response time)?
• Who on your side will witness or certify commissioning and who signs off on acceptance? Options: Site operations lead, Energy/facilities manager, Third‑party verifier, Utility representative, Executive sponsor, Other
• If a single commissioning metric fails, what remediation path would you accept (fix & retest, partial acceptance with penalties, project pause)? Options: Fix & retest, Partial acceptance with remediation plan, Project pause until fixed, Cancel project

Decision Rhythm — Who Signs Off and How Do We Keep Momentum?

• Even with a clear savings model, who beyond you has veto power and why might they say no?
• Please list the decision roles, their expected approval artifacts, and typical review cycles (legal, procurement, finance, operations).
• What contractual or procurement constraints should we be aware of (preferred vendor clauses, insurance, SLAs, indemnities)?
• Would a defined pilot with commercial guardrails (scope, duration, acceptance criteria) make approvals easier? Options: Yes — pilot required, Yes — pilot preferred but not required, No — skip pilot, Unsure
• What would be a clear, small first step you’d be willing to take after this discovery conversation? Options: Schedule modeling session, Approve site audit, Greenlight pilot proposal, Request internal review, Other