State Storage Mandates and Your Battery Deal
A developer wants to put a battery on your site to help a utility hit a state procurement target. Here is how to decide whether to host, co-own, or build, and how to negotiate before the RFP window closes.
Who this is for
- ■Multi-site retail chains with rooftop or lot space in mandate states
- ■Industrial manufacturers with substation access or large-service interconnection
- ■Commercial real estate portfolios evaluating site-host agreements
- ■Cold storage operators who need guaranteed backup power
- ■Healthcare campuses weighing dispatch rights against islanding requirements
Do we host a third-party battery, co-own it, or build it ourselves, and what terms do we need before the next RFP window closes?
A developer is knocking because a utility somewhere has a hard megawatt deadline written into state law. 10 states have adopted energy storage procurement targets: California, Oregon, Nevada, Illinois, Virginia, New Jersey, New York, Connecticut, Massachusetts, and Maine. When a utility faces a statutory obligation, it must contract for capacity through RFP windows. That obligation cascades to developers, who then need physical sites with suitable interconnection to build. Your property is the asset that lets a developer meet its bid obligation. The mandate is why they will pay you.
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- 02 The mechanism The RFP Calendar and Where Your Leverage Lives
Illinois is the clearest live example of the cadence. The Illinois Power Agency held an initial procurement event for 1,038 MW of standalone storage, split into 450 MW in MISO Zone 4 and 588 MW in the PJM ComEd Area. Projects must reach commercial operation by year-end 2029, run for 4 hours, and meet labor and equity requirements. Contracts are 20 years using an Indexed Storage Credit pricing structure under the Clean and Reliable Grid Affordability Act. Additional windows are scheduled for 2027 and 2028, with a total goal of 3,000 MW.
Those specific events target front-of-meter utility-scale projects, not behind-the-meter C&I hosts directly. But the broader demand curve is the same. Developers need site control before they submit bids. Their willingness to pay concentrates in the months leading up to each procurement event. In Illinois, the period before the 2027 and 2028 windows is when host leverage peaks. That window is finite.
Milestone What it means for you Procurement window opens Developer needs signed site control to bid credibly Interconnection queue submitted Your existing service becomes valuable if it shortens the queue Award announced Terms harden, developer leverage grows Commercial operation deadline Penalty exposure sits with the developer, not you Third-party ownership
Developer finances, installs, owns, and operates the battery. You get a lease payment or service rate. Variations include PPAs, leases, and Energy Savings Performance Contracts.StructureCo-ownership
You take an equity stake alongside the developer. Costs, risks, and returns are shared. All TPO and direct financing tools are available under this structure.StructureDirect ownership
You finance, own, and operate the system. You capture all savings and incentives. You also carry all maintenance, operational, and performance risk.Why TPO existsThe tax credit question
Historically, the core of the TPO pitch was that a tax-paying developer could capture the Investment Tax Credit, potentially 30% of project cost, plus accelerated MACRS depreciation, while a tax-exempt hospital or municipality could not use those credits directly. Under the IRA, direct pay changes that math for qualifying tax-exempt entities. So TPO today is really about developer scale, financing cost, and operational expertise. For taxable C&I operators, the ITC question becomes: how much of that value shows up in your lease rate, and is transferability part of the structure?
- 03 What it does to you Three Ownership Structures and Who Captures WhatStructure
Third-party ownership
Developer finances, installs, owns, and operates the battery. You get a lease payment or service rate. Variations include PPAs, leases, and Energy Savings Performance Contracts.StructureCo-ownership
You take an equity stake alongside the developer. Costs, risks, and returns are shared. All TPO and direct financing tools are available under this structure.StructureDirect ownership
You finance, own, and operate the system. You capture all savings and incentives. You also carry all maintenance, operational, and performance risk.Why TPO existsThe tax credit question
Historically, the core of the TPO pitch was that a tax-paying developer could capture the Investment Tax Credit, potentially 30% of project cost, plus accelerated MACRS depreciation, while a tax-exempt hospital or municipality could not use those credits directly. Under the IRA, direct pay changes that math for qualifying tax-exempt entities. So TPO today is really about developer scale, financing cost, and operational expertise. For taxable C&I operators, the ITC question becomes: how much of that value shows up in your lease rate, and is transferability part of the structure?
The most consequential issue in these deals is dispatch rights. A developer optimizing for wholesale revenue, energy arbitrage, ancillary services, capacity payments, needs the battery empty enough to charge during low-price windows. A cold storage operator or healthcare campus needs the battery full enough to provide backup power on demand. Those objectives are structurally opposed.
