Quick snapshot: pad identity, basin, and timeline

• Tell me your pad identifier and which basin the pad sits in
• Which of these best describes how soon you need additional compression to avoid production loss Options: Within 7 days, Within 14 days, Within 30 days, Within 60 days, No fixed deadline, planning only
• If the timeline above slips by two weeks, what downstream consequence happens first Options: Flaring begins, Wells must be shut in, Revenue materially drops, Temporary throttling of wells, No immediate consequence
• Provide the best contact for day-of-site coordination, name and role

Where production and pressure are really sitting

• When peak throughput arrives, what wellhead pressure range do your wells deliver to the gathering system Options: < 25 psig, 25–50 psig, 50–150 psig, > 150 psig, Variable by well, see notes
• Estimate current combined production from the pad in Mcf/d or provide the forecast for the first 90 days
• Walk me through how you currently model backpressure on the gathering line as more wells come online
• Which of the following best captures your current compression gap at peak, measured in horsepower or units Options: No gap, capacity on hand, Small gap, < 250 HP, Medium gap, 250–1,000 HP, Large gap, 1,000–3,000 HP, Very large, > 3,000 HP or unknown
• What single production or pressure metric, if not met, would force you to pause the deployment or walk away from a rental plan

What breaks when compression underperforms

• Which operational outcome causes the most immediate pain when a compressor goes down Options: Daily lost gas revenue, Regulatory exposure from flaring, Contract penalties with midstream, Field crew overtime and travel, Safety or environmental incidents
• Describe a recent compressor outage, including how long it lasted and the operational steps you took
• How many times in the last 12 months have you had an outage that required replacement-unit deployment Options: 0, 1–2, 3–5, More than 5
• Who gets notified first when capacity falls below target, and what action do they typically take
• Which single failure mode would kill this engagement for you, meaning you would stop the project immediately

The other options on your table

• Which alternatives are you actively evaluating right now Options: Extend current rental provider, Purchase new compressor(s), Repair and reuse existing fleet, Use third-party spot rentals, Delay well starts, Other
• Who is the incumbent compressor supplier or internal group currently responsible for this pad Options: Existing rental provider, Internal operations team, No incumbent, greenfield
• What would have to be true about staying with the incumbent for you to not change providers
• Has anyone proposed solving this with internal capital for purchase instead of renting, and if so who and what timeline Options: Yes, procurement/capital team, Yes, operations team, No internal buy proposal, Considering but unclear
• Which competitor features are you comparing most closely when you decide between renting and buying Options: Per-horsepower monthly rate, Replacement-unit response time, Uptime history, Field mechanic coverage, Contract flexibility to swap sizes, Emissions monitoring capability
• If a vendor matched your price but could not meet your service response window, would you switch Options: Yes, No, Depends on replacement guarantee

Site facts that will make or break installation

• List the pad-level readiness items already complete, such as concrete pad, fuel hookup, electrical, access roads, or permits
• Which of these utilities or site services are NOT yet confirmed on the pad Options: Fuel delivery or storage, Temporary power or generator, Electric grid connection, Water or wastewater, Access for heavy transport, None of the above
• Who on your team owns permitting and local regulatory compliance for this site
• Are there known environmental or permit constraints that could delay commissioning, such as noise limits, emissions monitoring, or restricted hours Options: Yes, emissions monitoring required, Yes, restricted operating hours, Yes, site-specific limits, No known constraints, Unsure
• Estimate how long your site will take to reach full readiness from today, in weeks Options: < 1 week, 1–2 weeks, 3–4 weeks, 5–8 weeks, > 8 weeks
• What single site constraint would stop delivery or commissioning outright

