How a large electric cooperative recovered $3.2M in unbilled revenue and cut compliance reporting from two weeks to three days
$950K
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Annual Ongoing Savings
sustained after initial recovery - operational efficiency gains
85%
Reduction in Regulatory Reporting Time
from 2 weeks to 3 days per cycle - FERC, NERC, and state
$3.2M
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2
3
4
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2
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Unbilled Revenue Recovered
identified by automated anomaly detection before billing runs
Implementing SMART360 was a game-changer for our electric cooperative. The revenue recovery alone justified the investment, but we've also seen dramatic improvements in grid reliability monitoring and regulatory reporting efficiency. What used to take weeks now takes days
Chief Operations Officer
Electric Distribution Company
THE PROBLEM
Revenue leaving through cracks no one could see and compliance consuming staff it couldn't afford
For a cooperative serving 500,000 connections across 450 square miles, revenue leakage isn't a rounding error. It's a structural problem. The Electric Distribution Company knew money was slipping through unbilled usage, missed reads, and metering gaps, but their legacy systems couldn't tell them where, how much, or why. The leakage was real. The visibility to fix it wasn't.
At the same time, regulatory obligations were expanding. FERC, NERC, and state-level reporting mandates require detailed, auditable data submitted on fixed schedules. Without automation, that meant two weeks of staff time every reporting cycle, pulling data manually from disconnected systems, reconciling figures, and formatting outputs to meet regulatory standards. Two weeks of work, repeated every quarter, for compliance that produced no revenue and consumed the team's most skilled people.
Key friction points before SMART360
Unbilled revenue leakage with no system capable of identifying root causes or flagging anomalies before billing runs
Grid reliability metrics tracked manually, outage response was reactive, not data-driven
Regulatory reporting (FERC, NERC, state-level) consuming two weeks of staff time per cycle
Limited customer visibility into outages and usage, driving call volume and dissatisfaction
Growing operational costs with no real-time dashboard to identify where savings were possible
"We recognized significant revenue leakage in our operations, but our systems weren't capable of identifying the root causes. Additionally, our regulatory reporting was consuming excessive staff time and resources."
— Chief Financial Officer, Electric Distribution Company
Why SMART360 and the case for a phased rollout
The cooperative evaluated several platforms before selecting SMART360. The deciding factor wasn't any single feature, it was the combination of an automated billing anomaly engine, built-in regulatory compliance tools, and a field service layer that could connect grid events to customer records in real time. Most platforms addressed one or two of those areas. SMART360 addressed all three in a unified system.
The implementation approach mattered as much as the platform itself. An 8-week phased rollout, starting with a comprehensive system audit before a line of configuration was written, meant the team understood what they had before deciding what to replace. Data migration from seven existing systems was handled in parallel with staff training, so go-live wasn't the start of a learning curve. It was the end of one.
SMART360 MODULES IN USE
Five modules. One platform. Every revenue and compliance gap addressed.
The cooperative didn't implement SMART360 as a billing fix. They deployed it across five operational areas, each one targeting a specific source of cost, leakage, or compliance risk.
Customer Portal & Self-Service
Customers had no visibility into outages or their own usage data — every question became a call center interaction, driving up volume and response costs.
Customer Information System → delivered real-time outage maps, consumption insights, and digital communication channels — driving a 57% increase in customer engagement and a 22% lift in satisfaction scores.
Field Service Management
Outage response was slowed by disconnected field communications — crews had no mobile system for real-time updates, extending time to restore for every grid event.
Work & Service Orders → gave field crews a mobile-first workflow connecting grid events to service orders — improving outage response time by 15% and eliminating manual handoffs between dispatch and field.
Analytics Dashboard
Managers made decisions from stale reports — real-time grid performance data didn't exist, making it impossible to flag anomalies before they compounded into billing errors.
AI & Analytics → provided live dashboards across grid performance, usage patterns, and revenue metrics — cutting reporting time by 85% and enabling a shift from reactive to data-driven operations.
