Custom software for energy and utility companies — energy management systems, SCADA integration, regulatory compliance tools, and renewable energy portfolio management for operators who need more than generic utility software. FreedomDev builds the systems that connect field devices to control rooms to boardrooms, with full NERC CIP compliance and real-time operational visibility across generation, transmission, and distribution assets.
An energy management system for a mid-size utility or independent power producer is not a dashboard — it is the operational backbone that balances generation against load, manages fuel procurement against forward contracts, dispatches assets based on marginal cost and grid constraints, and reports every megawatt-hour to FERC, the regional ISO, and state PUC regulators. The EMS must ingest real-time telemetry from SCADA systems monitoring substations, generating units, and distribution feeders. It must correlate that telemetry with market signals from ERCOT, PJM, MISO, CAISO, or whichever ISO/RTO operates the grid your assets connect to. It must produce the settlement-quality meter data that determines how much revenue you earn — or how much you pay in imbalance penalties. And it must do all of this while maintaining the cybersecurity posture that NERC CIP standards require for bulk electric system assets. Most utilities run a patchwork of vendor systems — GE's EMS/SCADA platform for operations, Oracle Utilities for billing, SAP for financials, PI System for historian data — connected by manual processes and overnight batch files that introduce 12-to-24-hour delays in data that should flow in seconds.
The gap between what vendor platforms provide and what energy companies actually need grows wider every year. Distributed energy resources — rooftop solar, battery storage, demand response aggregations, EV charging networks — have turned the traditional one-directional grid into a bidirectional system that legacy EMS platforms were never designed to manage. FERC Order 2222 requires ISOs and RTOs to allow DER aggregations to participate in wholesale markets, which means utilities and aggregators need software that can model, forecast, optimize, and settle DER portfolios in near-real-time. A 500 MW gas-fired combined cycle plant dispatches on a single set of heat rate curves and ramp constraints. A 500 MW DER portfolio comprising 12,000 residential solar systems, 3,000 battery storage units, and 50 commercial demand response sites dispatches on 15,050 individual device constraints, weather forecasts, customer opt-out preferences, and state-specific net metering rules. The software complexity is orders of magnitude higher, and the generic EMS cannot handle it.
FreedomDev builds energy management software for companies operating in this complexity. We understand SCADA protocols — DNP3 (IEEE 1815), IEC 61850, Modbus TCP/IP, OPC UA — because we have built integration layers that pull real-time data from substations, generating units, and field devices into unified operational platforms. We understand energy market structures because we have built settlement engines that calculate locational marginal pricing exposure, congestion costs, and capacity market obligations for generators operating in PJM and MISO. We understand regulatory compliance because we have built systems that produce FERC Form 1 data, NERC CIP evidence artifacts, and state PUC rate case exhibits from the same operational database. Our stack — .NET backend, SQL Server for transactional data, React for operator interfaces, and time-series databases for historian data — is purpose-built for the high-throughput, high-reliability demands of energy operations. We are not a SCADA vendor and we are not an EMS vendor. We are the company that builds the custom software layer between your operational technology and your business systems.
The U.S. electric utility industry generates approximately $470 billion in annual revenue and serves 156 million customers across 3,300 utilities. The average utility manages infrastructure installed over a 40-year span, with control systems, metering platforms, and business applications from different vendors deployed in different decades. Duke Energy operates assets across six states with different regulatory structures. Xcel Energy manages a generation portfolio spanning coal, natural gas, nuclear, wind, and solar across eight states. NextEra Energy runs the largest wind and solar portfolio in the world alongside Florida Power & Light's regulated utility operations. Each of these companies — and the hundreds of mid-size municipal utilities, cooperatives, and independent power producers that operate alongside them — faces the same fundamental software challenge: connecting operational technology that speaks SCADA protocols to information technology that speaks REST APIs, and making both layers comply with NERC CIP cybersecurity standards that treat the boundary between OT and IT as the most security-critical zone in the entire infrastructure.
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A typical mid-size utility operates SCADA infrastructure deployed across three or four decades. Substations commissioned in the 1990s run RTUs communicating over serial DNP3 on leased telephone lines. Substations upgraded in the 2010s use IEC 61850-based protection relays with GOOSE messaging on fiber-optic Ethernet. Generating units run proprietary DCS platforms from Emerson, Honeywell, or ABB — each with its own historian, alarm management system, and interface protocol. Distribution automation devices — reclosers, capacitor bank controllers, voltage regulators — communicate over a mix of cellular, RF mesh, and proprietary radio networks. The result is an operational technology landscape where no single system has a complete picture of what is happening across the enterprise. The control room sees generation through one screen, transmission through another, and distribution through a third — if they see distribution at all. When a weather event or equipment failure cascades across these boundaries, operators spend critical minutes switching between systems and correlating alarms manually. Building a unified operational view requires integration across DNP3, IEC 61850, Modbus, OPC UA, and proprietary APIs — with protocol conversion, data normalization, and timestamp synchronization that preserves the sub-second accuracy required for event sequence analysis.
