Calisen adopts Kraken for smart-meter field operations

Calisen is adopting Kraken Field to coordinate scheduling, dispatch, and workforce management across its national smart-meter installation and maintenance operation.

The platform will support approximately 1,100 field personnel, matching engineers with work according to location, competence, tools, equipment, appointment conditions, and the type of meter intervention required.

Across its operation, Calisen carries out a home visit approximately every six seconds. At that volume, modest improvements in travel, scheduling, appointment success, and job duration can produce a substantial cumulative increase in workforce capacity.

Kraken Field will replace elements of manual planning with automated optimisation. The system can adjust schedules as jobs change, assign appropriately equipped personnel, reduce unnecessary travel, and provide a more consistent operational view across dispatch and field teams.

Deployment will proceed through controlled pilot phases involving internal teams and early-adopter employees before wider use. Scheduling assumptions, interfaces, workforce processes, and exception handling can therefore be tested against live operating conditions before national expansion.

Around three-quarters of British homes now have smart meters. Work across the remaining programme is increasingly weighted towards harder-to-access properties, non-communicating equipment, upgrades, faults, and installations where the first visit did not produce a completed and functioning system.

Calisen owns or manages approximately 16 million meters, including around 40% of smart energy meters in UK homes. Its wider workforce totals approximately 1,500 people, placing field-service performance at the centre of its infrastructure operation.

Installation volume becomes asset management

Early smart-meter deployment was dominated by new installation activity, while a mature fleet creates a more varied workload involving communications faults, device replacement, configuration issues, changing network coverage, customer access, safety checks, and coordination with solar, storage, EV charging, and flexible tariffs.

Each appointment therefore needs to be treated as a technical intervention rather than a generic field visit. Required competence, equipment, access time, and diagnostic information can vary according to the meter type, communications arrangement, property, supplier, and fault history.

Automated scheduling can improve first-time completion only where the underlying data are accurate. Skills records, equipment availability, stock, travel time, appointment duration, property constraints, meter type, and previous job history all influence the quality of the resulting plan.

An algorithm working from incomplete information may produce an efficient schedule that fails in practice. Data governance and operational feedback are therefore as significant as the optimisation method used to arrange the work.

The deployment sits within a wider expansion of electricity-system data infrastructure. Elexon’s forthcoming Smart Data Repository will make aggregated half-hourly consumption data more accessible for planning, flexibility, and market development, while dependable field assets remain the physical foundation beneath those services.

A meter that cannot communicate or record accurately weakens settlement, tariff operation, demand analysis, and customer participation in flexibility. The consequences extend beyond the individual appointment because data quality propagates into supplier, network, and market systems.

Workforce optimisation also carries a safety and competence dimension. Scheduling must not treat engineers as interchangeable where authorisation, training, or equipment differs, and operational rules must remain binding even when a less suitable assignment appears geographically efficient.

Integration with stock and equipment management can reduce repeat visits caused by missing components, but only where records show what each engineer carries and which replacement equipment is compatible with the installation. Returns, failed devices, firmware versions, and serial-number tracking can all affect asset records.

Travel reduction provides an operational gain where appointments are geographically dispersed. Lower mileage can release productive time, although route optimisation still has to accommodate appointment windows, emergency work, traffic, vehicle charging, and jobs that overrun.

Cybersecurity forms part of the deployment because the platform will hold operational information about infrastructure, employees, appointments, and customers. Access permissions, mobile-device security, integrations, audit logs, and incident response need to be established before workforce processes become dependent on the system.

Resilience will also be required where communications or central services fail. Dispatch teams and field personnel need fallback procedures that allow urgent or already assigned work to continue without compromising safety, records, or customer information.

The partnership reflects a broader movement within utilities from isolated software tools towards common operating platforms spanning customer, asset, and field activity. Consolidation can reduce duplicate data and manual hand-offs, but it also raises the operational significance of system availability, data quality, and controlled software changes.

Britain’s smart-meter programme is no longer defined only by the number of devices installed. Performance increasingly depends on whether meters remain connected, accurate, maintainable, and capable of supporting an electricity market built around more granular data.

Calisen’s deployment targets the operational layer responsible for maintaining that physical fleet as the workload becomes more technically varied. Successful implementation will depend on combining optimisation with accurate asset records, workforce competence, dependable field equipment, and processes capable of handling the exceptions that remain unavoidable in live electrical installations.