ERCOT PCLR: trading firm transmission for time-to-energization in Batch Zero

ERCOT (the grid operator that runs almost all of Texas’s power market) has historically connected new electricity customers one at a time, assuming each new factory or building adds modestly to demand. The current backlog of giant data centers does not fit that model: under the old “fully firm” rules — meaning the grid promises to serve the load 100% of the time, no matter what — every new request has to wait years for new transmission lines to be built. To clear the pile-up, PGRR145 and NPRR1325 (the protocol amendments ERCOT filed on March 4, 2026) create a one-time review window called Batch Zero — the very first scheduled review window with a hard April–July 2026 deadline — that processes every backlogged project together under a shared reliability standard. ERCOT’s Board is scheduled to approve the rules on June 1, 2026.

The fast-pass tool inside Batch Zero is called PCLR (Permanently Co-Located Resource — ERCOT’s regulatory category for a private power plant that lives next to a single big load like a data center and can’t share with anyone else). Practically: a developer splits its requested megawatts (MW) into two slices. The firm slice (LPC, or Low Power Consumption) gets the same iron-clad service as a normal customer using transmission that already exists. The flexible slice agrees that whenever the local grid gets congested, ERCOT’s five-minute dispatch engine (SCED) can order the load to drop. In exchange, that flexible slice gets to plug in years before new transmission would arrive. Earlier voluntary flexibility products in ERCOT paid the load to occasionally curtail; PCLR is the opposite trade — the load is required to curtail when told, in exchange for being allowed to connect at all.

Hard deadlines

Texas projects already sitting in the old queue have roughly 14 weeks to decide whether to opt in. Miss the July 24, 2026 declaration and the project stays on the slow firm-queue path; miss the March 2027 Interconnection Agreement (IA) execution and the capacity reservation disappears entirely.

How dispatch works: the Adjusted Bid Cap

How often a PCLR site actually gets ordered to curtail comes down to one formula, the Adjusted Bid Cap (ABC). It’s the maximum price ERCOT will let the load “bid” for energy when the local grid is congested — and any time the real price tops that cap, the load gets dropped:

ABC = System Lambda − max(MaxShadowPrice × ShiftFactor) − $0.01 / MWh

In plain English, the formula does three things. First, it starts with the statewide energy price (System Lambda). Second, it subtracts the single biggest contribution this site is making to the worst local grid bottleneck, calculated as the “shadow price” of that bottleneck (the dollar value of relieving it) multiplied by the site’s “shift factor” (how much electricity the site pulls through that specific congested wire). Third, it subtracts one cent. That penny is a tiebreaker: it guarantees the flexible load gets curtailed before any competing power plant is told to back off. Whether a site is economical depends on its specific shift factor times the historical congestion at its specific location on the grid. Sites near chronic bottlenecks get curtailed often and may lose most of the flexible MW during summer peaks. Sites in uncongested areas almost never trigger the cap. There is no commercial software today that calculates this per-site.

Financial commitments and live branches

In parallel, the Public Utility Commission of Texas (PUCT, the state agency that regulates electric utilities) is writing the rules for how much money developers must put down to hold their place in line. Rulemaking Project 58481 (which writes a new section, 16 TAC §25.194, into the Texas Administrative Code) has a draft “Proposal for Publication” on the table that requires $50K/MW in financial security at the intermediate stage plus a separate $50K/MW non-refundable connection fee due when the Interconnection Agreement is signed. Multiple competing proposals are still on the table: the Office of Public Utility Counsel (OPUC, the consumer-side advocate) wants $100K/MW security; an industrial customers’ group (TIEC) wants $20K/MW for projects under 250 MW; utility Oncor wants to replace the non-refundable fee with a 10-year take-or-pay capacity contract for projects over 200 MW; and Google, Lancium, and Total argue the deposit should grow in steps as the project passes milestones. Final rules are expected Fall 2026. Until then, any Cliff financial scenario for a Texas site should expose these branches as toggles.

