Continuity Infrastructure
for Remote Utility & Water Operations
Drinking water and wastewater infrastructure sits inside the EU critical-entity perimeter. Power continuity at remote pumping stations, substation auxiliary nodes, telemetry outposts and weak-grid booster assets is no longer an operational footnote — it is an architectural decision now driven by EU Grids Package COM/2025/1005, NIS2, CER Directive 17 July 2026 designation, and the ANRE Romania 5th regulatory period investment-incentive framework.
VENDOR.Max is a continuity infrastructure layer — engineered as auxiliary power architecture for the SCADA/RTU/IED control, telemetry and auxiliary station-service support that determines whether your remote infrastructure delivers service, meets resilience obligations, and avoids the recurring fuel logistics burden that defines diesel-backed utility operations today.
VENDOR.Max for utility and water infrastructure is a continuity infrastructure power architecture engineered as an auxiliary layer for remote utility nodes — pumping stations, substation auxiliary power for SCADA/RTU/IED control, telemetry outposts, water booster and lift stations, and weak-grid distribution support assets. It is positioned beneath primary substation and station-service equipment (Schneider Electric, ABB, Siemens, Hitachi Energy, SEL, Eaton, Vertiv — partners, not competitors), addressing the structural dependency on diesel logistics, recurring generator maintenance and battery UPS replacement cycles that defines remote utility infrastructure economics.
Remote utility infrastructure power refers to continuity at distributed, unmanned utility assets where diesel supply chains, maintenance burden, weak-grid stability or underground siting make conventional backup architectures structurally costly. Architectural class: auxiliary continuity infrastructure layer — not primary device replacement.
Use case: remote utility & water continuity infrastructure.
Best fit: pumping stations, substation auxiliary (SCADA/RTU/IED), telemetry outposts, weak-grid booster nodes, underground sites.
Decision-maker: Utility VP Operations (DSO/TSO), Water Operations Director, Gov/EU Programme Manager.
Stage: TRL 5–6 pre-commercial validation.
Proof: 1,000+ documented hours, 532h cycle, ES2950176 (granted), WO2024209235 (PCT).
Next step: Pilot Readiness Assessment →
Substation auxiliary power for SCADA/RTU/IED control, relay protection and station-service support continuity — the resilience-conversion layer for DSO/TSO portfolio assets. Remote pumping stations where fuel delivery defines OPEX. Telemetry and metering outposts where power loss becomes monitoring blindness. Underground and covered sites where solar is structurally inapplicable.
The structural dependency on diesel logistics, recurring generator maintenance, and battery UPS replacement cycles that makes remote utility infrastructure expensive to power and operationally fragile. Under EU Grids Package COM/2025/1005 and the ANRE 5th regulatory period investment-incentive framework, auxiliary substation architecture is being repriced from residual line-item to architectural lever with documented innovation-recognition pathway.
TRL 5–6 pre-commercial validation. Not a certified commercial product. 1,000+ cumulative documented operational hours; longest single continuous operational segment 532h at 4 kW. Patent canon: PCT WO2024209235 + ES2950176 OEPM (granted) + EP/US/CN/IN national and regional examination tracks active. Independent verification pathway (DNV / TüV) in progress; CE/UL pathway defined, target 2026–2028.
TRL 5–6
Laboratory validated · pre-commercial
532h cycle
Longest single continuous operational segment
6 jurisdictions
ES2950176 granted · PCT WO2024209235 · EP/US/CN/IN examination active
DNV / TüV
Independent verification pathway · engagement in progress
Remote utility nodes don't fail dramatically.
They fail through accumulated deployment friction.
Water does not stop needing to flow because a generator failed at a remote pumping station. A substation does not lose its primary equipment when auxiliary AC drops — but it loses SCADA visibility, remote restoration capability, and SAIDI/SAIFI performance. Under EU Grids Package and the ANRE 5th regulatory period investment-incentive framework, this distinction has been formally repriced.
For utility operators managing distributed, unmanned infrastructure — substation auxiliary nodes, booster stations, pressure regulation outposts, telemetry cabinets, metering assets — continuity is not a background assumption. It is the operating condition that determines whether the organisation meets its CER critical-entity resilience obligations, NIS2 incident-reporting posture, and ANRE 5th period investment-recognition criteria.
