At the end of 2025, Lawrence Berkeley National Laboratory counted 2,060 gigawatts of generation and storage capacity sitting in U.S. interconnection queues. That is more nameplate than the entire installed generating fleet of the United States, which finished 2024 at roughly 1,280 GW. The queue is no longer a waiting room. It is a balance sheet, and the entries on it have started to clear at prices that bear no resemblance to the underlying real estate beneath them.
The entitlement stack, the bundle of approvals, queue positions, water rights, air permits, capacity interconnection rights, ESA and USACE clearances, ALUC posture, Williamson Act exits, and Specific Plan approvals, is detaching from the land it sits on. By 2030, that stack trades with explicit per-megawatt-month pricing, in a securitized format, rated by Tier 1 agencies, and held by sovereign and pension allocators who would never touch raw dirt. The land becomes the wrapper. The entitlement is the asset.
Queue As A Marked-To-Market Asset
The LBL Queued Up report tracks every active interconnection request across the seven U.S. ISOs and the non-ISO West. The 2024 edition logged 1,570 GW pending. The 2025 edition pushed past 2,060 GW. Queue volume has grown faster than 30 percent year over year for four consecutive years, while the completion rate has collapsed. Of the projects that requested interconnection between 2000 and 2018, only 19 percent reached commercial operation. Withdrawal rates above 70 percent are now the modal outcome across PJM, MISO, and CAISO.
Median time from interconnection request to commercial operation crossed 5 years in PJM in 2024 and is approaching 7 in MISO. ERCOT, the only ISO with a connect-and-manage model rather than a serial study process, runs at roughly 3 years. The spread between ERCOT timelines and PJM timelines is now the single largest driver of regional load-siting decisions, and it has nothing to do with the cost of dirt.
A queue position that has cleared System Impact Study and Facilities Study, with executed Large Generator Interconnection Agreement, is no longer a procedural artifact. It is a financial instrument with an implied option value, a strike price set by the network upgrade cost allocation, and a maturity date set by the Commercial Operation deadline. PJM's 2024 transition cluster filings show LGIA-stage positions changing hands inside corporate restructurings at valuations that imply roughly $80,000 to $140,000 per MW of cleared capacity, before any project equipment is procured.
What Survives When A Plant Retires
FERC Order 2023, issued July 2023 and refined through Order 2023-A in March 2024, formalized cluster studies and tightened readiness deposits. Order 845, predating it by five years, established the surplus interconnection service framework. Together they create the mechanical pathway that makes Capacity Interconnection Rights portable. When a thermal plant retires, the CIR does not retire with it. The rights survive, transferable under defined tariff conditions, and re-deployable to a replacement asset at the same point of interconnection.
This is the entire economic basis of the brownfield repositioning trade. Amazon Web Services and Talen Energy executed a 1.92 GW PPA at the Susquehanna nuclear site in June 2025, structured around the existing 500 kV interconnection. Microsoft and Constellation signed a 20-year offtake for the 837 MW Three Mile Island Unit 1 restart in September 2024, with commercial operation targeted for 2028. Meta and Oklo agreed to a 1.2 GW deployment anchored in Pike County, Ohio in 2025. Vistra has fielded inbound interest on Comanche Peak's existing site rights that values the interconnection envelope independently of the reactor.
The consistent feature across all four deals is that the buyer is paying for survivability, not steel. The interconnection rights, the air permits grandfathered to the site, the cooling water withdrawals already adjudicated, the ALUC and FAA clearances already filed. The equipment can be replaced. The entitlement cannot.
The Brownfield Comp Set That Is Already Trading
The AWS-Talen transaction priced at roughly $650 million for the campus stake plus a multi-decade PPA. Stripping the energy contract, the implied valuation of the entitlement bundle alone runs in the range of $330,000 to $410,000 per MW. The Three Mile Island restart involves $1.6 billion in capital that Constellation is fronting for an asset Constellation already owns, which means Microsoft is paying a PPA premium that capitalizes the entitlement separately from the megawatt.
In 2022, the going rate for a raw, unentitled industrial parcel in a strong grid node was 2 to 3 times the agricultural floor. In 2026, the spread between raw parcels and entitlement-bundled parcels at equivalent locations has widened to 8 to 15 times. The same dirt with a cleared queue position, executed water service agreement, completed CEQA or NEPA review, and air permit in hand prices at a multiple that no land appraiser using comparable-sales methodology can defend, because the comparables are not land. They are options on grid access.
Water Rights As The Second Entitlement
The Colorado River Basin lower-division states finalized a post-2026 operational framework in early 2026 that pencils out roughly 1.5 million acre-feet of mandatory reductions across Arizona, Nevada, and California against the 1922 Compact baseline. Priority date is the only thing that matters. Pre-1922 senior rights in the lower basin clear at $80,000 to $120,000 per acre-foot in private transactions. Junior post-1968 rights trade below $30,000 and face curtailment risk in any year that Lake Mead drops below 1,050 feet.