Billing Automation
Unbilled usage went undetected because the billing system had no anomaly engine — metering gaps weren't flagged until after invoices were issued, if at all.
Billings & Payments → automated the full billing cycle with pre-run anomaly detection — recovering $3.2M in previously unbilled revenue and sustaining $950K in annual savings.
Regulatory Compliance Reporting
FERC, NERC, and state mandates required two weeks of manual data gathering per cycle — pulling skilled staff off strategic work for repetitive, high-stakes data assembly.
Automated Compliance Reporting → generates pre-built reports from live data — reducing reporting from two weeks to three days and achieving a 99.2% compliance rate.
THE IMPLEMENTATION
Eight weeks. Four phases. Seven systems integrated.
An 8-week implementation timeline for a 500,000-connection cooperative isn't aggressive, it's disciplined. The phased approach Bynry used with the Electric Distribution Company was designed so that each stage de-risked the next: no training began before data migration was validated, and no module went live before staff had practiced it in a sandbox environment.
Phase 1 · Assessment & discovery
Comprehensive system audit and pain point mapping
Full audit of existing billing workflows, compliance processes, and field operations — identifying the specific sources of revenue leakage and reporting inefficiency before any configuration began.
Phase 2 · Solution design
Customized implementation plan with phased rollout strategy
SMART360 configured to the cooperative's billing rules, grid topology, and regulatory requirements. Integration architecture designed for 7 existing critical systems.
Phase 3 · Data migration & integration
Secure transfer of historical data across 7 connected systems
Historical billing, meter, and customer data migrated securely. All 7 existing systems integrated via cloud-native connectors — zero data loss, full audit trail maintained throughout.
Phase 4 · Training & deployment
Role-based training for all staff levels, then go-live
Comprehensive training delivered by role — billing teams, field crews, compliance staff, and management each trained on their specific SMART360 workflows. Mobile app deployed to field workers before go-live.
RESULTS
$3.2M recovered. ROI in 7 months. Reporting that used to take two weeks now takes three days.
The clearest measure of SMART360's impact is the revenue number: $3.2M in previously unbilled revenue identified and recovered. That's money the cooperative had already earned, it just hadn't been captured. The anomaly detection engine in SMART360's billing module found it systematically, at scale, across 500,000 connections.
$3.2M
unbilled revenue recovered
identified by automated anomaly detection before billing runs
85%
reduction in regulatory reporting time
from 2 weeks to 3 days — FERC, NERC, and state compliance
7 months
to full ROI
from go-live to complete return on implementation investment
$950K
in annual ongoing savings
sustained operational efficiency gains after initial recovery
99.2%
regulatory compliance rate achieved
automated reporting with real-time reliability metrics
22%
increase in customer satisfaction
57% increase in digital engagement across outage maps and self-service
15%
improvement in outage response time
field crews connected to grid events in real time — closing the gap between detection and resolution that had been adding hours to every incident
The compliance story is where staff time was reclaimed most visibly. Two weeks of manual data collection and report assembly, every reporting cycle, redirected to three days of automated generation and review. The skilled engineers and analysts who spent that time on data formatting now spend it on the analysis and strategic planning the data was always meant to enable.
What comes next
With the revenue recovery and compliance baseline now established, the cooperative's roadmap focuses on what the data makes possible: infrastructure lifecycle planning driven by real usage patterns, predictive maintenance scheduling based on grid reliability metrics, and expansion of the customer portal to serve commercial and industrial accounts with more granular consumption analytics.
The $950K in annual savings isn't a one-time figure. As the cooperative's team moves from data collection to data application, using SMART360's analytics to drive maintenance scheduling and capacity planning, the operational savings compound. The platform was built to scale with the cooperative, not to be replaced when it grows.
Utility Name
Electric Distribution Company
SERVICE AREA
450 sq miles, North America
Sector
Electric Utility (Cooperative)
SIZE
500,000 connections
PREVIOUS SYSTEM
None
Pain point
Unbilled revenue leakage, Limited customer visibility into outages and usage, Growing operational costs with no real-time dashboard, Grid reliability metrics tracked manually