Equipment, gas composition, and reliability signals

• Describe the gas composition concerns on this pad, including H2S, water, liquids, or heavy hydrocarbons if known
• Which equipment condition evidence can you share to validate reliability, choose all that apply Options: Maintenance logs, Run-hours and S/N, Recent inspection photos, Failure reports, Emissions test results, None available
• How many field mechanics or technicians does your team typically have assigned per basin for emergency response Options: 0, 1–2, 3–5, More than 5
• When was the last time you ran a full maintenance audit on your compression assets Options: Within 3 months, 3–6 months, 6–12 months, More than 12 months, Never
• If equipment wear from contaminants becomes a recurring issue, how would you expect to change your procurement or operating model Options: Increase spare inventory, Change rental terms, Buy new equipment, Accept higher downtime risk, Other

Who signs off and who must stay convinced

• Who are the decision makers and approvers we need to engage, name role and primary concern for each
• Which internal stakeholder will say no if the uptime guarantee carries exclusions they find unacceptable Options: Operations leader, Compression engineer, Legal or contracts, Finance, Environmental health and safety
• What budget owner or approval threshold would require escalation to procurement or capital committee Options: <$50k, $50k–$150k, $150k–$500k, >$500k, Unsure
• How does your team prefer technical evidence for acceptance, choose the formats that matter most Options: On-site performance tests, Historical uptime reports, Fuel consumption data, Third-party inspection, Factory witness testing
• Which single stakeholder concern, if unresolved, would stop the deal from advancing this quarter

Operational readiness and integration constraints

• Do you have the internal headcount available to support commissioning and handover on the dates you proposed Options: Yes, dedicated team, Limited availability, can support remotely, No, would need vendor support, Unsure
• Which third-party systems must be integrated or handed over at acceptance, such as SCADA, emissions reporting, or fleet telemetry Options: SCADA/HMI, Emissions reporting, Fleet tracking/telemetry, Billing interfaces, None, Other
• Is historical well and production data available in a format you can share for engineering, and who owns that data Options: Yes, engineering team owns it, Yes, production team owns it, Data exists but needs cleanup, No consolidated data available
• Are there contractual or regulatory approvals that must be obtained before installation, such as local permits or operator consents Options: Yes, permits pending, Yes, approvals in review, No approvals required, Unsure
• Which infrastructure prerequisite, if missing, would require you to pause scheduling until resolved Options: Road or crane access, Fuel supply, Power connection, Permits, Crew availability

Acceptance criteria and success signals that matter to you

• Which measurable outcomes will prove the solution works for you after 30 days Options: Uptime percentage, Mcf/d throughput vs forecast, Fuel consumption per Mcf, Emissions levels within permit, Response time to tickets
• What uptime percentage over a 30 day period would make you consider the deployment successful Options: > 99%, 97%–99%, 95%–97%, < 95%
• What replacement-unit response time must be contractually guaranteed for you to proceed Options: < 12 hours, < 24 hours, < 48 hours, < 72 hours, Not required
• If the pilot proves the expected throughput and uptime, what internal approval or budget step would allow you to sign a longer term agreement that week
• Which data and reporting cadence will you require during the first 90 days to stay comfortable Options: Daily operational summary, Weekly performance report, Real-time alerts, Monthly review, Other

Risks, deal breakers, and timeline accelerants

• Which of these risks worries you most about bringing an external compression partner on site Options: Not meeting uptime needs, Hidden site requirements, Gas composition damage to equipment, Insufficient field service in basin, Contract inflexibility
• How would you prefer we demonstrate fleet availability and mechanics coverage for your basin Options: Nearby unit assignments, Field mechanic proximity map, Replacement-unit staging plan, Case studies from basin
• If a single risk were mitigated immediately, which would accelerate your decision the most Options: Guaranteed replacement within 48 hours, Proof of recent maintenance records, Site readiness confirmation, Firm price and terms
• Which constraint, answered now, would kill the deal for you

