Utilities · Grid operations and DER management software
Operations says yes. The money waits for the regulator.
You sell grid operations, outage or DER management software to network operators. The money comes from US rate cases and price controls in Britain and the EU, so a programme left out of the plan waits for the next one. At US IOUs, finance then asks for a capitalisable option after operations has chosen you.
- Typical deal (DERMS)
- €100k–2M a year Illustrative
- Sales cycle (US IOUs)
- About 15 months Illustrative
- Buying group
- 6–12 people Illustrative
Updated 5 October 2026 · Based on Panelhop research, October 2026
At a US investor-owned utility6–12 people Illustrative
The short answer
How do grid software vendors sell to utilities and DSOs?
Grid software vendors sell ADMS, OMS, SCADA and DERMS to utilities on the regulator’s calendar. US investor-owned utilities, British DNOs and large European DSOs fund it through rate cases and price controls; co-ops and public power buy on peer references and board votes. Vendors should enter the rate filing, business plan or budget early and map finance and regulatory affairs.
Grid operations and DER management software · How a deal really moves
Grid deals wait on the filing and the order. In between, the pilot drifts and finance asks for capex. The same deal, on the regulator’s calendar. Filing windows watched weekly, commit forecast by milestone.
One network operator, 6–12 people, a regulator’s order and about 15 months per deal at US IOUs, by our estimate.
What opens a deal
- Rate case (GRC) order: Regulation · US
- RIIO-ED3 plans, December 2026: Regulation · UK
- Rising US utility capex: Budget · US
- Wildfire plan approval: Regulation · US
- New COO or CIO: Leadership · US
- §14a controllable devices: Regulation · DE
Signal Desk · weekly: In-market accounts, scored and mapped
Your buyer and who decides
A network operator
US IOU, DNO, large DSO or public power
5 DNOs in Britain · 191 large DSOs ACER tracks
Panel Check · coverage baselined
- Operations executive, can Veto: Cost overruns the regulator later disallows.
- Finance, can Veto: SaaS booked as opex with no return.
- CIP and OT security, can Veto: An audit finding traced back to a new vendor.
- IT and architecture, can Veto: Another platform that needs scarce integrators.
- Control room manager: A cutover in the middle of storm season.
- Grid modernisation lead: A pilot with no production budget behind it.
- Regulatory affairs: Intervenor challenges and disallowed costs.
- Procurement, can Veto: A procurement challenge on a large award.
How the deal moves
Programme planning
- Where it stalls
- Your programme isn’t in the rate filing
- With Panelhop: Signal Desk
- Filing dates, plan windows and grid hires scored weekly, with a brief
Rate filing Typical time: about a year
Pilot Typical time: 3–12 months
- Where it stalls
- Pilot extended again, still no budget owner
- With Panelhop: Leak Fix
- A pilot needs a budget owner, feeder-level criteria and a scale-up date
Requirements and RFP Typical time: 2–6 months
Evaluation Typical time: 1–3 months
- Where it stalls
- Finance asks for a capex version at the end
- With Panelhop: Leak Fix
- Finance, regulatory affairs and CIP compliance mapped before scoring
Security review Typical time: 1–3 months
- Where it stalls
- CIP questionnaires land after the price
- With Panelhop: Leak Fix
- A security owner and a dated task on every deal from discovery
Order and close
- Where it stalls
- Verbal win, waiting quarters for the order
- With Panelhop: Panel Ops
- Deals forecast by regulatory milestone, accuracy reported monthly
Phased deployment
Panel Ops · monthly: Scores and plays tuned against the baseline
Illustrative Source: Stages, seats, triggers and stalls from Panelhop research, October 2026; ACER (European Union Agency for the Cooperation of Energy Regulators); Ofgem; the services as described on the Services page. Note: Durations, panel sizes and cycle lengths are Panelhop estimates from our research, not measurements.