Recurring fuel chain at every remote node
The line item that never closes
Backup generator procurement, fuel delivery scheduling, run-readiness verification, fuel quality management, theft exposure at remote sites — each remote node adds not just an energy cost but an operational dependency on a supply chain that must be maintained year-round. For substation auxiliary architecture across a DSO/TSO substation cluster portfolio, this multiplies linearly with asset count.
Every service visit is an operational expedition
The OPEX category that scales with network size
Unmanned pumping stations, substation auxiliary cabinets and telemetry outposts do not service themselves. Generator inspection, station battery replacement under IEEE 485 sizing rules, sensor calibration and fault response each require dispatch — often to sites without reliable road access, in conditions that make routine maintenance expensive and sometimes operationally unsafe.
Power loss at a treatment node — not an inconvenience
CER + NIS2 audit posture · SAIDI/SAIFI consequence
Per the US EPA Power Resilience Guide (EPA 800-R-19-001), power loss at drinking water and wastewater utilities can render firefighting pumps inoperable, force healthcare facility closures, and allow contaminants to enter the distribution system. Wastewater pump failure may lead to direct discharge of untreated sewage.
For EU operators, this sits inside the CER Directive (2022/2557) all-hazards resilience framework with critical-entity designation deadline 17 July 2026, and the NIS2 Directive (2022/2555) Article 21 risk-management obligations and management accountability framework. Remote-node power architecture is no longer evaluated in isolation from organisational resilience posture.
Underground chambers, covered vaults, shaded distribution
The structural gap solar + battery does not address
Treatment vaults, underground pump chambers, shaded distribution nodes and enclosed substation auxiliary cabinets cannot use solar architecture. Battery-only UPS systems sized under IEEE 485 replace one maintenance cycle (fuel) with another (battery replacement every 3–5 years per IEC 60896). For below-ground and covered utility assets, no commercially proven fuel-logistics-independent alternative currently exists at scale — this is the architectural gap.
The resilience perimeter for water and utility infrastructure
has changed. The operating assumptions have not caught up.
Four overlapping regulatory regimes converge on utility auxiliary architecture by 2026. The conversation has moved from operational line-item to architectural priority — the reporting structures have not always caught up.
EU Grids Package COM/2025/1005 (10 December 2025) re-frames grid modernization as architectural priority with €584B investment needed to 2030 (€1.2T to 2040); 40% of EU distribution grids over 40 years old; renewable curtailment cost EU €8.9B in 2024 alone. Commission Notice C/2025/8473 operationalises anticipatory investment framework with first-ready-first-served principle and queue-cleaning provisions — auxiliary infrastructure decisions are now documentable as anticipatory CAPEX with regulatory recognition pathway.
CER Directive 2022/2557 sets critical-entity designation deadline 17 July 2026 with Article 13 all-hazards resilience measures. DSOs/TSOs and water operators are critical entities in energy and water sectors. NIS2 Directive 2022/2555 introduces Article 21 risk-management obligations and a management accountability framework across essential and important entities. The EU Water Resilience Strategy 2025 sets infrastructure protection and continuity as binding priorities to 2030.
In Romania, the ANRE 5th regulatory period 2025–2029 investment-incentive framework defines RRR ~6.94% with an additional ~1% investment incentive applied to qualifying infrastructure investments. This positions auxiliary substation architecture as documentable investment-grade CapEx under the regulatory recognition pathway, rather than residual line-item. Romania PNRR Componenta 6 targets ~29 substations with ~€29.557M envelope for modernization and digitalization. The 2026 decision window is the moment to document architecture commitments before the 2027–2029 capital-allocation cycle locks.
10 December 2025 — EU Grids Package COM/2025/1005 published.
17 July 2026 — CER Directive Member State critical-entity designation deadline.
2025–2029 — ANRE Romania 5th regulatory period: RRR ~6.94% plus additional ~1% investment incentive.
2026–2028 — VENDOR.Max CE / UL certification pathway window.
2030 — EU Grids Package 40% domestic equipment target (strategic autonomy procurement filter).
The cost base that makes architectural reassessment rational is already documented in sector-standard benchmarks. These figures represent the operating burden remote utility infrastructure already carries — before any VENDOR.Max consideration.
Source: US EPA — Energy Efficiency for Water Utilities · EPA 816-F-13-004. Power Resilience Guide: EPA 800-R-19-001. Figures describe sector baseline — not operator-specific or VENDOR.Max-specific savings.