Deciding the next steps and who does what

• If we can confirm the timeline, site readiness, and a replacement guarantee, how soon could you sign Options: Immediately, Within 1 week, 1–2 weeks, Longer than 2 weeks, Needs executive approval
• Who on your side needs to be in the next technical call and what outcome do they require to move forward
• What documentation should we bring to the next meeting to answer your team's primary concerns Options: Maintenance logs, Uptime reports, Replacement logistics plan, Draft commercial terms, Emissions monitoring spec
• Before we schedule site inspection, what single open question must we resolve
• Finally, which communication channel do you prefer for day-of updates during deployment Options: Phone call, SMS/text, Email, Shared platform channel, On-site point person only

• Site Survey Planning and Access Confirmation
• On-Site Inspection and Evidence Capture
• Maintenance Records Reconciliation and Condition Assessment
• Site Findings Review and Readiness Decision

• If site is cleared, trigger the Pre-Deployment Readiness checklist handoff for scheduling delivery.
• Completed inspection checklist with itemized condition ratings and geo-tagged photo set uploaded to the shared folder.
• List of critical deficiencies that block deployment identified and documented with evidence.
• Measured notes for utilities and access constraints that will feed the installation plan.
• Upload the full set of geo-tagged photos and the completed checklist to the shared workspace using the approved naming convention.
• Produce the preliminary on-site notes package listing condition ratings and any immediate critical items needing remediation.
• Collect any physically available maintenance tags, logbooks, or stickers found on equipment and photograph them for records.
• If stop-work conditions were found, issue an inspection hold notice and list required mitigations before re-inspection.
• Present consolidated findings and evidence
• Formal site readiness decision recorded as go for Pre-Deployment Readiness or no-go with documented remediation actions and deadlines.
• Named remediation actions with deadlines and verification criteria documented for each critical deficiency.
• Follow-up verification date or re-inspection scheduled if remediation is required.
• Publish the consolidated inspection and records package including the readiness decision and remediation plan.
• Create the remediation tracking log with deadlines and verification criteria and share it to the shared workspace.
• Schedule the follow-up verification or reinspection and notify the inspection team and site contact.
• Map maintenance records to inspected assets
• Equipment condition report drafted with risk ratings and a prioritized list of repair or testing actions.
• Catalog of missing records and a clear list of supplemental tests required to close data gaps.
• Recommended acceptance criteria for each asset to be used in the deployment decision.
• Publish the equipment condition report with risk ratings, recommended repairs, and estimated lead times.
• Request and collect any missing maintenance records or test results identified during reconciliation.
• Schedule any required supplemental inspections or non-destructive tests and record expected completion dates.
• Provide a checklist of acceptance criteria per asset for the final readiness decision meeting.
• Confirm scope and success criteria
• Approved site survey checklist and photo metadata standard that will be used on-site.
• Confirmed access windows, safety constraints, and the inspection date and time window.
• Agreed list of maintenance records required and delivery method for each item.
• Publish the final site survey checklist and photo naming standard to the shared workspace.
• Provide the site map with staging and access points annotated and upload to the shared folder.
• Request the listed maintenance records for the last 24 months and confirm delivery method and deadline.
• Schedule and confirm the on-site inspection time window and on-site contact details.
• Safety briefing and access verification
• Review site map, access, and safety constraints
• Assess maintenance history for high-risk indicators
• Review and agree remediation list and timelines
• Pad and foundation inspection
• Identify records gaps and required supplemental testing
• Equipment visual condition survey
• Finalize inspection checklist and photo naming/metadata standard
• Confirm acceptance criteria and go/no-go decision
• Define required records and delivery method
• Schedule follow-up verification or reinspection
• Produce recommended classification and next steps
• Utilities, fuel, and power connection verification
• Confirm schedule and field assignments
• Access, staging, and lifting route validation
• Document immediate critical deficiencies

