The bottleneck holding back U.S. data center growth is no longer compute hardware - it is power. U.S. data center grid power demand rose 22% in 2025 and is projected to nearly triple by 2030, reaching approximately 134 GW, according to S&P Global's 451 Research1S&P Global's 451 Research. That trajectory is forcing utilities, regulators, and project developers to confront a structural gap - and, increasingly, to look at long-duration energy storage (LDES) as a central part of the solution.
The urgency is reshaping commercial arrangements from the ground up. New tariff structures, renegotiated power purchase agreements (PPAs), and bespoke storage finance mechanisms are emerging specifically to bridge the gap between hyperscale demand and an overtaxed grid. For LDES developers, this shift is creating the first credible pathway to commercial-scale deployment in the U.S.
The Scale of the Challenge
McKinsey estimates that U.S. data center power demand alone could rise by 400 TWh by 2030, growing at 23% annually, representing 30-40% of new net electricity demand and requiring roughly $500 billion in infrastructure investment. Orrick's analysis2Orrick's analysis of the financing landscape notes that interconnection delays now commonly stretch beyond five years in constrained markets.
As previously reported on Energy Tech News3As previously reported on Energy Tech News, AI workloads are the primary catalyst. Goldman Sachs projects global data center power use will climb from roughly 55 GW to 84 GW by 2027, with AI's share rising from 14% to 27%. By 2030, JLL forecasts global data center capacity will nearly double to 200 GW, with AI workloads accounting for roughly half.
The grid is struggling to keep pace. U.S. interconnection queues are delaying projects for years, with some established markets forecast to face electricity shortages as early as 2026. Analysts at Enki Research4Analysts at Enki Research note that data center site selection is now governed primarily by power availability - superseding latency, fiber access, and proximity to existing infrastructure.
Key implication for LDES developers: The data center sector's demand for firm, dispatchable, round-the-clock clean power is precisely the use case long-duration storage is engineered to serve - and one that short-duration lithium-ion batteries structurally cannot fulfill.
Tariff Design Under Transformation
State regulators are developing new rate structures tailored to large-load customers in real time. The common thread: cost-causation principles that prevent data center infrastructure costs from being socialized across general ratepayers - and that create explicit linkages between data center service and storage investment.
Ohio set an early precedent. The Public Utilities Commission of Ohio directed AEP Ohio to file data-center-specific tariffs after interconnection requests for 36 sites reached 13 GW of load. Under the commission's order, large data center customers in AEP Ohio's service area must be responsible for at least 85% of their subscribed energy use, regardless of actual consumption.
Michigan went further. The Michigan Public Service Commission conditionally approved DTE Electric's special contracts with a 1,383 MW data center in Saline Township - but attached explicit storage obligations. Under the DTE/MPSC framework, the data center operator funds the development of 1,383 MW of energy storage facilities over a 15-year period; DTE owns and operates the assets, retaining wholesale market revenues. The minimum billing demand was set at 80% over a 19-year contract term, compared to the standard 50-60% under DTE's general D11 tariff.
Pennsylvania issued proposed guidelines in November 2025 for a model large-load tariff covering customers with individual loads of 50 MW or aggregate loads of 100 MW or more. Key proposals include a five-year minimum contract term, an 80% minimum demand charge, a six-month timeline for interconnection studies, and annual contributions to a hardship fund.
| State / Regulator | Mechanism | Key Terms | Storage Linkage |
|---|---|---|---|
| Ohio (AEP Ohio) | Data Center Tariff | 85% minimum billing demand | Implicit - cost-causation shields ratepayers |
| Michigan (DTE / MPSC) | Special Supply + Storage Agreement | 80% min. demand; 19-year contract | Explicit - customer funds 1,383 MW DTE-owned storage |
| Pennsylvania (PA PUC) | Model Large Load Tariff (proposed) | 5-yr term; 80% min. demand; 6-month study | Hardship fund contribution required |
| California (CPUC) | LLT Procurement Mandate | 1 GW intraday + 1 GW multiday storage | Direct LDES procurement; grid firming for all loads |
| FERC (federal) | Large Load ANOPR (RM26-4) | 100% participant funding; 20 MW threshold | Co-location rules; reliability study triggers |
The Michigan model in particular is drawing attention as a template: the data center becomes a direct funder of grid storage, aligning its uptime interests with utility grid stability objectives. Orrick's guide to data center financing2Orrick's analysis identifies these bespoke "Clean Transition Tariff" arrangements as a growing contracting mechanism, alongside behind-the-meter PPAs and virtual PPAs.