Outside the EU regulatory perimeter, the operating reality is often more immediate. Across sub-Saharan Africa and MENA, water and utility operators face absent or unreliable grid supply, fuel delivery constraints and limited field service access — often without a regulatory framework that enforces resilience.
The consequence of power failure is not a compliance filing — it is a service delivery failure that affects communities directly. The architectural logic for continuous infrastructure power at remote utility nodes is identical; the compliance language changes by region.
Grid-only, generator-backed and battery-heavy approaches
each carry their own structural burden.
Works until it doesn't
An assumption, not a strategy
For utility infrastructure in weak-grid pockets, on vulnerable feeders, or at distribution edges where restoration time is not aligned with operational urgency, grid-only is not a resilience strategy — it is an unstated dependency that becomes visible only during outage. Under CER Article 13, this dependency is increasingly an audit finding.
A logistics chain that doesn't close
Continuity through recurring exposure
Diesel-backed continuity solves the immediate gap but introduces a logistics chain that does not stop: fuel procurement, delivery scheduling, regular inspection runs, manufacturer-specified service intervals, fuel quality management, maintenance contracts, run-readiness verification. For remote utility sites with difficult access, each obligation becomes an expedition — not a maintenance task.
One maintenance cycle replaces another
Lifecycle exposure carries through
Battery UPS systems sized under IEEE 485 address short-duration gaps but carry their own lifecycle economics: replacement cycles every 3–5 years per IEC 60896, thermal operating constraints, NERC PRC-005 monitoring obligations. For remote sites with limited access, a battery lifecycle event is not a scheduled task — it is a logistics problem repeated every cycle.
VENDOR.Max is engineered as auxiliary continuity infrastructure operating beneath primary substation and station-service equipment provided by Tier-1 OEMs — Schneider Electric, ABB, Siemens (Energy + Smart Infrastructure), Hitachi Energy, SEL (Schweitzer Engineering Laboratories), Eaton, Vertiv. These entities supply power transformers (HV/MV/LV), MV/LV switchgear, circuit breakers, protection relays primary, IEDs, RTUs and SCADA gateways: the substation's primary electrical function.
VENDOR.Max addresses a different architectural class — the auxiliary infrastructure layer that preserves SCADA/RTU/IED, relay control, battery monitoring and emergency communications operational visibility when station service is disturbed. These are partner positions, not competing technologies. Integration occurs via the standard IEC 61850 + IEC 62351 station-automation and communications-security interface. Multi-vendor reality of DSO/TSO substation portfolios is preserved.
The case for VENDOR.Max evaluation is not that conventional approaches are wrong. It is that for the right asset classes — remote, unattended, weak-grid, maintenance-heavy substation auxiliary and utility edge infrastructure — a continuity architecture engineered for operation without fuel logistics dependency is worth a structured technical assessment under the 2026 regulatory window.
Not a primary substation device.
A continuity architecture that sits beneath it.
VENDOR.Max is engineered as the auxiliary continuity infrastructure layer for remote and weak-grid utility nodes. It does not replace primary substation equipment, MV/LV switchgear, circuit breakers, protection relays or transformer-level station service. It addresses what sits beneath them: the SCADA/RTU/IED control continuity, telemetry uptime, and auxiliary station-service support that determines whether your infrastructure delivers service when the supply chain or grid does not.
At the complete device boundary, classical energy accounting applies: P_in,boundary = P_load + P_losses + dE/dt; efficiency η ≤ 1. Patent canon: PCT WO2024209235 + ES2950176 OEPM (granted) + EP/US/CN/IN national and regional examination tracks active.
Substation auxiliary · SCADA / RTU / IED
DSO / TSO portfolio assets
Auxiliary AC continuity for SCADA gateways, RTUs, IEDs, protection relay supervision, station battery monitoring and emergency communications. Integration via IEC 61850 + IEC 62351 station-automation interface. Multi-vendor portfolio reality with Schneider Electric, ABB, Siemens, Hitachi Energy, SEL primary equipment preserved.
Remote pumping stations · lift & booster nodes
Water & wastewater operators
Distributed pumping nodes where fuel delivery, road access, and maintenance dispatch define the operating expenditure floor. Includes potable water booster stations, wastewater lift stations, pressure regulation outposts and chlorination injection points without reliable grid supply.
