The case

The application that gets picked.

Buy the interconnect. Permit the cooling. Host the IT.

The interconnect approval queue decides who wins compute capacity — not GPUs. Undifferentiated 50 MW interconnect filings wait. You are not buying solar. You are buying an existing grid connection and filing a load the operator can say yes to. Texas (Pecos) is the worked example. The same two clocks exist on every grid: power out, and permission to pull power in after dark.

CFO: Economics
CTO: Cooling & generation
Counsel: Permitting

Firm offtake, flex hours, and what the overlay costs.

The purchase

Buy the interconnect. Overlay cooling. Host 50 MW of firm IT.

This is a real-estate and cooling purchase, not a generation bet. The cooling overlay is quoted at $0.6–0.9M per MW of firm IT you can contract — ~$30–45M for this 50 MW conversion.

Acquire: 100 MWdc, commercial operation 2021 or earlier. The interconnect comes with the deed.
Overlay: ~$30–45M cooling plant. Quoted per MW of IT you can contract — not per MWdc of modules. Fifty acres of tables, not the whole field.
Host: 50 MW of 99.9% firm AI in 6–12 months. Dry coolers stay as fail-safe.
Earn: Phase 1: $150M/year on 50 MW firm. Full platform: $333M/year on 111 MW firm. 154 MW flex is extra hours, not a second $3M contract.
Time: A new interconnect is 5–7 years. This plant already exports. Overnight import is 54 MW, not 62.5.

CFO

Compare $0.6–0.9M per MW of contractable IT to on-site engines and to a new interconnect.
Phase 1 floor is 50 MW firm — $150M per year at a planning value of $3M per MW-year. Full platform firm is 111 MW — $333M per year. Same planning rate.
154 MW is peak / flexible hours. Extra compute when weather and storage allow. It is not a second firm offtake.
Phase 3 is a residual plant: ~22–28 MW of engines, not 54. It holds 50 MW inside an air permit that would refuse a 54 MW yard. 111 MW is the wire coming off, not a bigger stack.
The ~$30–45M invoice is what makes 50 MW of firm AI contractable. It is not a kWh-savings project.
Construction follows a 50-acre radiator reservation on the fenceline you already own. Remaining PV stays generation.
The farm bid is a separate energy-asset purchase. The overlay is the cooling invoice. GPUs stay on the customer’s books.

CTO

Midday surplus can run conventional chillers. After sunset there is no array to run them, and on the hottest afternoons dry coolers cannot reject 50 MWth.
When outdoor air is as hot as the loop, 50 acres of radiator tables dump 50 MWth. 50 MW of IT draws 54 MW at the meter at PUE 1.08 — modeled facility load, not a site cap. That draw sits under ERCOT’s 75 MW large-load threshold.
At the meter: 54 MW with Komorebi (PUE 1.08) versus 62.5 MW with chillers. Same 50 MW of IT. Dry coolers remain as fail-safe.
Phase 1 is grid-tied and thermally firm on a Pecos design day. Phase 2 plumbs TES/ORC so islanded operation is a residual engine plant — the filing, not a second offtake. Heat to electricity first. Engines last.

MWdc is the farm you buy and pipe. MW AC is what the interconnect carries. MW IT is the compute you contract.

First commercial plant

Scale from a 10 MW Phase 1 plant.

That is the first plant we contract. Other sizes stay linear with the 100 MWdc existing-PV conversion.

Phase 1 additional firm AI compute10 MW10 MW150 MW

Fast-track AI compute: 10 MW
Additional modeled AI compute: +12.2 MW
99.9% firm at maturity: 22.2 MW
Peak / flexible: 30.8 MW
Repowered PV: 19 MWdc
Recovered CSP: 18.8 MWth

Illustrative enabled-compute value, at $3M per incremental MW-year: $30.0M / year

Qualify this size

Permitting and economics per additional MW of AI

Capex, water, noise, air, and time are the same decision. Cooling-first reuses a permitted interconnect and avoids a new chiller yard. Time is to additional IT, not to a greenfield campus. Texas is the worked example; the comparison holds on other grids.

Path	$M / AI MW	Fuel exposure	Gen. water	Cooling water	Time	Emissions / noise
Komorebi cooling-first	$0.6–0.9M	Low	None added	Low	6–12 mo	Low
Reciprocating gas engines	$1.5–2.2M	Medium	Medium–high	Mechanical cooling	12–24 mo	Medium
Komorebi full platform	$2.3–3.6M	Low	None added	Low	Staged	Low
Aeroderivative simple-cycle GT	$3.2–4.6M	High	High	Mechanical cooling	24–36 mo+	High
Fuel cells	$4.9–8.0M	High	Low	Site cooling still required	18–30 mo	Low stack, fuel upstream

Reciprocating engines are typically more efficient than simple-cycle aeroderivative turbines. Combined-cycle GTs are not in this table. Fuel-cell generation-side water is Low in normal operation.

Indicative cost of energy that reaches the halls — $ / MWh

Cooling-first cuts overhead at the meter, so more of each purchased or generated MWh reaches IT. That is not a generation LCOE. Generator rows below are conventional generation LCOE.