What you hear What is actually happening The battery is on your site, so backup power is guaranteed. Backup only exists if minimum state-of-charge floors are written into the contract. Revenue share means we win when they win. Revenue share transfers ancillary market saturation risk from the developer to you. Twenty years of steady lease income. Twenty years of exposure to policy and market shifts unless you negotiate re-openers. The developer will take care of everything at end of term. Only if a decommissioning bond is in the contract with defined restoration terms. The contractual resolution to the dispatch conflict is a host priority clause: a defined minimum state-of-charge floor, protected backup windows with written notice requirements before the developer can override, and a compensation mechanism when their dispatch obligation runs against your operational needs.
Revenue-share mathSaturation is a real risk
Market analysts have flagged that storage is nearly saturating ancillary service markets in ERCOT and CAISO. In CAISO, net revenue per kilowatt-year was lower in 2023 than in 2022 even as total battery spending rose by 22%. Batteries in California crossed 10 GW in 2024. NREL research indicates four-hour storage captures over 80% of capacity and arbitrage value, with the incremental value of longer duration much less than the cost. If your lease floats with developer revenues in a market that is filling up, you are holding that bag, not them.
Saturation signals worth pricing22%CAISO total battery spending rose, net revenue fell10GWCalifornia battery capacity crossed this in 202480%Value captured by four-hour storage todayA revenue-share lease tied to ancillary services in a saturating market is a declining asset. A fixed payment puts that risk on the developer. The most consequential issue in these deals is dispatch rights. A developer optimizing for wholesale revenue, energy arbitrage, ancillary services, capacity payments, needs the battery empty enough to charge during low-price windows. A cold storage operator or healthcare campus needs the battery full enough to provide backup power on demand. Those objectives are structurally opposed.
What you hear What is actually happening The battery is on your site, so backup power is guaranteed. Backup only exists if minimum state-of-charge floors are written into the contract. Revenue share means we win when they win. Revenue share transfers ancillary market saturation risk from the developer to you. Twenty years of steady lease income. Twenty years of exposure to policy and market shifts unless you negotiate re-openers. The developer will take care of everything at end of term. Only if a decommissioning bond is in the contract with defined restoration terms. The contractual resolution to the dispatch conflict is a host priority clause: a defined minimum state-of-charge floor, protected backup windows with written notice requirements before the developer can override, and a compensation mechanism when their dispatch obligation runs against your operational needs.
Revenue-share mathSaturation is a real risk
Market analysts have flagged that storage is nearly saturating ancillary service markets in ERCOT and CAISO. In CAISO, net revenue per kilowatt-year was lower in 2023 than in 2022 even as total battery spending rose by 22%. Batteries in California crossed 10 GW in 2024. NREL research indicates four-hour storage captures over 80% of capacity and arbitrage value, with the incremental value of longer duration much less than the cost. If your lease floats with developer revenues in a market that is filling up, you are holding that bag, not them.
Saturation signals worth pricing22%CAISO total battery spending rose, net revenue fell10GWCalifornia battery capacity crossed this in 202480%Value captured by four-hour storage todayA revenue-share lease tied to ancillary services in a saturating market is a declining asset. A fixed payment puts that risk on the developer.- 05 Your leverage Interconnection, Re-Openers, and the Terms to Demand
Interconnection queues in most non-ERCOT markets now run multiple years. ERCOT's process runs about 3.5 years, while other jurisdictions typically wait about 6 years. If your site has large-service interconnection, an existing substation, or unused capacity on a solar interconnection, you can materially shorten the developer's path to a bid-ready project. FERC Orders 860 and 2023 require RTOs to facilitate surplus interconnection service, so a 50 MW solar plant with daytime-only output can add batteries without a new interconnection study. That is real value. Most operators give it away without asking.
Interconnection timeline by marketA site that shortens the developer's queue is worth more. Price it into the deal. - 1 Map your state's procurement calendar and identify the window that drives developer urgency.
- 2 Inventory your existing interconnection: service size, substation access, unused solar interconnection capacity.
- 3 Require the developer's pro forma broken out by revenue category, not a blended number.
- 4 Negotiate a host priority dispatch clause with a written minimum state-of-charge floor.
- 5 Choose fixed lease payments over revenue-share if the target market is approaching saturation.
- 6 Add a re-opener clause at year 10 years on any 20-year contract. 10 years
- 7 Require a decommissioning bond covering equipment removal and site restoration.
- 8 For multi-site portfolios, negotiate a master site-host agreement that preserves optionality on which locations get developed.