• Solution Experience, Compression Options and Deployment Scenarios

• Confirm the current state and quantify the cost
• You confirm the proposed staged deployment meets the 30-day requirement and prevents flaring or shut-ins under the provided forecast.
• Deliver a priced, staged deployment plan showing unit sizes, lead times, installation responsibilities, expected uptime impact, and replacement-unit response assumptions within 3 business days.
• You confirm the uptime and replacement-response assumptions reduce daily revenue exposure to an acceptable level.
• Review the well data and modeling inputs
• Run the replacement-unit response simulation for the agreed peak-period scenario and provide quantified revenue protection figures before the follow-up meeting.
• Present engineered compression options and staged deployment scenarios
• Provide the latest well production forecast, recent wellhead pressure logs, and gas composition or contaminant reports for final modeling.
• You agree on measurable acceptance criteria for horsepower per stage, uptime SLA, replacement-unit response time, and emissions monitoring to use in the Solution Scope stage.
• Simulate failure and replacement response
• You identify any missing data or constraints that would change the modeled outcome.
• Confirm the list of approvers, decision criteria, and any budget or contracting constraints to enable a mutual commit discussion.
• Validate assumptions and acceptance criteria
• Forced validation, confirm decision readiness
• Agree next evidence and decision steps

• Solution Experience Session
• Solution Experience Deck
• Solution Brief

• meeting
• slides
• document

• Deploy Compressor Package (50–5000 HP)
• Install and Connect Compressor Package onsite
• Commissioning and Start‑Up Service
• Emergency Field Mechanic Dispatch (two‑hour radius)
• Replacement Unit Rapid Swap Deployment (48‑hour guarantee)
• Scheduled Preventive Maintenance Visits
• On‑Contract Operations and Monitoring (O&M)
• Provide Spare Parts and Consumable Kits
• Fuel Supply Management and Consumption Monitoring
• Emissions Monitoring and Compliance Reporting
• Install Gas Filtration and Contaminant Mitigation
• Equipment Removal, Transport, and Redeployment
• Deliver Runtime Performance and Maintenance Logs

Deploy Compressor Package (50–5000 HP)

• Pad ID and well cluster names your package will serve (enter well or pad identifier used in your field ops)?
• Required nominal horsepower and preferred package type (choose the single best fit for initial scope)? Options: 50-150 HP reciprocating, 150-500 HP rotary screw, 500-1500 HP rotary/combined, 1500-5000 HP custom skid, Undecided — request engineering assessment
• Inlet wellhead pressure range (psig) and target discharge pressure (psig) your field requires for this package?
• Average production gas rate you expect this package to handle (Mcf/day per pad or aggregate)? Options: <500 Mcf/day, 500-2,000 Mcf/day, 2,000-10,000 Mcf/day, >10,000 Mcf/day, Unknown — provide forecast spreadsheet
• Confirm the acceptance test threshold you require for initial deployment and the evidence you will accept (for example: sustain X Mcfd and Y psig for 24 hours with SCADA logs)? Options: Signed commissioning checklist + SCADA logs (24 hours), Field technician report + photos + runtime hours (24 hours), Custom acceptance criteria - describe in next field

Install and Connect Compressor Package onsite

• Electrical supply available at pad and single-line diagram (SLD) reference you can provide (voltage, phase, breaker size)? Options: 480 V AC 3-phase, 600 V AC 3-phase, Generator-only - specify size, No grid power - generator required, Attach SLD
• Fuel gas supply pressure and composition you will provide for operation and start-up (psig, methane %, CO2 %, H2S ppm)?
• Who on your team will be responsible for pad preparation (concrete, anchor bolts, grading) and what documentation will you provide to verify pad readiness? Options: You will provide pad prep, We should quote pad prep work, Shared responsibility — will define
• Transport and lift constraints at the pad (road width, bridge limits, crane availability, max skid weight) that could affect installation?
• Connection deliverables you expect from installation (electrical terminations, piping spool welding to API standard, instrument hook‑ups, grounding) — select all that apply or add others? Options: Electrical terminations to SLD, Piping spool welding and NDE, Instrument hook-ups and tag list, Grounding and lightning protection, Other - describe