At a glance
| Typical deal (DERMS) | €100k–2M a year Illustrative |
|---|---|
| Sales cycle (US IOUs) | About 15 months Illustrative |
| Buying group | 6–12 people Illustrative |
| Motion | Regulated programme, often pilot-first |
Source: Panelhop research, October 2026. Note: Values marked Illustrative are Panelhop estimates from our research, not measurements.
Grid deals leak between the control room and the regulator.
Where do grid software deals get lost?
Grid software deals are lost when the programme misses the filing or the pilot finds no budget owner. Others are lost when finance meets the deal at the end or a co-op’s existing suite closes the door. Most of these leaks show in the CRM once regulatory dates and ownership type sit on the account.
Where the pipeline leaks: 5 points across 8 stages.
The demo landed, but the money is next cycle
- What you see
- A utility that liked the demo has no money until the next rate case or price control.
- Why it happens
- Nobody tracked filing dates or business plan windows for target accounts.
Stage Programme planning
Co-ops say their suite or G&T already covers it
- What you see
- Co-op prospects say their existing suite or their G&T already covers OMS and SCADA.
- Why it happens
- Co-ops aren’t tiered by G&T and current suite, and no nearby co-op reference is lined up.
Stage Programme planning
Grid pilots get extended, not put into production
- What you see
- Grid pilots are extended again and again with no production decision.
- Why it happens
- Operations and IT weren’t engaged, and no scaling budget was named before the pilot.
Stage Pilot
Finance wants it capitalised after operations chose you
- What you see
- A late request to restructure the deal as a licence plus capitalised implementation.
- Why it happens
- The deal ran through operations alone; finance and regulatory affairs were never mapped.
Stage Evaluation
Grid commit slips with no competitor in sight
- What you see
- Grid deals marked commit slip with no competitive loss.
- Why it happens
- CRM stages carry no docket number or expected order date.
Stage Order and close
Rate orders, price controls and rising demand fund grid software.
What triggers a utility to buy grid or DER software?
A utility buys grid or DER software when a rate order or price control funds it, a rule requires it or rising demand lifts its capex plan. Wildfire plans in the western US and Germany’s §14a rules on controllable devices are such rules. None of the 20 utility vendors Panelhop analysed ties an offer, on the website pages we read, to a dated regulatory trigger such as RIIO-ED3 business plans.
The 6 events that open or close the window for a deal.
Regulation
Rate case (GRC) orders
- What happens
- A state commission order authorises an IOU’s grid capex, O&M or cloud cost deferral.
- Where to spot it
- State commission dockets, orders and press releases.
- Window
- Approved spend usually follows within 12 months, by Panelhop’s estimate.
Regulation
RIIO-ED3 business plans
- What happens
- Britain’s 5 DNOs, covering 14 licence areas, submit ED3 business plans in December 2026.
- Where to spot it
- Ofgem’s ED3 publications and each DNO’s business plan consultations.
- Window
- A vendor’s influence on a DNO’s plan is highest before submission; Ofgem decides by the end of 2027, and buying follows as the price control starts on 1 April 2028.
Budget cycle
Rising US utility capex
- What happens
- US investor-owned utilities project $238.8bn of capex for 2026, up 17%, as electricity demand rises.
- Where to spot it
- EEI data and each utility’s capex plan updates after rate orders.
- Window
- Open while capex plans stay high; capital-heavy plans favour software deals that can be capitalised.
Regulation
Wildfire mitigation plan approvals
- What happens
- Western US commissions approve multi-year wildfire plans that fund situational awareness and risk modelling.
- Where to spot it
- State commission and wildfire safety dockets.
- Window
- Spend follows approval, with annual plan updates.
Leadership
New COO or CIO at a network operator
- What happens
- A new operations or IT executive at a network operator reviews the grid roadmap and its vendors.
- Where to spot it
- SEC filings and appointment announcements.
- Window
- The new leader’s first 3–12 months, by Panelhop’s estimate.
Regulation
Controllable devices under §14a EnWG
- What happens
- Under §14a EnWG, German DSOs may dim heat pumps, private EV chargers and similar devices connected since 1 January 2024 when the grid is congested, so they need monitoring, control and metering upgrades.
