A storage developer approaching your facility is not doing you a favor. They need your property to win a state procurement contract, and the terms they bring you in their first draft are written to protect their revenue, not yours. A battery storage host agreement for commercial and industrial facilities can deliver real value, but only if the operator negotiates dispatch rights, lease economics, and decommissioning terms before the procurement window closes and the developer's leverage grows.

This post is for plant managers, facility managers, COOs, and energy managers at commercial and industrial facilities whose electric bills run five figures a month or more. If a developer has already called, or if you are in a state with hard megawatt storage targets, the procurement calendar is already moving around you. By the end of this post, you will know when a host deal actually works in your favor, when it works against you, and the specific questions to ask before you sign anything.

What a Battery Storage Host Agreement Actually Is

A battery storage host agreement is a contract between your facility and a developer (or utility, or aggregator) that gives that party the right to install, own, and operate an energy storage system on your property. In exchange, you receive some combination of a lease payment, a reduced electricity rate, or a share of the revenue the battery earns in wholesale or retail markets.

The agreement governs more than just the physical installation. It determines who controls when the battery charges and discharges, what happens when the developer's dispatch schedule conflicts with your backup power requirements, how long the contract runs, and who is responsible for removing the equipment when the contract ends.

These agreements show up in three structural forms. Third-party ownership means the developer finances, installs, and owns the system. You provide site access and a long-term contract; the developer captures the equipment economics. Co-ownership means you take an equity stake alongside the developer. You share costs, risks, and returns. Direct ownership means you finance, own, and operate the system yourself. You capture all savings and incentives, and you take all the risk.

The version most C&I operators encounter when a developer comes calling is third-party ownership. That is the structure this post focuses on, because it is the one with the most one-sided first drafts.

Why These Agreements Exist on Paper vs. How They Work in Real Life

On paper, the logic is clean. Ten states have adopted energy storage procurement targets with real megawatt numbers and calendar deadlines: California, Oregon, Nevada, Illinois, Virginia, New Jersey, New York, Connecticut, Massachusetts, and Maine. New York doubled its target to 6 GW by 2030. Virginia set 3,100 MW by 2035. Connecticut has interim deadlines in 2024 and 2027.

When a utility faces a statutory procurement obligation and a hard deadline, it issues RFPs. Developers respond to those RFPs by bidding projects, and projects require physical sites. Your commercial or industrial property is the asset a developer needs to submit a bid. The mandate is the reason they will pay you for site access.

In real life, the operator rarely knows what the developer actually needs. Most C&I operators who receive an approach from a storage developer are negotiating without knowing what leverage they have. The developer knows their procurement deadline. They know their interconnection timeline. They know which sites are interconnection-ready and which require years of queue work. If your site already has large-service interconnection infrastructure, an existing substation, or unused capacity on a solar interconnection agreement, you are materially shortening a developer's path to a bid-ready project. In most non-ERCOT markets, interconnection queues now run multiple years, with significant variation by ISO. That compression is worth money. Most operators give it away without asking.

When a Battery Storage Host Agreement Actually Helps Your Facility

A host deal can work in your favor under a defined set of conditions.

Your site has interconnection infrastructure the developer genuinely needs. Large-service interconnection, an existing substation, or unused solar interconnection capacity compresses the developer's timeline and cost. That compression has a dollar value in your negotiating position.

You are in a state with a hard procurement mandate and an upcoming RFP window. The Illinois example is concrete: Illinois scheduled a procurement event for August 26, 2026, covering 1,038 MW of standalone storage split between MISO Zone 4 and the PJM ComEd area, with a commercial operation deadline of December 31, 2029. Additional procurement windows are scheduled for 2027 and 2028. Developer demand for site control concentrates in the months before each window. That is when your leverage is highest, and that window is finite.

You can negotiate a fixed lease payment rather than a revenue-share arrangement. A fixed payment puts market risk on the developer. If ancillary service revenues decline as storage builds out (and they are declining in ERCOT and CAISO as saturation increases), you are not exposed to that compression.

Your backup power requirements are predictable and can be written into a host priority clause. If you can define a minimum state-of-charge floor, protected backup windows, and a compensation mechanism in writing, you have the foundation of a workable agreement.

You have the ability to negotiate re-opener rights at year ten on a 20-year deal and require a decommissioning bond. Both of those terms are standard in sophisticated deals and are absent from almost every first draft a developer brings.

When a Battery Storage Host Agreement Is a Terrible Idea (or Locks You In)

The deal works against you under an equally defined set of conditions.