Telemetry & metering outposts
Distribution edge visibility
Remote telemetry cabinets, smart-meter concentrators, fault passage indicators and grid-edge monitoring assets where power loss becomes monitoring blindness. Continuity here directly affects SAIDI / SAIFI measurement integrity and CER all-hazards resilience posture.
Underground & covered sites
Where solar is structurally inapplicable
Underground pump chambers, treatment vaults, shaded distribution cabinets and enclosed auxiliary rooms where solar-plus-battery architecture cannot operate. Architecturally addressable only by fuel-logistics-independent continuity layer.
Weak-grid distribution support
Vulnerable feeders · restoration-time gap
Distribution-edge assets on feeders where grid restoration time is not aligned with operational urgency. Continuity layer reduces dependency on diesel-backed bridge architecture for the recurring short-to-medium outage profile.
Where VENDOR.Max does not fit
Architectural class boundary
Primary substation transformers, MV/LV switchgear, circuit breakers, protection relays primary, primary station-service replacement, municipal prime-power generation, residential consumer power, mobile vehicle propulsion (separate VENDOR.Drive configuration).
Five operational shifts that follow
from architectural class change.
No recurring site fuel logistics
Recurring chain removed
Continuity architecture without on-site combustion reduces or removes the fuel procurement, delivery scheduling, quality management and theft exposure chain that scales linearly with substation cluster portfolio asset count.
Reduced maintenance dispatch
No generator inspection cycle
No manufacturer-specified generator service intervals, no fuel quality verification visits, no battery UPS replacement cycles every 3–5 years per IEC 60896. Maintenance footprint reshaped around the operational envelope, not the consumables calendar.
SCADA / telemetry uptime preserved
Control visibility retained
Auxiliary continuity preserves SCADA/RTU/IED operational visibility, relay supervision, battery monitoring and emergency communications when station service is disturbed. Restoration capability and SAIDI / SAIFI measurement integrity protected.
No solar dependency
Underground / covered sites addressable
Operates without solar irradiance, enabling continuity at underground pump chambers, treatment vaults, shaded distribution cabinets and enclosed substation auxiliary rooms where solar-plus-battery architecture cannot deploy.
No on-site combustion
CER all-hazards posture aligned
Non-combustion auxiliary architecture aligned with CER Directive all-hazards resilience framework, EU strategic-autonomy procurement orientation, and the documentable investment-recognition pathway under ANRE 5th regulatory period.
Four continuity approaches at remote utility nodes —
side by side, on operating attributes.
Grid-only
Fuel chain: None
Maintenance: Low
Weak-grid fit: Poor
Underground: Yes
CER posture: Dependent on grid
Status: Standard practice
Diesel-backed
Fuel chain: Recurring · year-round
Maintenance: High · service intervals
Weak-grid fit: Yes
Underground: Yes · ventilation required
CER posture: Logistics exposure
Status: Common · legacy
Solar + battery
Fuel chain: None
Maintenance: Battery cycle every 3–5y
Weak-grid fit: Site-dependent
Underground: No · structural gap
CER posture: Partial
Status: Established · site-limited
VENDOR.Max continuity layer
Fuel chain: None on site
Maintenance: Reduced footprint
Weak-grid fit: Yes
Underground: Yes
CER posture: Non-combustion aligned
Status: TRL 5–6 pre-commercial
Comparison reflects architectural attributes at site level for remote / unattended / weak-grid utility infrastructure. Site-specific outcomes depend on load profile, asset class, grid context and integration pathway. VENDOR.Max is at pre-commercial validation stage; deployment requires structured technical assessment.
Pre-commercial validation,
not commercial product.
VENDOR.Max sits at TRL 5–6 — technology validated in relevant operational environment, system prototype demonstrated under representative operating conditions. This is pre-commercial stage. It is not certified for unrestricted commercial deployment.
Validation has been accumulated under controlled operational conditions and is documented at the device boundary. Numbers reflect measured operational segments, not projected performance.
Independent verification engagement with DNV and TüV is in progress. CE / UL certification pathway is defined for the 2026–2028 window. Procurement-grade certification is required before any commercial DSO / TSO / water utility deployment.
TRL stage: 5–6 pre-commercial validation.
Hours documented: 1,000+ cumulative operational hours.
Longest segment: 532h continuous operational run at 4 kW.