NERC Critical Infrastructure Protection standards — CIP-002 through CIP-014, plus the low-impact requirements under CIP-003 — impose cybersecurity obligations on every entity that owns, operates, or maintains bulk electric system assets. CIP-002 requires identification and categorization of BES Cyber Systems as high, medium, or low impact. CIP-004 requires personnel risk assessment and security awareness training with documented evidence of completion. CIP-005 requires electronic security perimeters with documented network diagrams showing every access point. CIP-007 requires system security management including patch management, malware prevention, and security event monitoring with 90-day log retention. CIP-010 requires configuration change management and vulnerability assessment. CIP-011 requires information protection for BES Cyber System Information. Every one of these standards requires documented evidence — not just that the control is implemented, but that it has been consistently applied, monitored, and reviewed. NERC auditors from the regional entity (RFC, SERC, WECC, MRO, and others) review three to six years of evidence during a compliance audit. Most utilities assemble this evidence manually from spreadsheets, email records, ticketing systems, and network management tools — a process that consumes thousands of staff-hours per audit cycle and still produces gaps that result in potential violations.
Generators and load-serving entities operating in organized wholesale markets — PJM, MISO, ERCOT, CAISO, ISO-NE, NYISO, SPP — must settle energy, capacity, and ancillary service transactions based on locational marginal prices that change every five minutes. A 1,000 MW generator portfolio operating across multiple nodes in PJM faces LMP basis risk between the node where it generates and the hub or zone where it transacted. Congestion and loss components of LMP can swing settlement values by $5-15/MWh on routine days and $50-200/MWh during scarcity events. Capacity market obligations under PJM's Reliability Pricing Model or MISO's Planning Resource Auction create fixed revenue streams that must be tracked against delivery obligations with performance penalties for non-delivery during emergency conditions. Ancillary services — regulation, spinning reserve, non-spinning reserve — have separate settlement calculations based on mileage signals, deployment duration, and opportunity cost. Most energy companies track these settlements using spreadsheets populated from ISO settlement statements — a process that makes it functionally impossible to identify settlement errors, calculate real-time margin exposure, or optimize dispatch decisions against forward contract positions. The revenue at stake is significant: a 500 MW combined cycle plant generates $150-250 million in annual energy and capacity revenue, and a 1% settlement error is $1.5-2.5 million.
Wind and solar generation are weather-dependent resources that produce power based on meteorological conditions, not operator dispatch commands. A 200 MW wind farm in Iowa may produce 70 MW at 8 AM, 180 MW at 2 PM, and 40 MW at midnight — and the hour-ahead forecast may be off by 15-30% on days with shifting weather fronts. Solar generation follows a more predictable diurnal pattern but is subject to cloud transients that can drop output from 100% to 20% in minutes. Utilities and independent power producers with large renewable portfolios must integrate weather forecast data from multiple providers (DTN, Vaisala, Meteologica), blend those forecasts with historical production data to produce calibrated generation forecasts, and submit those forecasts to the ISO for scheduling and settlement purposes. Forecast errors result in imbalance charges — the ISO procures real-time energy to fill the gap between your scheduled and actual output, and you pay the difference at real-time prices that are typically higher than day-ahead prices. For a 1,000 MW wind portfolio, improving forecast accuracy by 5 percentage points can reduce imbalance costs by $2-4 million annually. The software challenge is combining meteorological data, SCADA production data, turbine availability status, curtailment signals, and market price forecasts into a single optimization engine that updates dispatch and scheduling decisions continuously.
The average age of a U.S. power transformer is over 40 years, and the American Society of Civil Engineers gives the U.S. energy infrastructure a C- grade. Utilities manage tens of thousands of assets — transformers, breakers, switches, poles, conductors, capacitor banks, voltage regulators — each with different failure modes, maintenance schedules, and replacement costs. A large distribution transformer costs $3-8 million and has a lead time of 12-24 months. A catastrophic failure during a summer peak event affects thousands of customers and triggers regulatory scrutiny from the PUC. Most utilities track asset condition in GIS (Esri ArcGIS), maintenance history in their work management system (Maximo, SAP PM, Oracle WAM), and operational loading in SCADA — three systems that do not share data. An asset manager looking at a transformer replacement decision cannot see the loading history from SCADA, the dissolved gas analysis trends from the lab, and the maintenance history from the work management system in a single view. They export data from three systems into a spreadsheet and make a judgment call. Building a predictive asset management platform requires integrating GIS, SCADA historian, work management, and condition monitoring data into a unified asset health scoring model that identifies the transformers, breakers, and conductors most likely to fail and prioritizes capital investment accordingly.