When to engage a storage developer, and when to walk
✓ Worth negotiating- Your site is in a mandate state with a procurement window inside the next two to three years
- You already have large-service interconnection or unused solar interconnection capacity
- You can accept fixed lease payments and hard dispatch floors that protect your backup needs
- Your operations can tolerate multi-year construction disruption on the identified footprint
- You have the internal capacity to enforce contract terms over a 20-year window
✗ Walk or restructure- The developer will not disclose their pro forma by revenue category
- The offered structure is revenue-share tied to ancillary services in a saturating market
- There is no written minimum state-of-charge floor or override compensation mechanism
- The contract lacks re-opener rights, a decommissioning bond, or clear site restoration terms
- Your site is critical-load with no viable alternative backup and dispatch rights are not host-priority
- Decision matrix
When to engage a storage developer, and when to walk
✓ Worth negotiating- Your site is in a mandate state with a procurement window inside the next two to three years
- You already have large-service interconnection or unused solar interconnection capacity
- You can accept fixed lease payments and hard dispatch floors that protect your backup needs
- Your operations can tolerate multi-year construction disruption on the identified footprint
- You have the internal capacity to enforce contract terms over a 20-year window
✗ Walk or restructure- The developer will not disclose their pro forma by revenue category
- The offered structure is revenue-share tied to ancillary services in a saturating market
- There is no written minimum state-of-charge floor or override compensation mechanism
- The contract lacks re-opener rights, a decommissioning bond, or clear site restoration terms
- Your site is critical-load with no viable alternative backup and dispatch rights are not host-priority
Questions for your morning huddle- Does our site have existing interconnection infrastructure that would shorten a developer's queue, and is that reflected in what they are offering us?
- In the lease structure being proposed, who captures the ITC and MACRS depreciation, and how much of that value is explicitly passed through to our payment?
- What is the minimum state-of-charge floor in the dispatch language, and what is the compensation when the developer's wholesale dispatch overrides our backup power?
- Is the lease payment fixed or floating with developer revenues, and do we understand which markets are approaching saturation?
The one thing to rememberThe mandate creates a real buyer for your site, but developer leverage grows and yours shrinks the closer you get to the procurement deadline.
Before your next developer meeting, inventory your existing interconnection capacity, map your state's next procurement window, and write down the three dispatch and revenue terms you will not sign without.
Know if the numbers actually pencil out before you sign anything.
A written second opinion on the project in front of you, whether that is a rate change, new equipment, or a renewable installation.
- 01A short call, to figure out quickly whether we can actually be helpful. If we can't, we'll say so on the spot.
- 02We pull the data, your bills, your rate structure, vendor proposals, project specs.
- 03You get the verdict in writing: whether the payback will materialize, and the opportunities or risks nobody has raised.
Get a Blueprint at blueprint.tac-nrg.com Free for Indiana-based operations spending five figures or more a month on electricity. No obligation. You keep the write-up either way. - The one thing to remember
The mandate creates a real buyer for your site, but developer leverage grows and yours shrinks the closer you get to the procurement deadline.
Before your next developer meeting, inventory your existing interconnection capacity, map your state's next procurement window, and write down the three dispatch and revenue terms you will not sign without.
The Energy Decision BlueprintKnow if the numbers actually pencil out before you sign anything.
A written second opinion on the project in front of you, whether that is a rate change, new equipment, or a renewable installation.
- 01A short call, to figure out quickly whether we can actually be helpful. If we can't, we'll say so on the spot.
- 02We pull the data, your bills, your rate structure, vendor proposals, project specs.
- 03You get the verdict in writing: whether the payback will materialize, and the opportunities or risks nobody has raised.
Get a Blueprint at blueprint.tac-nrg.com Free for Indiana-based operations spending five figures or more a month on electricity. No obligation. You keep the write-up either way.how much does a developer pay to put a battery on my property
The package does not name a per-acre or per-kW site payment rate. What it does say is that the payment structure varies by ownership model: fixed lease payments, revenue-share arrangements, PPA rate discounts, or Energy Savings Performance Contract splits. What you can actually collect depends on your state's procurement window, whether your site shortens the developer's interconnection queue, and how you allocate dispatch rights and revenue risk in the contract.
who owns the tax credit on a third-party battery deal
The developer typically owns the battery and captures the Investment Tax Credit, historically around 30% of project cost, plus MACRS accelerated depreciation. Under the IRA, direct pay changes the math for qualifying tax-exempt entities like hospitals and municipalities. For taxable C&I operators, the real question is how much of that tax value is passed through to your lease rate, and whether transferability of the credit is part of the deal structure. Ask for the after-ITC project cost in writing.