The Lower Snake River basin priority dates run analogous economics on a smaller scale. Owens Valley priority rights, controlled largely by LADWP, trade in secondary markets at premiums that imply $200,000 per acre-foot for senior positions when transfers clear the State Water Resources Control Board's change petition process. The change petition itself takes 3 to 7 years and is the single largest gating item on any inter-basin transfer.
A data center campus drawing 15 megawatts of cooling load can run dry-cooled, but the efficiency penalty is 8 to 12 percent of usable IT capacity. Wet-cooled requires roughly 1.8 to 2.5 acre-feet per MW per year of continuous makeup water. At Western valuations, a 500 MW campus's water entitlement is a $90 to $300 million line item that the buyer cannot synthesize on accelerated timelines. The water right is the second entitlement and it adjudicates separately from the land, the power, and the air permit.
CEQA, NEPA, And The Cost Of A Stable Project Description
California's 2024 CEQA reforms, codified through SB 149 and the OPR's 2024 guidelines update, did not shorten Environmental Impact Reports. They tightened the requirement that the project description be stable from Notice of Preparation through Final EIR. Median EIR duration in California for industrial projects above 50 acres now runs 18 to 30 months. Federal NEPA review under Council on Environmental Quality's 2024 rules, even in the streamlined categorical exclusion path, averages 14 months for any project triggering Section 7 ESA consultation or Section 404 USACE jurisdiction.
The stable project description requirement is a binding cost variable, because mid-process amendments trigger recirculation and reset the 45 to 60 day public comment clock. Any developer who has to change cooling technology, substation location, or transmission corridor mid-EIR loses 6 to 9 months. Pre-permitted sites with completed Final EIR and Record of Decision avoid this entirely, which is why they price at the multiples they do.
The Per-MW-Month Pricing Becoming Standard
Ohio AEP filed a large-load tariff class in late 2024 with a minimum take provision and a 12-year contract term. Georgia Power's Schedule LLS, approved by the Georgia PSC in 2024, applies cost-causation riders to loads above 100 MW. Dominion Virginia's 2025 rate case introduced a directly-allocated infrastructure rider for hyperscaler customers in Loudoun County. Indiana AES has a pending filing structured similarly. The pattern is uniform. Cost-causation is now the standard ratemaking treatment for large new load, which means the megawatt itself is no longer a fungible commodity priced at the system average. The megawatt at this site, with this interconnection, under this tariff class, is the priced unit.
The secondary market followed. By mid-2025, capacity rights at specific points of interconnection began trading separately from EPC contracts and equipment commitments. Implied per-MW-month pricing for cleared, executed positions in PJM West and CAISO LSE-served territories ranges from $4,200 to $7,800 per MW-month, before any energy is delivered. This is the option premium on grid access, marked to market, in a market that did not exist as a market in 2022.
What Becomes True By 2030
Four forward conditions follow from the convergence above.
First, by 2027, expect explicit entitlement derivatives. Forward contracts on cleared queue positions, written against standardized LGIA milestones, traded over-the-counter initially and migrating to a regulated venue by 2028. The contract specification will reference the FERC Order 2023 cluster study calendar as the settlement reference.
Second, by 2028, Tier 1 ratings agencies, Moody's, S&P, and Fitch, publish methodology papers for rating entitlement bundles as structured products. The rating logic will distinguish queue position tier, water rights priority date, air permit grandfathering status, and CEQA or NEPA completion stage as the four credit-relevant inputs. Bundles rated investment grade will trade inside 200 basis points of comparable long-dated infrastructure debt.
Third, by 2029, sovereign wealth and pension capital allocates to entitlement portfolios as a fixed-income proxy. The duration profile, 15 to 30 years of cleared rights against multi-decade hyperscaler PPAs, fits LDI mandates better than any other private market exposure available at scale. ADIA, GIC, CPPIB, and the Norwegian Government Pension Fund Global will publish allocation targets in the 2 to 5 percent of alternatives range.
Fourth, by 2030, the per-MW-month pricing convention becomes the standard quotation unit for industrial real estate in any market with binding grid constraints. Brokers quote sites in $/MW-month of cleared capacity, not $/acre. The acre denomination survives only in jurisdictions where grid access is structurally abundant, which by 2030 means parts of ERCOT, parts of SPP, and almost nowhere else.
The queue, the water, the air, the EIR, and the tariff class are not entitlements in any conventional regulatory sense by then. They are tradable instruments. The land underneath them is the bearer certificate.