Commissioning and Start‑Up Service

• Commissioning tests you require to accept start-up (examples: vibration baseline, blowdown curve, fuel consumption run, leak checks) — list specific tests and thresholds.
• Performance verification outputs you need in the commissioning report (select all required artifacts): Options: Vibration spectrum and baseline, Fuel consumption (MMBtu/hr) and efficiency, Discharge pressure and measured flow curve, Lubrication oil analysis results, Instrument calibration certificates
• Confirm how you will formally accept commissioning: which evidence will close acceptance (for example: signed commissioning checklist and SCADA tag logs for a continuous 24‑hour window)? Options: Signed checklist + SCADA logs (24 hours), Field tech report + photos + runtime hours, Third‑party witness report required
• On-site approver for commissioning sign-off and their contact details (name, role, phone, email)?
• Third-party or regulatory witnesses required during start-up (permit inspector, API inspector, state agency) and the agency name or permit number if applicable? Options: No third-party witness required, Yes - provide agency name/permit ID

Emergency Field Mechanic Dispatch (two‑hour radius)

• Primary on-site contact for emergency dispatch and the typical shift coverage when a two‑hour response is required (name and phone)?
• Basins and pad locations where you expect units to operate and require the two‑hour mechanic coverage (select all that apply)? Options: Permian, Marcellus, Haynesville, Other - list
• Expected maximum allowable response time for critical failures at this site (hours)? Options: 2 hours, 4 hours, 8 hours, Next business day
• Spare parts you expect first‑response mechanics to carry for initial repairs (filter elements by micron rating, common gaskets, starter parts, belts)?
• Access to your SCADA or remote controls for repairs: do you require VPN credentials, limited tag access, or will you provide on-site local control during mechanic visits? Options: Yes — provide VPN and tag list, No — local control by your staff during visits, Hybrid — provide emergency access only

Replacement Unit Rapid Swap Deployment (48‑hour guarantee)

• Logistics staging address and nearest highway/interstate for delivering a replacement skid (provide depot or pad staging coordinates)?
• Do you accept the 48‑hour replacement deployment guarantee as a contractual SLA or do you require a faster SLA/exception discussion? Options: Accept 48‑hour guarantee, Require faster SLA - request exception, Need phased SLA with financial remedies
• Pad readiness constraints that could delay a swap (anchor bolts, piping adapters, electrical disconnects) and an estimated mitigation time for each constraint in hours?
• Required logistics proof at replacement delivery you will accept (for example: GPS tracking link, carrier ETA, signed delivery manifest, photos on set-down)? Options: GPS tracking + delivery manifest, Carrier ETA + photos, Signed handover checklist
• Permitting or inspector gates that must be cleared prior to energizing a replacement unit (permit ID, inspection window, agency contact)?

Scheduled Preventive Maintenance Visits

• Maintenance interval you prefer for scheduled preventive maintenance (select interval or specify operating‑hour trigger)? Options: Monthly, Quarterly, By operating hours (specify hours)
• Documentation required after each PM visit (choose required deliverables): Options: Service log, Oil analysis report, Filter replacement checklist, Calibration certificates, All of the above
• Site safety procedures the technician must follow on each visit (lockout/tagout LOTO reference, confined space permit name or ID, PPE requirements)?
• Predictive maintenance features desired with PMs (vibration trend alarms, oil particle counts, thermal imaging) — select all that apply? Options: Vibration trending, Oil particle analysis, Thermal imaging scans, Standard PM only
• Estimated number of units per pad you expect under the PM contract for scheduling purposes? Options: 1, 2-3, 4+

On‑Contract Operations and Monitoring (O&M)