Investor-owned utilities operate under cost-of-service regulation, meaning they must justify their revenue requirements to state public utility commissions through rate case proceedings. A general rate case filing includes thousands of pages of testimony, workpapers, and exhibits documenting the utility's costs, rate base, depreciation schedules, load forecasts, and requested return on equity. The data behind these filings comes from every system the utility operates: generation costs from the EMS and fuel procurement system, transmission and distribution costs from the work management and GIS systems, customer data from the billing system, financial data from the ERP, and capital investment plans from the asset management system. Assembling this data into regulatory exhibits typically takes 6-12 months and dozens of staff across finance, engineering, operations, and regulatory affairs. Interrogatories from PUC staff and intervenors generate hundreds of data requests that must be answered with supporting documentation traceable to source systems. A single inconsistency between a workpaper and a data request response can undermine the credibility of the entire filing. Municipal utilities and cooperatives face similar reporting obligations to their governing boards and members, often with smaller staff and fewer resources to compile the data.
We were running five different SCADA systems across our generating fleet and distribution territory — none of them talked to each other, and our NERC CIP compliance team spent half their time manually assembling evidence from different platforms. FreedomDev built an integration layer that gave us a unified operational view and automated our CIP evidence collection. Our last NERC audit took three weeks instead of three months, and we had zero potential violations for the first time in the company's history. The system paid for itself in avoided compliance penalties within the first audit cycle.
A unified operational data platform that integrates SCADA telemetry from every generation, transmission, and distribution asset into a single real-time view — regardless of the underlying protocol. FreedomDev builds protocol translation layers that normalize data from DNP3 (IEEE 1815), IEC 61850, Modbus TCP/IP, OPC UA, and vendor-proprietary interfaces into a common data model with consistent naming, units, and quality codes. Time-series data flows into a historian (OSIsoft PI, AVEVA PI, or open-source alternatives like TimescaleDB) with sub-second resolution and years of retention. Real-time dashboards built in React give operators, dispatchers, and managers the view appropriate to their role — control room operators see one-line diagrams with live telemetry and alarm status, asset managers see equipment loading trends and threshold violations, and executives see fleet-level generation and reliability KPIs. Alarm management follows ISA-18.2 standards: alarm rationalization, prioritization, suppression logic, and shelving — eliminating the alarm floods that desensitize operators during high-stress events. This systems integration layer connects your OT infrastructure to your IT business systems while maintaining the network segmentation and access controls that NERC CIP-005 requires at the electronic security perimeter boundary.
Learn moreA purpose-built compliance management platform that automates evidence collection, tracks control implementation, and produces audit-ready documentation for NERC CIP-002 through CIP-014. The system maintains your BES Cyber System inventory with impact ratings (high, medium, low), maps each system to applicable CIP requirements, and tracks the evidence artifacts that demonstrate compliance. CIP-004 personnel training: automated tracking of security awareness training completion with role-based training requirements mapped to individual employees and documented evidence of background investigations. CIP-005 electronic security perimeter: automated network diagram generation from your firewall and switch configurations, with change detection that flags unauthorized access points. CIP-007 patch management: integration with your vulnerability scanning tools to track applicable patches, document patch evaluation decisions, and record installation evidence with before/after configuration snapshots. CIP-010 configuration management: baseline comparison for BES Cyber Systems with automated change detection and documented authorization workflows. Every evidence artifact is timestamped, version-controlled, and indexed by standard, requirement, and audit period — so when the regional entity auditor requests three years of CIP-007 R2 evidence, the response is a filtered export, not a three-month document assembly project. FreedomDev builds this on the compliance management patterns we have refined across regulated industries.
Learn moreCustom settlement verification and revenue analytics systems for generators, load-serving entities, and energy traders operating in ISO/RTO wholesale markets. The platform ingests settlement statements from PJM, MISO, ERCOT, CAISO, ISO-NE, NYISO, or SPP, parses every charge code and line item, and reconciles against your internal meter data, generation logs, and forward contract positions. Shadow settlement engines recalculate energy, capacity, and ancillary service charges using the same algorithms the ISO uses, identifying discrepancies before the resettlement window closes. Real-time margin dashboards show dispatch-level profitability by unit, node, and market product — so your commercial team sees whether running a peaking unit at current LMP covers its variable cost plus start-up cost, or whether buying from the spot market is cheaper than self-generating. Forward position management tracks your bilateral contracts, capacity commitments, and renewable energy credit obligations against actual and forecasted delivery. Business intelligence dashboards built on Power BI or custom React visualizations give executives portfolio-level views of revenue, margin, and market exposure with drill-down to individual assets and settlement intervals.