- Where to spot it
- BNetzA rulings and monitoring reports, and DSO tenders for control platforms.
- Window
- Ongoing: DSOs reported 264,874 market locations with controllable devices under the new rules at the end of 2024.
Regulatory affairs holds no veto but shapes the funding.
Who signs off on grid software at a US investor-owned utility?
Grid software is signed off by the operations executive, finance, IT, CIP compliance and procurement, with the control room and grid modernisation team as users. Regulatory affairs decides whether the spend goes into the rate case.
At a US investor-owned utility, 6–12 people sit on the panel and 5 seats can stop the deal.
At a US investor-owned utility: 6–12 people
Operations executive
Can Veto
VP Distribution Operations · SVP Utility Operations
- Cares about
- Reliability results the regulator tracks.
- Worries about
- Cost overruns the regulator later disallows.
Control room manager
Distribution Operations Manager
- Cares about
- One operational view through storms and switching.
- Worries about
- A cutover in the middle of storm season.
Grid modernisation lead
Chief Digital Officer
- Cares about
- Turning a pilot into a funded programme.
- Worries about
- A pilot with no production budget behind it.
Regulatory affairs
VP Regulatory Affairs · Rate Case Manager
- Cares about
- Spend that fits the next rate case.
- Worries about
- Intervenor challenges and disallowed costs.
Finance
Can Veto
CFO · Controller
- Cares about
- Capitalisable spend that earns a return.
- Worries about
- SaaS booked as opex with no return.
CIP compliance and OT security
Can Veto
CIP Senior Manager · OT Security Lead
- Cares about
- Supply-chain evidence for systems tied to the bulk electric system.
- Worries about
- An audit finding traced back to a new vendor.
IT and architecture
Can Veto
CIO · Enterprise Architect
- Cares about
- Integration with GIS, AMI, CIS and SCADA.
- Worries about
- Another platform that needs scarce integrators.
Procurement
Can Veto
Category Manager
- Cares about
- A competitive award that survives challenge.
- Worries about
- A procurement challenge on a large award.
The control room wants it; the regulator funds it.
Who buys grid operations and DER software?
Grid operations and DER software is bought by distribution operations and grid modernisation leaders, funded through regulated revenues at large operators and through board-approved budgets at co-ops and public power. Across the 191 large DSOs ACER tracks in 26 countries, annual investment reached about €35.3bn in 2024 and is expected to hit €46.7bn by 2027.
What vendors of this type sell
- ADMS and distribution management
- Outage management systems (OMS)
- SCADA and substation automation
- DERMS, flexibility and controllable-load platforms
- Grid edge sensing and network models
Which utilities buy it
- US investor-owned utilities
- DNOs in Great Britain
- Large public power utilities
- Large European DSOs
- US distribution co-ops and G&Ts, mainly for OMS and SCADA
Grid deals begin in the regulatory filing.
How does a grid software deal move at a regulated utility?
A grid software deal moves from programme planning into a rate case or business plan, then pilot, RFP, evaluation and security review. It closes when the commission order or price control determination lands. The longest waits sit with the regulator.
Stage by stage: what you do, what the utility does, and what changes at the 5 stages where deals stall.