Path	$ / MWh	Basis
Komorebi cooling-first	$40–60	Delivered to AI compute — overhead reduction
Reciprocating gas engines	$55–85	Generation LCOE
Komorebi full platform	$35–55	Delivered to IT — duration and ORC hours
Aeroderivative simple-cycle GT	$70–110	Generation LCOE
Fuel cells	$95–145	Generation LCOE

Figures are from two illustrative U.S. planning cases — a Pecos Campus Case (300 MW existing IT at PUE 1.25, 375 MW campus electrical, WUE 1.5 L/kWh, 1,000-acre envelope) and a 100 MWdc Existing PV Farm Conversion Case — based on 2025 public benchmarks. Grid envelope stays 375 MW through Phase 2. Phase 1: 51 MW freed ÷ PUE 1.08 = +47 MW IT. Recovery then 1.05 → 1.04; Phase 3 campus grows only from on-site generation. Actual results vary by site, resource, fuel, interconnection, and execution. Patents pending. Not an offer.

Worked example · 100 MWdc existing PV · Pecos, Texas

Book 50 MW firm. Treat later MW as options.

Phase 1 is the underwritten case — grid-tied, cooling on 10% of tables, 50 MW of design-target 99.9% firm AI at the existing meter. Remaining PV stays generation. Leftover acres can take Phase 2 CSP steel on concrete rail. TES/ORC is Phase 2: the filing, not a second offtake. Phase 3 is a residual engine plant: it holds 50 MW if overnight service is delayed, or if a 54 MW yard will not permit. 111 MW is the interconnect coming off, not a bigger stack.

Phase 1 — cooling: +50 MW AI
Full platform — firm: 111 MW AI
Peak / flexible: 154 MW AI

Starting plant is 100 MWdc on the same land. Re-module keeps 100 MWdc of PV on a denser pad. Fifty acres convert to radiator tables. Leftover acres can take Phase 2 CSP steel. TES/ORC is Phase 2. Engines are last.

$150M / year — Phase 1 firm

50 MW of design-target 99.9% firm AI × $3M per MW-year planning value. A planning year, not a live meter.

$333M / year — 111 MW firm

Option on the same land. Same $3M rate. Not in the Phase 1 offtake.

154 MW peak / flexible

Not a second firm contract. Extra hours. Do not book at $3M per MW-year.

Phase 3 is a residual engine plant. TES/ORC runs first, so shaft is about 22 MW in summer and 28 MW in winter — not 54, and not 62.5 if the hall were chilled. That is the plant air, noise, and water will consider. It holds 50 MW when overnight service is delayed, or when a 54 MW engine yard would not permit. 111 MW firm is the interconnect coming off, and only if that residual plant still permits. Recovered heat, not a bigger stack. Not in the Phase 1 offtake.

Eight-day Pecos screen on the radiator campus: 50 MW firm served in the window, PV held at 100 MWdc, 50 acres reserved for tables. A full-year radiator-campus run is not yet the published design target. Prior whole-field radial year is not this plant. A 10 MWdc pilot — about 5 MW of firm IT — is the step that validates hot-day performance, parasitic demand, and ground-temperature behavior at commercial scale.

Compared with

The metric is firm IT.

Two comparisons. First: conversion of an already-connected solar deed into a 50 MW IT host this year — no interconnect and no 24/7 heat sink is 100% of nothing. Second: 8.5 MW less parasitic load versus PUE 1.25 at the same 50 MW IT. Book Phase 1. Treat later MW as options.

A new interconnect or a new plant
A site with no interconnect and no 24/7 heat sink this year is 100% of nothing in IT offtake. That is a 5–7 year clock. This farm already exports. Overnight import is a separate filing. 54 MW is the modeled meter draw at PUE 1.08, not a new generation tie.
8.5 MW less parasitic load
Same 50 MW of IT: 54 MW at the meter at PUE 1.08 versus 62.5 MW at PUE 1.25. That incremental comparison is second. Releasing 8.5 MW of parasitics is what makes 50 MW contractable at a planning value of $3M per MW-year.
On-site engines for the 50 MW
A 54 MW engine yard often will not permit. TES/ORC first, so islanded shaft is ~22–28 MW. That residual plant holds 50 MW when overnight service is delayed, or when combustion is the constraint. Engines last. Not the base offtake.
More batteries as the cooling plant
A pack can run compressors. It cannot dump server heat. Every MWh spent on chillers is a MWh that never reaches GPUs.

Why the overlay beats a new plant

Lower capex per additional MW of AI than recips or simple-cycle GTs — and no new water right or chiller-yard air permit
Reuses the interconnect and land you already have, or makes a campus you already permit hold more IT
The array stays PV. A 50-acre radiator reservation is the 24/7 cooling plant — then AI compute on the interconnect you already have
If overnight service is delayed — or the air permit cannot take 54 MW of engines — Phase 2 TES/ORC is already in, so the islanded plant is ~22–28 MW, not a 54 MW engine yard

Request the briefing pack

Buy the interconnect. Permit the cooling. Host the IT.

Buy the interconnect. Overlay cooling. Host 50 MW of firm IT.

CFO

CTO

Scale from a 10 MW Phase 1 plant.

Permitting and economics per additional MW of AI

Indicative cost of energy that reaches the halls — $ / MWh

Book 50 MW firm. Treat later MW as options.

The metric is firm IT.

A new interconnect or a new plant

8.5 MW less parasitic load

On-site engines for the 50 MW

More batteries as the cooling plant

Why the overlay beats a new plant