Learn moreA portfolio management platform for companies operating wind, solar, battery storage, and hybrid renewable assets across multiple sites and market territories. The system integrates SCADA production data from each site, weather forecast feeds from DTN, Vaisala, or Meteologica, and market data from the relevant ISO to produce calibrated generation forecasts, optimized scheduling bids, and real-time curtailment management. For wind assets: turbine-level availability tracking (IEC 61400-26 categories), wake effect modeling, and production performance analysis that separates weather-driven underperformance from equipment-driven underperformance. For solar assets: inverter-level monitoring with degradation tracking, soiling loss estimation, and clipping analysis. For battery storage: state-of-charge management, cycle counting, degradation modeling, and market arbitrage optimization that maximizes revenue across energy, capacity, and ancillary service markets while respecting warranty constraints on cycling depth and frequency. Renewable energy credit tracking follows each MWh from the meter through REC registration (M-RETS, NEPOOL GIS, PJM GATS, WREGIS), allocation to offtake contracts, and retirement — with full chain-of-custody documentation for voluntary and compliance REC markets. Portfolio-level reporting aggregates across sites and technologies for investor reporting, tax equity compliance, and corporate PPA settlement.
Learn moreAn integrated asset health management system that combines GIS asset location data, SCADA loading history, work management maintenance records, and condition monitoring results (dissolved gas analysis for transformers, partial discharge testing for switchgear, infrared thermography for connections) into a unified asset health scoring model. The platform calculates health index scores for each asset class — transformers, breakers, reclosers, poles, conductors — using weighted algorithms that incorporate age, loading history, maintenance history, condition test results, and environmental exposure. Risk scoring combines health index with consequence of failure (customers affected, load served, environmental sensitivity, regulatory exposure) to prioritize capital investment and maintenance scheduling. Predictive models trained on historical failure data and condition monitoring trends identify assets approaching end-of-life before catastrophic failure occurs. Integration with your GIS provides spatial visualization of asset risk across your service territory, enabling geographic prioritization of capital programs. Work order generation flows directly into Maximo, SAP PM, or your existing work management system. Regulatory reporting produces the asset condition data that PUC filings and reliability improvement plans require.
Learn moreA centralized regulatory data platform that aggregates financial, operational, and customer data from across the utility into a single source of truth for rate case filings, FERC Form 1, state PUC annual reports, and regulatory data requests. The platform pulls cost data from SAP or Oracle Financials, load and generation data from the EMS/SCADA historian, customer and billing data from Oracle Utilities or SAP IS-U, capital investment data from your project management system, and reliability metrics (SAIDI, SAIFI, CAIDI, MAIFI) from your outage management system. Regulatory workpaper templates generate the exhibits, schedules, and supporting calculations that rate case testimony requires — depreciation studies, cost allocation models, revenue requirement calculations, and rate design exhibits. When PUC staff or intervenors submit data requests, the platform traces every number in every exhibit back to its source system and extraction date, producing responses with full audit trail documentation. Version control tracks every revision to every workpaper, so the regulatory affairs team can demonstrate exactly how and why a number changed between the initial filing and the rebuttal. Business intelligence dashboards built with Power BI provide executives with real-time visibility into cost trends, capital spending, and reliability metrics that inform the regulatory strategy well before the rate case is filed.
Learn more| Metric | FreedomDev | Generic SaaS |
|---|---|---|
| SCADA Protocol Integration | Native support for DNP3, IEC 61850, Modbus, OPC UA with unified data model | Single-protocol systems requiring third-party gateways and manual data mapping |
| NERC CIP Evidence | Automated evidence collection indexed by standard, requirement, and audit period | Manual spreadsheet compilation requiring months of preparation before each audit |
| Market Settlement Verification | Shadow settlement engines that catch ISO billing errors before resettlement deadlines | Spreadsheet reconciliation that misses discrepancies until after correction windows close |
| Renewable Forecasting | Multi-source weather integration with calibrated ML models reducing imbalance costs | Single vendor forecast with no site-specific calibration or real-time adjustment |
| Asset Health Scoring | Integrated health index combining SCADA, GIS, work management, and condition monitoring | Age-based replacement schedules disconnected from actual asset condition data |
| Regulatory Filing Support | Traceable workpapers with source-system audit trails for every number in the filing | Manual data extraction into spreadsheets with no traceability to source systems |
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