PPA Structures Evolve to Incorporate Storage Performance
Traditional corporate renewable PPAs - indexed to annual megawatt-hour delivery - are proving inadequate for hyperscale data center needs. Data centers operating to "Five 9s" standards (99.999% availability) permit only around five minutes of downtime per year, requiring fully firm, uninterrupted supply. Annual renewable energy certificates do not guarantee hourly delivery, let alone multi-day resilience during weather events.
The market response has been structured hybrid contracting. Pillsbury's analysis of PPA structures5Pillsbury's analysis of PPA structures notes that hyperscalers increasingly prefer to procure energy directly - and that negotiating interconnection agreements early is now "mission critical." Microsoft entered into an agreement with Brookfield in May 2024 to deliver over 10.5 GW of new renewable energy capacity between 2026 and 2030, while Google's parent Alphabet announced a $4.75 billion agreement in December 2024 to acquire Intersect Power, integrating generation and data center development.
Newer arrangements explicitly pair renewable generation with LDES capacity payments. Hydrostor, which has executed over $2 billion in LDES PPAs6Hydrostor, which has executed over $2 billion in LDES PPAs, structures agreements that allow data center and utility offtakers to access dispatchable clean power when solar and wind are curtailed - effectively monetizing the storage duration premium. Google is also working with Milan-based Energy Dome to deploy CO₂ batteries for data center applications, a technology that provides 10-hour discharge without critical minerals.
The critical structural challenge for project finance remains revenue certainty. Multi-day arbitrage alone cannot justify LDES investment. Capacity payments tied to storage performance - ensuring a project is paid for availability to discharge, not merely for energy delivered - are increasingly viewed as the necessary bankability mechanism.
The Investment Gap and Financing Constraints
Despite mounting commercial interest, LDES capital markets remain under stress. Global LDES funding fell 30% year-on-year in 2025, excluding the U.S. Department of Energy's $1.76 billion conditional loan guarantee commitment to Hydrostor. Venture capital investment in LDES fell by 72% globally in 2025, according to Wood Mackenzie's Long Duration Energy Storage Trends report. The firm found that LDES accounts for just 6% of total global energy storage installations.
Wood Mackenzie managing consultant for energy storage Jiayue Zheng assessed that LDES technologies are "caught in a strategic squeeze" - lithium-ion batteries have captured the four-to-eight-hour market7lithium-ion batteries have captured the four-to-eight-hour market through cost and supply chain advantages, while LDES "lacks sufficient demand and pricing mechanisms to achieve commercial viability."
⚠️ The Financing Gap: Roughly 98% of announced LDES capacity globally remains pre-final investment decision (FID), according to Sightline Climate's analysis8Sightline Climate's analysis. Long payback periods, inconsistent capacity market accreditation, and technology risk are deterring lenders - precisely when data center operators need committed supply. Revenue certainty mechanisms - including capacity payments tied to LDES performance and longer-term PPA structures - are the critical missing link.
The global LDES market was valued at $3.6 billion in 2025 and is projected to grow at a 10.5% CAGR through 20359global LDES market was valued at $3.6 billion in 2025 and is projected to grow at a 10.5% CAGR through 2035, according to GM Insights - driven by renewable integration needs and, increasingly, data center demand for reliable clean power. The energy storage market co-located with AI data centers is projected to reach $4.1-$6.0 billion annually by 2030, up from approximately $1.2 billion in 2025, representing a 28-38% compound annual growth rate.
Between 2021 and 2025, only three LDES companies - Hydrostor, Eos Energy, and Form Energy - collectively raised over $4 billion. Form Energy's first 100-hour iron-air batteries began hitting the grid commercially in October 2025, marking the first commercial-scale multi-day battery storage deployment, following contracts with Dominion, Great River Energy, and Xcel Energy. As reported by Energy Tech News3As previously reported on Energy Tech News, Form Energy has also announced a supply agreement with data center developer Crusoe.
Federal Regulatory Signals: FERC, Interconnection, and Co-Location
Federal regulatory activity is accelerating - creating both opportunity and uncertainty for LDES developers eyeing data center offtake.
The DOE directed FERC to issue an Advance Notice of Proposed Rulemaking (ANOPR, Docket RM26-4) targeting large-load interconnection reforms. The ANOPR proposes10The ANOPR proposes 100% participant funding for network upgrades, standardized study timelines, and expedited connection pathways for customers with co-located generation. If adopted, the 100% participant-funding model would fundamentally alter the economics of data center grid access - and sharply incentivize co-located LDES.
FERC's five-member panel unanimously ordered PJM Interconnection to develop rules for co-locating data centers and other large loads at power plants, giving the grid operator 60 days to propose service rules. PJM's last two base capacity auctions showed a growing shortfall compared to reserve margin targets, with prices expected to keep rising until large data center loads are addressed.
