June 11, 2026
Storage has been moved from add-on to anchor. Here’s how to build the muscle to develop and install commercial battery projects.
By Tim Montague | For much of the past decade, C&I solar installers have viewed battery storage as a value-add. That era is over. In 2026, storage will become THE DEAL at a growing number of C&I locations, and in areas with high demand for charging points, the battery often provides more economic value than the PV array above it. Developing these projects yourself, finding the customer, structuring the financing and controlling the work through commissioning, that is where the value lies.
The 3 forces driving the shift
Ask for costs. For medium to large commercial customers, peak demand charges can be 30 to 70 percent of the monthly bill. A properly sized battery can reduce peak demand by 20 to 50 percent, with total bill reductions of 10 to 20 percent typical if demand management and runtime are both modeled.
Resilience. Reliability is what you do when the grid is up and running, and that’s what VPPs compensate for. Resilience is what you do when the grid goes down, and there is currently no US market mechanism that pays for this as a service.
The value stack: Earn, save, protect
The clearest way to map battery storage for a C&I customer is through three questions: What can it deliver? What can it save? and…What does it protect?
Earn includes revenues from the wholesale and network services markets. In California, ISO-NE, NYISO and PJM, behind-the-meter batteries can make money from capacity markets, demand response programs and ancillary services such as frequency regulation and rotating reserves. In California, that stack includes Demand Side Grid Support, Base Interruptible Program and Emergency Load Reduction Program, plus resource adequacy contracts with community choice aggregators (CCAs), or IOUs. Resource adequacy works like this: the battery owner commits to making a certain number of kilowatts available during peak periods, and the CCA or IOU pays a monthly fee per kilowatt of committed capacity. Practitioners estimate that at about $4.50 per kW-month, although real-world performance is closer to 90 percent of rated capacity, so model the discount.
To rescue is often where the biggest bucks live. A well-sized battery with good control software can systematically handle peaks in demand, and the savings increase as you optimize runtime and increase self-consumption of solar energy. A 250 kW solar-only project in Rockford, Illinois (PJM area) had a payback period of 4.3 years and an ROI of $215,000. Adding a 530 kW battery increased the IRR from 13 percent to 21 percent, increased the NPV from $158,000 to $486,000, and increased total savings over 15 years from $216,000 to over $1 million.
Protect is where the conversation often ends. G&W Electric in the Chicago area absorbed up to $250,000 per temporary outage, with as many as 12 per year. A solar microgrid, batteries and flywheels completely eliminated these losses. Backup power and island value are very location specific, but for the right customer they pale in pro forma.
Optimizing all three categories requires analysis of the load profile at the 8,760-hour level, accurate system sizing, and control algorithms that most EPCs cannot model on their own. Software and analytics partnerships are now part of the product.
Building the business around storage
Adding storage space to your practice is not a product decision, but an operational decision. Here’s what the restructuring around it looks like.
Storage design and technology. Work closely with SaaS partners and specialty integrators to understand what load profiles will occur and how to size systems relative to the facility load and any existing solar.
Financing. Start with the host’s existing banking relationships for host-owned deals, and know which green banks to turn to if their lender won’t finance it. Third-party ownership is also feasible, with the TPO offering an energy services agreement structured similarly to a solar PPA. Ongoing relationships with tax equity providers and TPO lenders give you flexibility when the deal requires it.
Code and security. NFPA 855 (2026 Edition) now requires a Hazard Mitigation Analysis at virtually every location. NFPA 69 now provides the design basis for explosion control and replaces NFPA 68. UL 9540A adds a large-scale fire test at the installation level. Most states are still working on the 2020 edition, but boards are increasingly requesting compliance with the current edition, so reference both in your documentation.
Subcontractor bank. Qualified commercial electricians and commissioning engineers are limited and strict. Secure strong subs with battery experience now.
Vertical focus. Pick two or three markets and go deep. Generalists lose to specialists in commercial work.
Call the fire brigade in time
The involvement of the fire brigade is part of the concept and pre-application, not of commissioning. The fire chief must answer community questions about your project during the system’s twenty-year lifespan, and showing up at the eleventh hour with an OEM brochure is the quickest way to turn a neutral chief into an adversary. The emergency response plan must be site specific, operationally usable at 2 a.m. in the rain, and short enough to actually be read.
Expect questions about battery fires like Moss Landing, Warwick and McMicken at public hearings. Involve them in fact and leave out the “this product can’t fail” talk. It also helps to know your chemistry: LFP is now the dominant cell technology in C&I storage and is significantly less sensitive to thermal overflow than NMC. That is a legitimate and honest part of the story that needs to be told.
Develop the Pproject yourself
Treat every opportunity like a small development deal. Qualify from 12 months interval data and the rate before the site visit. Most installers new to storage default to a simple model to reduce demand costs and associated size. That gives you a number, but it is often the wrong number and revenue is left on the table.
The advanced approach stacks all three use cases in the same model. Demand cost management, backup duration, and VPP participation each pull the system design in different directions, and going wrong in either direction costs the customer money. Too big for backup and you spend too much on hardware. Below par for VPP and you are leaving the annual income unused. The pro forma is where these tradeoffs are resolved.
The other half of self-development is the software layer. Earning, saving and protecting at the same time requires a control platform that optimizes all three in real time. That means partnering with a BESS software or VPP aggregation company that brings tax forecasting, shipping algorithms, and market enrollment under one roof. The battery is the hardware; the software ensures that the value stack performs.
The deeper shift is identity
Installers who build storage self-development competency do not add a product line. They become developers of distributed energy infrastructure, with recurring customer relationships, network services revenues and long-term energy management responsibilities. Companies that make the transition this year determine their activities for the coming decade. She outsources the rest.
About the author: Tim Montague is chairman of Clean Energy Advisory Group and host of the Clean energy hour podcast, with more than 400 episodes interviewing leading practitioners in solar, storage and clean energy. He advises solar EPCs and developers on scaling into the C&I solar and storage markets. He is a WSI-certified AI consultant, HeatSpring instructor, and author of Wired for Sun: The Commercial Solar Playbook (2025). Reach him at tim@cleanpowerhour.com
Tags: battery systems, BESS, commercial and industrial, energy storage