| Stage | What you do | What the utility does | Today | With Panelhop |
|---|---|---|---|---|
| Programme planning | Briefs engineering and planning teams ahead of the filing. | Grid modernisation and regulatory teams decide what goes into the plan. | Filing windows are found after the plan is submitted. Stalls: Left out of the plan. A grid programme missing from the rate filing or business plan has to wait for an uncertainty mechanism or the next cycle. | Filing dates, plan windows and grid modernisation hires scored weekly per account, each with a brief. Signal Desk In-market accounts, weekly |
| Rate filing Typical time: about a year for a US rate case | Supplies benefits evidence fit for a regulatory filing. | Files the rate case or business plan and defends it while selection runs. | No CRM field for a docket or a business plan. | Docket, filing and expected order dates as fields on every grid opportunity. Leak Fix We build the fixes |
| Pilot Typical time: 3–12 months | Runs a pilot with the innovation team. | Tests the software on a feeder or region before committing. | Grid pilots start with no owner for the production decision. Stalls: Pilot purgatory. Grid pilots sit with innovation teams that lack production budget, so a successful pilot doesn’t become a rollout. | A grid pilot can’t move without a production budget owner, feeder-level success criteria and a scale-up date. Leak Fix We build the fixes |
| Requirements and RFP Typical time: 2–6 months | Answers an RFP often shaped by the incumbent or a consultant. | Writes requirements with IT and integrators, then tenders. | Grid RFPs land with whoever opens the portal alert. | Grid tenders and consultant procurements matched to each target account and assigned to a named owner as a CRM task. Signal Desk In-market accounts, weekly |
| Evaluation Typical time: 1–3 months | Demos on the utility’s own network model and data. | Scores bids, while finance asks whether the spend can be capitalised. | Operations champions the deal alone. Stalls: The opex objection arrives late. At US IOUs, finance and regulatory affairs, absent from discovery, push for a capitalisable on-premises option after operations has chosen. | Finance, regulatory affairs and CIP compliance mapped on the account before scoring. Leak Fix We build the fixes |
| Security review Typical time: 1–3 months | Answers NERC CIP supply-chain questionnaires and provides an SBOM. | Rates the vendor’s supply-chain risk before contract. | CIP questionnaires arrive after the price is agreed. Stalls: Security review starts after selection. Questionnaires for systems tied to the bulk electric system arrive after the price is agreed and add weeks at the end. | A security owner and a dated task on every grid opportunity from discovery onwards. Leak Fix We build the fixes |
| Order and close | Waits for the commission order before signature. | Signs once the order or final determination lands. | Commit is a judgement call. Stalls: Verbal win, no order. Large grid purchases often wait for the commission order, so a verbal award sits in commit for quarters. | Grid deals forecast by regulatory milestone, with forecast accuracy reported monthly against the baseline. Panel Ops We run it monthly |
| Phased deployment | Deploys in phases and proposes new feeders, regions or modules. | Expands as later rate cases and price controls allow. | Next phases wait for the customer to ask. | Phase and region expansion tracked as triggers on each customer, checked in the weekly signal review. Panel Ops We run it monthly |
Put the regulatory dates on the opportunity.
How does Panelhop change a grid software pipeline?
Panelhop puts each account’s filing and plan windows on the opportunity, maps finance and regulatory affairs before scoring and forecasts grid deals by regulatory milestone. A Panel Check (GTM audit) first baselines signal-to-first-touch time and stage conversion from your own CRM data. Your team keeps every relationship and every first touch.
What we baseline and report
- Target accounts where your programme is in the filing or business plan
- Grid opportunities with finance and regulatory affairs engaged before scoring
- Commit slippage against commission order and determination dates
Other vendor types in utilities.
What other vendors sell to utilities?
The same utilities buy from these vendor types too, through different panels and pipelines.
- Vendor type
Customer information and billing systems
CIS, billing, portals and rate engines for US public power, co-ops, IOUs and water utilities, UK water companies and German Stadtwerke.
Read the pipeline - Vendor type
AMI, meter data management and analytics
Smart meter networks, head-end systems, MDM and analytics for municipal, co-op and investor-owned utilities and German meter operators.
Read the pipeline - Vendor type
Asset, GIS and field workforce platforms
Network GIS, asset management, joint use, vegetation and mobile workforce software for electric, gas and water utilities.
Read the pipeline - Vendor type
OT security and cyber compliance
OT monitoring, vulnerability management, ISMS and NERC CIP compliance tools for utilities, Stadtwerke and DSOs.
Read the pipeline
The words your buyers use, defined.
What do terms like “ADMS (advanced distribution management system)” and “DERMS” mean?
Plain definitions of the terms that come up when you sell grid operations and DER management software to utilities.
- ADMS (advanced distribution management system)
- Control-room software that combines network monitoring, switching, outage handling and distribution analysis in one operational view.