The jurisdictional boundary between FERC and states remains contested. The National Association of Regulatory Utility Commissioners (NARUC) urged FERC to preserve state jurisdiction over retail energy regulation in its large-load rulemaking - a tension that could slow implementation of uniform interconnection standards.
The DOE's resource hub for data center energy11DOE's resource hub for data center energy explicitly identifies long-duration storage as one of the "key enabling technologies" being commercialized to meet data center electricity demand - alongside next-generation geothermal and advanced nuclear. The agency's strategy includes an Industrial Energy Storage Systems Prize designed to position data centers as grid assets rather than burdens.
Reliability Targets and the Grid Stability Equation
The push for LDES deployment is not solely a data center resilience play - it carries direct implications for broader grid stability. Under Wood Mackenzie's net-zero scenarios, the global average energy storage duration must increase from 2.5 hours to around 20 hours to maintain grid reliability as variable renewable penetration rises.
Inter-day storage (8-12 hours) can help grid operators manage winter peaks, reduce renewable curtailment, and support rising load from data centers, according to Sightline Climate's analysis. In 2024, the California Public Utilities Commission committed to procuring 1 GW of intraday storage and 1 GW of multiday storage as part of a broader emerging low-carbon technology solicitation.
The risk of misalignment between data center resilience and grid stability is real. Michigan's MPSC, in approving DTE's data center contracts, explicitly conditioned approval on the requirement that data center load be reduced or interrupted before any other DTE customers during an involuntary load shed. Grid planners increasingly require data center operators to demonstrate demand flexibility - a condition that, paired with on-site LDES, could convert hyperscale facilities from grid stress points into dispatchable grid assets.
Key Takeaways for Market Participants
Tariff design is the critical near-term lever. State commissions are moving faster than federal rulemaking. Developers and offtakers should track model large-load tariff proceedings in Pennsylvania, Michigan, and Virginia, and engage early in cost-allocation debates.
Data center offtake can unlock LDES finance. Long-term, performance-linked PPAs with hyperscalers or colocators - structured with capacity payments tied to discharge availability - offer the revenue certainty LDES project lenders require to reach FID. The Michigan DTE model demonstrates that regulators will approve such structures.
FERC's large-load ANOPR reshapes interconnection economics. A shift to 100% participant funding for network upgrades creates strong incentives for data center operators to co-invest in LDES, reducing transmission upgrade burdens and accelerating grid access.
Technology selection should follow use case, not hype. Compressed air (45%), thermal (33%), and vanadium redox flow (21%) accounted for the largest shares of 2025 LDES installations. No single technology dominates; portfolio approaches spanning 8-hour to 100-hour discharge will serve different reliability requirements.
The financing gap is real but closeable. DOE loan guarantees, ITC/ITC adder eligibility, and state-level procurement mandates anchor current LDES bankability. As capacity market accreditation frameworks evolve to recognize multi-hour discharge, private capital is expected to follow.
Frequently Asked Questions
Why can't standard 4-hour lithium-ion batteries meet data center LDES needs? Data centers operating under "Five 9s" uptime standards require continuous, firm power. A four-hour battery provides insufficient buffer during multi-hour or multi-day renewable droughts. LDES systems (8-100+ hours) are better suited for load-matching 24/7 renewable supply, though they currently carry higher upfront capital costs. As Sightline Climate notes8Sightline Climate's analysis, cost reduction - not just capacity market design - is the key unlock for LDES commercial viability.
What is a Clean Transition Tariff, and how does it apply to data centers? A Clean Transition Tariff is a utility rate structure pairing a large-load customer with dedicated clean energy resources - potentially including LDES - with costs and revenues ring-fenced to that arrangement. Regulators in Michigan and Virginia have approved or are piloting such structures, increasingly identified as a mechanism to simultaneously address data center demand growth and decarbonization goals.
What regulatory hurdle most slows LDES deployment alongside data centers? The primary barrier is the absence of capacity market rules that adequately value multi-hour discharge. Most U.S. wholesale markets accredit storage based on short-duration performance, leaving LDES unable to capture the full value of its reliability contribution. Until accreditation frameworks evolve - or data center offtake agreements provide bankable revenue - LDES projects will struggle to reach final investment decision.
How does interconnection reform affect LDES sited near data centers? FERC's Large Load ANOPR proposes that large-load customers bear the full cost of network upgrades required to connect them. If adopted, this model creates strong incentives for data centers to co-locate with on-site or nearby storage - including LDES - to reduce the upgrade burden and accelerate interconnection timelines. It also opens pathways for expedited approval where customers commit to peak load management.