• SCADA integration method you require for remote monitoring and control (select protocol or provide API details)? Options: Modbus TCP, OPC UA, MQTT, Proprietary API - provide spec
• Telemetry and SCADA tags you require in the monitoring dashboard (discharge pressure, inlet pressure, runtime hours, fault codes) — paste tag list or describe naming convention.
• Operating coverage required (24/7 remote monitoring + on‑call technician, business‑hours monitoring, or custom schedule)? Options: 24/7 remote monitoring + on‑call tech, Business‑hours monitoring, Custom schedule - describe
• Alarm escalation rules and contact sequence you want configured (phone then SMS then email, or alternate escalation tiers) with escalation time windows in minutes?
• Data retention period for runtime, fault and maintenance logs you require for operational review or audits? Options: 90 days, 1 year, 5 years, Custom - specify

Provide Spare Parts and Consumable Kits

• Which critical spare parts should be stocked locally or on-site (filter elements with micron rating, valves, piston rings, common gaskets)?
• Pick a consumable replenishment model you prefer for filters and wear items: Options: On‑demand shipping, Monthly restock, Consignment inventory at depot
• Do you restrict use of OEM parts or require preferred manufacturer parts only (provide list of allowed manufacturers if applicable)? Options: No restriction, OEM only - list manufacturers, Preferred manufacturers - list
• What maximum lead time for non‑stocked parts is acceptable to your operations (hours or days)? Options: <24 hours, 24-72 hours, >72 hours
• Explain how you want spare parts moved between pads and depots for redeployment (priority routing rules, consolidation preferences)?

Fuel Supply Management and Consumption Monitoring

• Which fuel type will be primary for package operation at this pad (field produced fuel gas, diesel, propane)? Options: Field produced fuel gas, Diesel, Propane, Other - specify
• Give your expected fuel consumption threshold you consider acceptable (specify MMBtu/day or gallons/day for diesel)?
• Enter the fuel metering and telemetry points you require (pulse meter, cumulative consumption, hourly rate, leak detection)?
• Do you want us to manage fuel procurement and delivery scheduling or will you supply fuel and manage deliveries? Options: We manage fuel procurement and deliveries, You will supply fuel, Hybrid - emergency refills only
• Fuel quality specifications you require (minimum BTU, maximum water/vapor content, H2S limit in ppm) and any supplier MSDS requirements?

Emissions Monitoring and Compliance Reporting

• Permit ID or regulatory program that governs emissions for this pad (state permit number, EPA rule citation) that we must reference in reports?
• Emissions metrics you require reported and reporting cadence (select gases and frequency): Options: NOx, CO, Methane slip, VOCs, Total hydrocarbons
• Reporting format required by your regulator or internal compliance team (monthly spreadsheet, EPA portal upload, certified third‑party report)? Options: Monthly spreadsheet, EPA portal upload, Certified third‑party report, Other - specify
• Monitoring method you prefer (continuous emissions monitoring system CEMS, portable analyzers, grab sampling) and any mandated sensor placement constraints?
• Records or chain-of-custody documentation you need for audits (sensor calibration certificates, sample chain‑of‑custody, maintenance logs)? Options: Calibration certificates, Sample chain-of-custody, Maintenance logs, All of the above

Install Gas Filtration and Contaminant Mitigation

• Known gas contaminants from your latest lab report (enter percentages or ppm for CO2, H2S, water dew point, liquids, sand)?
• Filtration solutions you prefer (coalescing filter, particulate filter micron rating, inlet separator, chemical treatment) — select applicable items? Options: Coalescing filter, Particulate filter (5 micron), Inlet separator, Chemical treatment
• Sampling points and pressure drop thresholds that should trigger filter element changeouts (specify tag or delta‑P value)?
• Produced‑fluid handling constraints that affect filtration design (condensate disposal route, on‑pad separator, flare restrictions)?
• Sour service or materials requirements you mandate for wetted parts (NACE compliance, H2S handling procedures) — yes or no? Options: Yes - sour service required, No