- DERMS
- Distributed energy resource management system: software that forecasts, monitors and dispatches solar, batteries, EV charging and flexible loads on the distribution grid.
- Rate base
- The capital a US utility may earn a return on. Capitalised software can enter the rate base; SaaS booked as opex usually can’t, which shapes how IOUs buy.
- Uncertainty mechanism
- A route in Ofgem’s price controls to fund spending that wasn’t certain enough for the original business plan. It is slower and less certain than plan inclusion.
- Prudency review
- A regulator’s check that a utility’s spending was reasonable. Costs found imprudent can be disallowed, so utilities want benefits evidence they can file.
- OMS (outage management system)
- Software that predicts outage locations from customer calls and meter events, dispatches crews and tracks restoration. It is often bought alongside or inside an ADMS.
Answers before your next utility deal.
What do vendors of grid operations and DER management software ask about selling to utilities?
How do you get grid software into a DNO’s RIIO-ED3 business plan?
To get grid software into a DNO’s RIIO-ED3 business plan, engage its network, digital and regulation teams before plans are submitted in December 2026. Bring benefits evidence fit for the plan. Britain has 5 DNOs covering 14 licence areas, so a grid vendor can plan each DNO account by account and map every seat in its buying group.
How do you sell SaaS grid software to an IOU when cloud is opex?
Selling SaaS grid software to a US investor-owned utility means bringing finance and regulatory affairs in early. SaaS booked as opex usually earns no return, while capitalised software can. Grid vendors respond by structuring capitalisable implementation work, citing state precedents for cloud cost recovery and timing the deal to the utility’s next rate case.
Why do utility grid software pilots stall?
Utility grid software pilots stall because they sit with innovation teams that have no production budget. Operations and IT are often not engaged, and nobody agreed a scale-up date or the system the pilot would replace. Grid vendors should make a budget owner, success criteria and a decision date conditions of starting any utility pilot.
How long does it take to sell ADMS or DERMS software to an investor-owned utility?
Selling ADMS or DERMS software to a US investor-owned utility takes about 15 months by Panelhop’s estimate, with a range of 6–36 months. Large purchases often wait for a rate case or commission order, and CIP supply-chain review adds time at the end. Grid vendors should forecast these deals by regulatory milestone, such as a docket’s expected order date.
How do you sell grid software to European DSOs?
Selling grid software to European DSOs starts with tiering, because 92% of European DSOs serve fewer than 100,000 customers and many lack the scale for enterprise systems. ACER, the EU agency for energy regulators, tracks investment at 191 large DSOs in 26 countries. Grid vendors should target those large DSOs directly and reach smaller DSOs through municipal utility networks and partners.
How do grid software vendors sell OMS and SCADA to electric co-ops?
Grid software vendors sell OMS and SCADA to US electric co-operatives through peer references and a vote of the co-op board. Many co-ops say their existing suite or their G&T already covers outage management and SCADA. Grid vendors do better by tiering co-ops by G&T and current suite, then leading with a reference from a nearby co-op of similar size.
Where the numbers come from.
Sources
Sourced figures link to their source below. Figures marked Illustrative, and figures given as estimates, are inferred from Panelhop research. Vendors appear only as types, never by name.
- ACER (European Union Agency for the Cooperation of Energy Regulators), Managing the ramp-up of electricity distribution investments to better serve grid users (report on DSO revenue setting practices) (2026)
- Edison Electric Institute (Electric Perspectives), EEI Data: Electric Companies to Invest $1.4T to Support Customers, Power Growth (2026)
- Ofgem sets rules for 2028 to 2033 grid investment to meet growing electricity demand (2026)
- Bundesnetzagentur and Bundeskartellamt, Monitoringbericht 2025 (2025)
- Bundesnetzagentur, Integration von steuerbaren Verbrauchseinrichtungen (2026)
- Panelhop research, October 2026: our analysis of the vendors, buying panels, pipelines and triggers for grid operations and DER management software in utilities, from public sources. Vendor names are not published.