You cannot control dispatch. The fundamental conflict in a third-party owned storage deal is that a developer optimizing for wholesale revenue needs the battery empty enough to charge during low-price windows. A cold storage operator or a healthcare campus needs the battery full enough to provide backup power on demand. Those objectives are structurally opposed. If the agreement does not contain a host priority clause with a written minimum state-of-charge floor and a compensation mechanism for overrides, you have signed away backup power in exchange for a lease payment.

Your revenue share is tied to markets approaching saturation. RFF and market analysts have documented declining ancillary service revenues in ERCOT and CAISO as storage capacity builds out. CAISO net revenue per kilowatt-year was lower in 2023 than in 2022. A revenue-share lease tied to those streams transfers that saturation risk to you. If the developer's pitch includes a revenue-share component, ask which markets the battery will participate in and what the trend line on revenues in those markets looks like.

The developer has not disclosed the after-tax project economics. The Investment Tax Credit can represent 30 percent or more of project cost, and MACRS accelerated depreciation adds further value. If a developer is capturing those benefits and offering you a lease rate that does not reflect them, you are subsidizing their returns. Your job in any negotiation is to ask what the after-ITC project cost is and how much of that tax benefit is explicitly reflected in what you are being paid.

The contract runs 20 years with no re-opener rights and no decommissioning obligation. A 20-year agreement is not unusual for a project of this scale. But 20 years without a re-opener puts you in a contract written for the market conditions of 2025 or 2026 through the mid-2040s. Technology, regulation, and your own operational requirements will all change. A re-opener at year ten costs the developer almost nothing if the deal is working. Insisting on one tells you a great deal about how confident they are in their own projections.

Vendor Pitches, Red Flags, and Questions That Smoke Out the Problem

The most common failure mode in these conversations is that the developer presents a blended revenue number and asks you to evaluate the deal from that number. A blended number hides the composition of revenue by source (energy arbitrage, capacity payments, ancillary services, demand charge reduction), and it prevents you from assessing which revenue streams are stable and which are declining.

Ask for the developer's pro forma by revenue category. Not a single annual dollar figure. A line-item breakdown showing what the battery is projected to earn from each market or service, over what time horizon, and under what assumptions about market prices.

Ask who owns the Investment Tax Credit and whether transferability is part of the deal structure. Under the Inflation Reduction Act, tax credits can be transferred to third parties. If the developer is transferring the credit to a tax equity investor and capturing that value, and your lease rate does not reflect it, that is a negotiation failure on your side, not a feature of the deal.

Ask what interconnection queue timeline they are planning around without your site, and what your site's existing infrastructure compresses that to. Put that compression in writing as a line item in the negotiation.

Ask what the minimum state-of-charge floor is and what the compensation mechanism looks like when their dispatch obligation overrides your backup requirements. If they cannot answer the first question with a specific number and the second with a specific dollar figure or formula, the dispatch rights language does not exist yet, and you are negotiating against a term sheet that protects nobody.

Specific questions to bring to the table:

Q: What is the after-ITC project cost, and how much of the ITC value is reflected in the lease rate you are offering?

Q: Provide a pro forma by revenue category with the market price assumptions underlying each line. What is the trend on ancillary service revenues in the specific ISO you are targeting?

Q: What interconnection timeline are you working against if this site does not participate? What does my existing infrastructure compress that to?

Q: What is the minimum state-of-charge floor in the dispatch rights language, and what is the compensation mechanism when your wholesale optimization overrides my backup power floor?

Q: What is your decommissioning plan at end of contract, and will you post a decommissioning bond before installation begins?

Q: What are the re-opener provisions at year ten?

What You Can Do This Week

Pull the last 12 months of electric bills and identify your peak demand interval, your average monthly demand charge, and the months where backup power was actually needed. This data tells you what a minimum state-of-charge floor needs to be to protect your operation.

Request your interval data from your utility. Interval data shows your load pattern in 15-minute increments. A developer will use this data to model battery dispatch. You should have it before they do, so you understand what your load profile looks like to their model.

Call your utility's interconnection desk or review your existing service agreement for any unused interconnection capacity. If you have solar interconnection that was overbuilt, or a large-service interconnection from a previous expansion, document it. That is the first number you bring to a developer negotiation.

If you are in Illinois, New York, Virginia, Connecticut, or any of the other nine mandate states, look up the next procurement window date for your ISO. In Illinois, that means the 2027 and 2028 events under the CRGA structure. Knowing when that window opens tells you when your leverage is highest.