Equipment Removal, Transport, and Redeployment

• Preferred decommissioning window and any transport constraints (night moves allowed, local escort requirements, permit for oversize loads)?
• Do you require decontamination or fuel purging procedures before transport (fuel purge certificate, solvent clean)? Options: Yes - decontamination required, No
• Maximum weight, height or footprint constraints for road transport from this pad to depot (specify limits or local route restrictions)?
• Documentation required at handover for transport and redeployment (transport manifest, pre-load inspection checklist, fuel purge certificate)? Options: Transport manifest, Inspection checklist, Fuel purge certificate, All of the above
• Redeployment priority rules across your assets when allocating units (for example: highest revenue pads first, contractual priority, geographic proximity)?

• Master Services Agreement (MSA)
• Statement of Work (SOW)
• Service Level Agreement (SLA)
• Order Form & Pricing Schedule
• Replacement Unit Commitment
• Field Service Coverage Commitment
• Scaling & Swap Rider
• Payment & Billing Terms
• Operational Acceptance & Commissioning Certificate
• Emissions Monitoring & Regulatory Compliance Addendum
• Insurance & Indemnity Exhibit

• Go-Live Health Check (Weeks 1-4)
• First Measurement Review (Weeks 4-10)
• Acceptance Gate Review (Day ~90)
• Ongoing Operational Review (Quarterly)

• Document the incumbent wind-down checklist completion or retention-read-only status and archive related records.
• Decide whether unit uptime percentage and fuel consumption rate are trending toward the Solution Scope targets or require remediation.
• Document root causes for any gaps and record specific corrective actions with resolution dates to reach acceptance by day 90.
• Deliver a 30-day performance packet including uptime percentage, fuel consumption rate, throughput, and incident log.
• Create a prioritized remediation plan with tasks, expected completion dates, and acceptance criteria for each remediation item.
• Update the shared ticket backlog to reflect priority and expected resolution dates ahead of the Acceptance Gate Review.
• Restate acceptance criteria from Solution Scope
• Produce a documented acceptance decision against the numeric targets recorded in Solution Scope with a named buyer signatory.
• Verify incumbent equipment has been decommissioned or retained read-only and ensure data and contract wind-down tasks are recorded.
• Publish the signed acceptance record and supporting evidence in the shared workspace.
• If applicable, publish a remediation schedule with milestones and re-test dates for any failed acceptance criteria.
• Re-confirm success criteria and owners
• Quarterly SLA and uptime review
• Confirm the solution continues to meet uptime guarantees and document any SLA variances and their remediation.
• Reduce the open ticket backlog and agree timebound actions to close high-priority operational issues.
• Publish the quarterly SLA compliance dashboard including uptime percentage, fuel consumption rate, throughput, and ticket metrics.
• Record a timebound plan to close high-priority open tickets and monitor progress in the shared channel.
• Schedule any agreed maintenance windows and parts provisioning to prevent future downtime.
• Confirm the deployment checklists are complete and each acceptance criterion in Solution Scope has a named owner.
• Document and prioritize any early issues that could impact uptime or safety with remediation due dates.
• Publish the go-live issues log with owners, priority, and target resolution dates into the shared workspace.
• Provide commissioning test results and first-run instrumentation logs for archival and review.
• Schedule the First Measurement Review meeting in the weeks 4-10 window and circulate required data extracts to participants.
• Present 30-day performance data
• Present cumulative performance data
• Operational metrics trend review
• Compare data to Solution Scope targets
• Deployment and commissioning validation
• Document pass/fail per criterion and evidence
• Early operational signals review
• Open ticket backlog and response-time audit
• Root-cause diagnosis for gaps
• Service tickets and response-time review
• Formal acceptance decision and signatory capture
• Open issues and escalation paths
• Emissions monitoring and compliance check
• Agree quarterly operational actions
• Agree corrective actions and timeline to acceptance gate
• Incumbent wind-down verification
• Agree immediate remediation actions and schedule next measurement
• Define remediation items for any failed criteria