Data Center
Interconnection and Compliance
Interconnection and Compliance
Model the load. Prove compliance. Interconnect faster.
2026
AUGUST 3, 2026
Every utility in North America must report to FERC how they will handle loads like yours.
THE ALERT NAMED YOU
Computational Load Entity: ≥ 20 MW connected at 60 kV, with more than 1 MW of IT load. AI training, inference, crypto, and traditional data centers all qualify.
SEVEN ESSENTIAL ACTIONS NERC IS DIRECTING
01
MODELING DATA
Detailed dynamic models, separately for IT and non-IT load.
02
STUDIES
SOLs, P-Q / P-V analysis, contingency planning for aggregate loss.
03
QUALIFIED CHANGE
Even repurposing crypto to AI triggers a new study.
04
COMMISSIONING
As-built model verification, full and no-load testing, ±10% voltage tests.
05
PROTECTION COORDINATION
Ride-through to equipment capability. No firm load loss from cleared faults.
06
FAULT RECORDING
Continuous monitoring + trigger-based high-resolution capture.
07
OPERATIONAL COMMUNICATION
Voice and SCADA channels with TOPs, RCs, BAs.
SCALE
1–2 GW
per campus
Hyperscale and AI training campuses now propose individual sites at the size of the largest fossil plants. Demand growth is the highest in two decades.
SPEED
5→30 MW
in seconds
AI training cycles ramp real power faster than conventional generators can follow. Step changes the size of a peaker plant, on a single facility, in seconds.
SHAPE
40–60%
power electronics
Servers, GPUs, UPS systems, and VFD-driven cooling are converter-based loads. They behave nothing like motors. The grid models them as motors anyway.
JULY 10, 2024
1,500 MW
lost in 82 seconds
A single 230 kV fault in the Eastern Interconnection. Six reclose attempts. Voltage-sensitive data center loads tripped simultaneously. Many facilities transferred to UPS or backup power. Some required manual reconnection.
Source: NERC Incident Review
ERCOT WEST TEXAS
50%
of LEL load at risk
ERCOT modeling of a severe West Texas fault (voltage dip below 0.70 p.u. for over 20 ms) projects a 1,500 MW Large Electrical Load loss. Enough simultaneous loss to threaten conventional generators' own ride-through margins.
Source: ERCOT June 2025 LEL Workshop
Real events on the system. Federal and regional regulators are responding to what they have already seen, not theoretical risk.
2025
OCT 2025DOE Section 403 letter directs FERC to standardize >20 MW load interconnections.
NOV 2025ERCOT NOGRR-282 ride-through requirements adopted (57–61.8 Hz / 299s; 0.20 p.u. / 150 ms).
DEC 18 2025FERC finds PJM tariff 'unjust and unreasonable' for AI/co-located large loads (EL25-49).
2026
APR 30 2026FERC final action deadline on DOE 403 large-load rulemaking.
MAY 4 2026NERC Level 3 Alert issued. Distribution to every TO/TP/BA/RC/TOP.
AUG 3 2026NERC Level 3 Alert reporting deadline. U.S. responses aggregated to FERC.
2027
Q1–Q2NERC Project 2026-02 standard ballot. First mandatory standard for computational loads.
Q2–Q3PJM tariff revisions per FERC EL25-49 directive in effect across co-located queues.
Q3ERCOT NPRR 1308 LLIS Phase 2 implementation; ride-through testing baseline.
Q3–Q4AESO Phase 2 capacity allocation framework launches following Phase 1 cap.
THROUGHOUTDominion PEILL v2; CAISO PTOs publish standardized data center handbook updates.
2028
JANERCOT deep voltage sag cliff. Proportional consumption mandatory at 0.5–0.8 p.u.
Q1–Q2NERC computational load registry fully operational. CLE registration enforceable.
Q2First-wave 90-day investigation triggers active for non-compliant facilities.
Q3PJM, MISO, ISO-NE align composite load model and dynamic data expectations.
Q4GO/GOP-style obligations begin for large load owners.
2029-30
Q1 2029Cross-region NERC reliability standard updates rolled out. EMT/RMS dual-model baseline.
Q2 2029International alignment: IESO Ontario and AESO Alberta data center frameworks harmonized.
Q3 2029FERC oversight reviews of regional implementations; refiling cycle begins.