Ask your legal counsel to review any host agreement for the six terms discussed here: dispatch rights with a state-of-charge floor, host priority language, compensation mechanism for override events, re-opener rights at year ten, decommissioning bond, and Investment Tax Credit pass-through or disclosure.

The Bottom Line on Battery Storage Host Agreements

State mandates create a real buyer for your physical site, and procurement deadlines are real deadlines. That is genuine leverage for a C&I operator in the right geography with the right infrastructure. But the battery storage host agreement for commercial and industrial facilities that a developer brings you in draft form will be written to protect their dispatch flexibility and their tax economics. The operator's job is to convert site access into a fixed payment, a host priority clause with teeth, a decommissioning bond, and a re-opener right before the window closes.

The dispatch rights question is the most important one. If the developer needs the battery empty when you need it full, that conflict does not resolve itself after you sign. It just becomes your problem.

Frequently Asked Questions: Battery Storage Host Agreements for C&I Facilities

Q: What is a battery storage host agreement and what should a C&I operator expect it to cover?

A: A battery storage host agreement is a contract that allows a developer to install, own, and operate a battery system on your property in exchange for a lease payment or revenue share. A well-negotiated agreement covers dispatch rights, a minimum state-of-charge floor, host priority language, compensation for override events, decommissioning obligations, and re-opener rights. The first draft a developer brings will typically cover none of those terms in your favor.

Q: Who controls when the battery charges and discharges in a third-party owned storage deal?

A: In a third-party owned storage deal, the developer controls dispatch by default. That is how they earn revenue from wholesale markets, capacity payments, and ancillary services. A host priority clause gives you a contractual minimum state-of-charge floor and a compensation mechanism for when the developer's dispatch schedule overrides your backup power requirements. Without that clause, the developer's revenue priorities take precedence over your operational needs.

Q: What happens to the Investment Tax Credit in a third-party owned battery storage deal?

A: In a third-party owned deal, the developer captures the Investment Tax Credit, which can represent 30 percent or more of project cost. Under the Inflation Reduction Act, credits can also be transferred to third-party tax equity investors. If the developer is capturing or monetizing those credits and that value is not explicitly reflected in your lease rate, you are subsidizing their project economics. Ask for the after-ITC project cost and a line-item disclosure of how the credit is handled before you accept any lease number.

Q: How do I know if my site has real value to a storage developer?

A: Your site has above-average value if it has existing large-service interconnection infrastructure, an existing substation, or unused capacity on a prior solar interconnection agreement. In most non-ERCOT markets, interconnection queues run multiple years, and a site that compresses that timeline gives a developer a materially shorter path to a bid-ready project. That compression is worth real money in your lease negotiation. Most operators give it away without asking because they do not know the developer's queue situation.

Q: What is a host priority clause and why does every C&I operator need one?

A: A host priority clause is a contractual provision in a battery storage host agreement that establishes a minimum state-of-charge floor for your facility, defines protected backup windows, sets advance notice requirements for dispatch, and creates a compensation mechanism when the developer's wholesale optimization overrides your backup power needs. Without one, the developer's dispatch schedule is unconstrained by your operational requirements. For cold storage operations, hospitals, or any facility where backup power is a production or safety dependency, a host agreement without this clause is not a workable contract.

Q: Should I take a fixed lease payment or a revenue-share arrangement in a battery storage host agreement?

A: A fixed lease payment puts market risk on the developer. A revenue-share arrangement puts market risk on you. Ancillary service revenues in markets like ERCOT and CAISO have been declining as storage capacity builds out, and analysts have documented that saturation is already compressing net revenue per kilowatt-year. If you take a revenue share tied to those markets, your income from the deal declines as the developer's revenue declines. A fixed payment eliminates that exposure. If a developer insists on revenue share, require a floor payment, disclosure of the revenue categories and market price assumptions, and the right to audit project financials annually.

If you are an Indiana-based C&I operator and a developer has already approached you about a site deal, or if you want to understand whether your facility's interconnection infrastructure creates real negotiating leverage, you can request the TEG Energy Decision Blueprint here. We pull your bills, your interval data, and any relevant project documentation, run the numbers against your specific rate and operational realities, and give you our full written opinion with no obligation to anything else. This process is free to qualified Indiana C&I operators.

For more on how federal tax credits affect the project economics in deals like these, see our post on federal energy tax credits (ITC, PTC, and 179D) for Indiana C&I operators. If you are also evaluating whether a battery makes sense as a standalone asset for demand charge reduction, the post on battery energy storage system payback for commercial and industrial operators covers the evaluation framework in full.

Watch this episode of Energy Answers on battery storage host agreements and state procurement mandates on YouTube.