The bigger pattern

PCLR is part of a larger national shift. The Southwest Power Pool (SPP, the grid operator covering the Plains states) already has a similar mechanism called HILLGA / LLRIS (FERC Docket ER26-247, effective January 15, 2026); it is currently the only fully-approved curtailment-for-speed program in the U.S. and ERCOT cites it as precedent. PJM (the grid operator covering the Mid-Atlantic and parts of the Midwest) is working on its own version — see the companion post on PJM’s flex interconnection year. Above all of them, the Federal Energy Regulatory Commission (FERC, the federal agency that oversees the wholesale electricity grid) is working on a national rule, RM26-4-000, that creates the legal umbrella for these programs. FERC’s original deadline to finalize was April 30, 2026, pushed to end of June 2026 by an “Order Regarding Intent to Act” issued April 16, 2026. The proposed rule would let any curtailable load over 20 MW finish its grid-impact studies in as little as 60 days, compared to roughly 3 years today.

What Cliff is building

Cliff is building the per-site math that answers whether a given Texas data center site should opt into PCLR: estimating the shift factor at that location, modeling the Adjusted Bid Cap under best-case (p50) and stress-case (p90) congestion scenarios, projecting how often the site would actually be curtailed in a typical year, and comparing that to the cost of waiting years for fully-firm service. This is a different shape of product than our PJM de-rate calculator — that one is driven by air-permit limits on backup generators; this one is driven by grid-market math (shift factor × shadow price × ABC formula). If you have a Texas project sitting in the old queue and need to make a go / no-go decision in the next 14 weeks, talk to us.

Primary sources

• ERCOT PGRR145 (Batch Zero Process for Large Load Interconnections)
• PUC Project 58481 (16 TAC §25.194 Large Load Interconnection Standards)
• Arushi Sharma Frank, “Flexible Loads in ERCOT = Provisional CLRs” (Luminary Strategies, Apr 9, 2026)
• Frank, “From Bottlenecks to Breakthroughs” (CSIS, Jul 23, 2025) — the theoretical foundation
• ERCOT Large Load Interconnection Process Q&A (Dec 23, 2025)

Glossary

ERCOT

Electric Reliability Council of Texas. The grid operator that runs almost all of Texas’s power market and decides who gets to plug in.

PUCT

Public Utility Commission of Texas. State agency that regulates electric utilities and writes the rules ERCOT operates under.

FERC

Federal Energy Regulatory Commission. The federal agency over wholesale electricity, interstate transmission, and the grid operators (ERCOT, PJM, SPP, etc.).

Batch Zero

ERCOT’s one-time, deadline-bounded review window (April–July 2026) that clears the backlog of giant-load interconnection requests as a single cluster instead of one-by-one.

PCLR (Permanently Co-Located Resource)

ERCOT’s regulatory category for a private power plant living next to a single big load (like a data center) that can’t share its output with the grid; used here as the fast-pass mechanism inside Batch Zero.

SCED

Security-Constrained Economic Dispatch. ERCOT’s automated engine that decides every five minutes which generators run and at what price; for PCLR, it’s also what orders flexible loads to drop.

Shift factor

The fraction of a site’s electricity demand that physically flows through a specific congested transmission line. Higher shift factor on a stressed line = more frequent curtailment.

Shadow price

The dollar value, in $/MWh, of relieving one more megawatt of congestion on a specific transmission constraint. Comes out of ERCOT’s dispatch math.

System Lambda

The statewide marginal electricity price ERCOT publishes — the price of the next MWh if there were no transmission limits.

Adjusted Bid Cap (ABC)

The price ceiling SCED applies to a PCLR’s energy bid during local congestion; if real prices top the cap, the site is curtailed. Formula: System Lambda − max(Shadow Price × Shift Factor) − $0.01.

Interconnection Agreement (IA)

The signed contract between a load (or generator) and the utility / grid operator that locks in physical connection rights, financial commitments, and timing.

NPRR / PGRR

Nodal Protocol Revision Request / Planning Guide Revision Request. ERCOT’s mechanisms for amending the rulebooks that govern the wholesale market and grid planning.

16 TAC §25.194 / §25.370

Sections of the Texas Administrative Code where the PUCT writes its rules for large-load interconnection and forecasting.

SPP / HILLGA / LLRIS

Southwest Power Pool (Plains-states grid operator) and its High-Impact Large Load Generator Aggregation / Large Load Rapid Interconnection Service — the only fully-approved U.S. curtailment-for-speed program today; the precedent ERCOT cites.

PJM

Mid-Atlantic / Midwest grid operator. Working on its own version of curtailment-for-speed in parallel.

Firm vs flexible load

Firm load is served 100% of the time, no matter what (the traditional default). Flexible load can be ordered to drop during congestion in exchange for plugging in faster.