Design range: 2.4–24 kW configurations.
Verification: DNV / TüV engagement in progress.
Certification: CE / UL pathway defined, 2026–2028 window.
Spain: ES2950176 · granted · OEPM.
PCT: WO2024209235 · international filing.
Europe: EP national / regional examination active.
United States: US examination active.
China: CN examination active.
India: IN examination active.
Patent canon: PCT plus granted Spain OEPM patent, with EP / US / CN / IN national and regional examination tracks active. EUIPO trademark 019220462 registered. Patent material identifies the inventors in the official patent records. Public evaluation should rely on the patent portfolio and registry status, not on reconstructed technical disclosure.
Patent protection is one component of validation evidence. It establishes the IP basis of the architecture but does not by itself constitute deployment certification.
Architectural class boundaries,
explicitly stated.
Architectural class: auxiliary continuity infrastructure layer for remote and weak-grid utility nodes.
Validation stage: TRL 5–6 with 1,000+ documented operational hours.
Patent canon: PCT plus granted Spain OEPM patent, with EP / US / CN / IN national and regional examination tracks active.
Energy accounting: classical boundary balance applies, P_in,boundary = P_load + P_losses + dE/dt.
Partner orientation: operates beneath Tier-1 primary equipment (Schneider Electric, ABB, Siemens, Hitachi Energy, SEL, Eaton, Vertiv).
Not free energy: at the complete device boundary, classical energy accounting applies, P_in,boundary = P_load + P_losses + dE/dt; η ≤ 1.
Not certified: CE / UL certification pathway is defined for 2026–2028, not yet complete.
Not NIS2 compliant: operator-level NIS2 / CER compliance is a programme responsibility of the operator.
Not prime-power replacement: does not replace municipal prime-power, primary station service, or primary substation equipment.
Not a tariff guarantee: ANRE investment-incentive recognition is decided by the regulator, not by the supplier.
Structured technical assessment,
not a sales conversation.
Engagement is structured around a four-stage Pilot Readiness Assessment. It is engineered for utility VP Operations, water operations directors and government / EU programme managers who need to evaluate auxiliary continuity architecture against documented operating conditions and regulatory context, not against marketing claims.
Each stage produces a documented output. No pilot commitment is required during stages one and two. No unrestricted commercial deployment occurs before the relevant independent verification and certification milestones are met.
Infrastructure context
Documented asset class review
Substation auxiliary asset inventory, remote pumping site profile, telemetry outpost mapping, weak-grid feeder context, regulatory posture under CER / NIS2 / ANRE / EU Grids Package. Produces an architectural fit assessment document. No commitment required.
Technical evidence review
Validation evidence walkthrough
Documented operating hours, longest continuous segment, energy accounting at the device boundary, patent portfolio status, independent verification pathway, certification timeline. Direct technical questions answered by engineering, not by sales.
Pilot scoping & integration
Site, load profile, IEC 61850 / 62351 integration
Site-class selection, load profile definition, IEC 61850 + IEC 62351 integration pathway with existing primary equipment, telemetry and control integration, measurement plan, success criteria. Produces a pilot proposal with operator-defined exit criteria at every stage.
Pilot execution & documentation
Measured operational segment
Pilot execution against the agreed measurement plan, with documented operational segments, boundary energy accounting, telemetry-grade measurement log. Output is procurement-grade evidence for operator internal evaluation and regulatory documentation.
DSO and TSO operators with substation auxiliary modernization mandates under EU Grids Package, ANRE 5th regulatory period or PNRR Componenta 6.
Water and wastewater utilities with remote pumping, lift and booster infrastructure under EU Water Resilience Strategy 2025.
Government and EU programme managers evaluating critical-entity resilience architecture under CER and NIS2.
Multilateral and development institutions with weak-grid water and utility portfolios in EMEA and global emerging markets.
Procurement seeking certified commercial product today. VENDOR.Max is at TRL 5–6 pre-commercial validation stage; CE / UL pathway is defined for 2026–2028.
Operators requiring primary substation equipment — transformers, MV/LV switchgear, circuit breakers, primary protection relays. These are partner-equipment categories.
Consumer or residential applications. Architecture is engineered for institutional and infrastructure deployment, not for individual consumer use.
Vehicle propulsion and mobile applications. Vehicle deployment is a separate configuration (VENDOR.Drive), not covered by this page.