how do I keep backup power if a third party owns the battery on my site
Through a host priority dispatch clause in the contract. That clause needs three things: a written minimum state-of-charge floor the developer must maintain, protected backup windows with defined notice requirements before the developer can override, and a compensation mechanism when the developer's wholesale dispatch obligation runs against your operational needs. Without those three elements in writing, backup power is not guaranteed no matter what the sales pitch says.
who owns the tax credit on a third-party battery deal
The developer typically owns the battery and captures the Investment Tax Credit, historically around 30% of project cost, plus MACRS accelerated depreciation. Under the IRA, direct pay changes the math for qualifying tax-exempt entities like hospitals and municipalities. For taxable C&I operators, the real question is how much of that tax value is passed through to your lease rate, and whether transferability of the credit is part of the deal structure. Ask for the after-ITC project cost in writing.
how do I keep backup power if a third party owns the battery on my site
Through a host priority dispatch clause in the contract. That clause needs three things: a written minimum state-of-charge floor the developer must maintain, protected backup windows with defined notice requirements before the developer can override, and a compensation mechanism when the developer's wholesale dispatch obligation runs against your operational needs. Without those three elements in writing, backup power is not guaranteed no matter what the sales pitch says.
should I do a revenue share or a fixed lease with a battery developer
Fixed lease puts market and saturation risk on the developer. Revenue share puts it on you. Storage is nearly saturating ancillary service markets in ERCOT and CAISO, and CAISO net revenue per kilowatt-year fell in 2023 even as total battery spending rose 22%. If your developer is projecting revenue from a market approaching saturation, a revenue-share lease is a declining asset. Fixed payments are more predictable and easier to underwrite for facility planning.
what is surplus interconnection service and why does it matter for my site
Surplus Interconnection Service lets a new resource use existing, underutilized interconnection capacity without triggering a full new interconnection study. FERC Orders 860 and 2023 require RTOs to facilitate it. Example: a 50 MW solar plant that only runs during the day can add batteries to use the interconnection at night. If your site has a solar array, a large service, or an existing substation with headroom, you may be able to accelerate a developer past a multi-year queue, and that is real value that should show up in your lease terms.
how long is the interconnection queue for a battery storage project
ERCOT runs about 3.5 years. Other jurisdictions typically wait about 6 years, though ongoing FERC Order 2023 reforms are changing timelines in some regions. For a developer bidding into a procurement window with a hard commercial operation deadline, queue duration is often the binding constraint. That is why a site that already has interconnection, or has access to Surplus Interconnection Service, is disproportionately valuable.
what is surplus interconnection service and why does it matter for my site
Surplus Interconnection Service lets a new resource use existing, underutilized interconnection capacity without triggering a full new interconnection study. FERC Orders 860 and 2023 require RTOs to facilitate it. Example: a 50 MW solar plant that only runs during the day can add batteries to use the interconnection at night. If your site has a solar array, a large service, or an existing substation with headroom, you may be able to accelerate a developer past a multi-year queue, and that is real value that should show up in your lease terms.
how long is the interconnection queue for a battery storage project
ERCOT runs about 3.5 years. Other jurisdictions typically wait about 6 years, though ongoing FERC Order 2023 reforms are changing timelines in some regions. For a developer bidding into a procurement window with a hard commercial operation deadline, queue duration is often the binding constraint. That is why a site that already has interconnection, or has access to Surplus Interconnection Service, is disproportionately valuable.
- Procurement mandate
- A statutory requirement that a utility contract for a specified quantity of energy storage by a specified deadline.
- Third-party ownership (TPO)
- An arrangement where a developer finances, installs, owns, and operates the battery on your property while you lease the system or buy services under long-term contract.
- Power Purchase Agreement (PPA)
- A contract to buy electricity or storage services at a predetermined rate over a specified term while the developer owns and operates the hardware.
- ESPC
- Energy Savings Performance Contract. An ESCO designs, installs, and finances the system and gets paid over time from a portion of realized energy cost savings.
- Indexed Storage Credit (ISC)
- The pricing structure Illinois uses to compensate storage projects under a long-term contract, established under the Clean and Reliable Grid Affordability Act.
- Ancillary services
- Products that maintain stable grid operation such as frequency regulation, voltage support, and reserves, distinct from selling energy directly.
- Host priority dispatch
- Contract language that gives the host site's operational needs, especially backup power, precedence over the developer's wholesale market optimization under defined conditions.
- Surplus Interconnection Service (SIS)
- A FERC-required mechanism letting a new resource use existing, underutilized interconnection capacity without a full new study.
- Investment Tax Credit (ITC)
- A federal tax credit for qualifying energy projects, historically around thirty percent of eligible project cost, that reduces the developer's after-tax project cost.