Direct answers to the questions
institutional buyers actually ask.
Is VENDOR.Max a generator?
VENDOR.Max should not be evaluated as a conventional generator. It is an auxiliary continuity infrastructure layer. At the complete device boundary, classical energy accounting applies: P_in,boundary = P_load + P_losses + dE/dt; efficiency η ≤ 1. It does not replace municipal prime-power or primary station service.
Does it replace our diesel backup generators?
For the right asset classes — remote, unattended, weak-grid, maintenance-heavy substation auxiliary and utility edge infrastructure — it is an architectural alternative to diesel-backed continuity. Fit, sizing and integration are determined site-by-site through the Pilot Readiness Assessment.
Does it integrate with Schneider / ABB / Siemens primary equipment?
Yes. Integration occurs via the standard IEC 61850 + IEC 62351 station-automation and communications-security interface, beneath primary substation equipment from Schneider Electric, ABB, Siemens, Hitachi Energy, SEL, Eaton, Vertiv. These are partner positions, not competing technologies. Multi-vendor portfolio reality is preserved.
What is the current certification status?
VENDOR.Max is at TRL 5–6 pre-commercial validation. CE / UL certification pathway is defined for the 2026–2028 window. Independent verification engagement with DNV and TüV is in progress. Commercial DSO / TSO / water utility deployment requires procurement-grade certification milestones to be met first.
How many operational hours are documented?
1,000+ cumulative documented operational hours under controlled conditions. Longest single continuous operational segment is 532 hours at 4 kW. All numbers reflect measured operational segments documented at the device boundary, not projected performance.
What is the patent status?
Patent canon: PCT WO2024209235 plus granted Spain OEPM patent ES2950176, with EP / US / CN / IN national and regional examination tracks active. EUIPO trademark 019220462 registered.
Does deployment satisfy NIS2 or CER compliance?
No. Operator-level NIS2 and CER compliance is a programme responsibility of the operator. VENDOR.Max architecture contributes to non-combustion auxiliary continuity posture aligned with CER all-hazards resilience framework, but compliance certification remains with the operator and the competent authority.
Is ANRE tariff recovery guaranteed?
No. ANRE 5th regulatory period defines RRR ~6.94% with an additional ~1% investment incentive applied to qualifying infrastructure investments. Whether a specific auxiliary architecture investment qualifies for the incentive is decided by the regulator on a case-by-case basis, not by the supplier.
What is the design power range?
2.4–24 kW configurations. The continuity layer is engineered for the auxiliary AC and DC load profile typical of substation auxiliary, remote pumping, water booster and telemetry-class assets. Larger configurations are subject to engineering review.
Does it work at underground or covered sites?
Yes. The architecture does not require solar irradiance and does not involve on-site combustion. This makes it applicable at underground pump chambers, treatment vaults, shaded distribution cabinets and enclosed substation auxiliary rooms where solar-plus-battery cannot operate.
What does the Pilot Readiness Assessment cost?
Stage 01 (infrastructure context) and Stage 02 (technical evidence review) are conducted without commitment. Stage 03 (pilot scoping) and Stage 04 (pilot execution) are commercial engagements with scope-defined terms agreed between the operator and the supplier.
Where is the supplier registered?
MICRO DIGITAL ELECTRONICS CORP SRL, Bucharest, Romania, EU. Registration CUI 50047468. Brand: VENDOR.Energy. The supplier operates under EU jurisdiction and is positioned within the EU strategic-autonomy and grid-modernisation context.
Begin with documented
infrastructure context.
The first stage of the Pilot Readiness Assessment is conducted without commercial commitment. It produces a documented architectural fit assessment for your specific asset portfolio and regulatory context.
For DSO and TSO substation auxiliary modernization, remote pumping and water booster continuity, telemetry outpost resilience, and weak-grid distribution edge infrastructure under the 2026 regulatory window.
Supplier: MICRO DIGITAL ELECTRONICS CORP SRL · Bucharest, Romania, EU · CUI 50047468.
Patent canon: PCT WO2024209235 + ES2950176 OEPM granted + EP / US / CN / IN examination tracks active.
Trademark: EUIPO 019220462 registered.
Stage: TRL 5–6 pre-commercial validation. Not certified for unrestricted commercial deployment. CE / UL pathway defined for the 2026–2028 window.