Q1 2030Sunset for legacy load models in TP/PC submissions. EMT becomes the floor.
THROUGHOUTHyperscale procurement specs assume regulatory baseline; EMT is no longer a differentiator.
ERCOT
≥75 MW LLI · ≥25 MW visibility
NOGRR-282 ride-through · NPRR 1308 LLIS
ACTIVE
PJM
Manuals 14H / 14C / 14G
FERC EL25-49 directive (Dec 2025)
RULEMAKING
DOMINION
PEILL ≥ 50 MW
PSS/E dynamic models · six-event ride-through
ACTIVE
SPP
HILL framework
~90-day study, RR696
ACTIVE
MISO
TO-led with MISO planning
MTEP Attachment FF · local TO guides
ACTIVE
NYISO
TEI process
SIS/SR with dynamics + telemetry
ACTIVE
CAISO
Via PTOs (PG&E / SCE / SDG&E)
PG&E TIH primary reference
ACTIVE
ISO-NE
PTO-led
PP5-6 studies · composite load model
EVOLVING
AESO
Phase 1 cap: 1,200 MW DTS
Phase 2 consultations underway
CAPACITY-LIMITED
IESO
≥20 MW step loads recognized
Market Rules Ch. 4
EVOLVING
Common floor: dynamic models, ride-through, telemetry, curtailment terms. The DOE 403 push standardizes the floor; regional specifics layer on top.
TYPICAL DATA CENTER LOAD COMPOSITION
SERVERS
30–40%
COOLING
20–40%
UPS / PDU
10–15%
STORAGE
5–10%
NETWORKING
5–10%
AI TRAINING IN ONE CHART
Real measurement: a 5 MW baseline jumps to a 30 MW sustained load during a training cycle. A two-minute drop. Then back to 30 MW. These are step changes the size of a peaker plant, happening on a single facility in seconds.
Source: EdgeTunePower measurement, presented at NERC LMWG
Up to 75% of a data center's load is converter-based. Steady-state phasor models cannot capture the switching, harmonic injection, or fault behavior of converters.
WHAT CMLD MODELS SHOW
A clean voltage event
Smooth sag · clean recovery · no reclose
WHAT ACTUALLY HAPPENED
July 10, 2024
Fault · swell · five recloses · sub-cycle detail
×
NO VOLTAGE SWELLS
Real grids have both. Swells damage power supplies.
×
NO TIME DELAYS
Real protection has delays. The delays are what matter.
×
NO AUTO-RECLOSING
Real faults always reclose. July 10, 2024 had six.
×
VOLTAGE-ONLY TRIGGERS
Real data centers trip on frequency too.
×
AGGREGATED LOAD
Real facilities have layered, vendor-specific protection.
Source: PSS®E PAG · Elevate Webinar Series #2 (Jul 2025)
OLD
PSPD / RMS / PHASOR
~4 ms (¼ cycle)
TIME STEP
CAPTURES
Steady-state
Slow dynamics below 10 Hz
MISSES
Sub-cycle transients
Harmonic interactions
Weak-grid behavior
DC-link protection trips
NEW
ELECTROMAGNETIC TRANSIENT
10–50 µs (sub-cycle)
TIME STEP
CAPTURES
Full waveform
Sub-cycle transients
Harmonics
Fast switching
Weak-grid behavior
REQUIRED FOR
Power-electronic load
Ride-through proof
DC-link protection
NOGRR-282 compliance
When NERC says verify ride-through, they mean EMT.
When ERCOT says demonstrate NOGRR-282 compliance, they mean EMT.
When your TO won't approve a study, this is why.
When ERCOT says demonstrate NOGRR-282 compliance, they mean EMT.
When your TO won't approve a study, this is why.
Source: NERC Data Center Load Modeling Tech Ref R1 · GridStrong Two-Pager
LOAD CHARACTERIZATION
INTERCONNECTION STUDIES
RIDE-THROUGH COMPLIANCE
PROTECTION COORDINATION
EMT MODELING
The wedge.
FAULT RECORDING
TELEMETRY & VISIBILITY
REGULATORY FILING
COMMISSIONING SUPPORT
Seven of seven NERC Level 3 essential actions covered. One firm. One platform.
91,000+
REQUIREMENTS INDEXED
Every NERC, regional, and ISO standard parsed into a structured database. Cited automatically in every study, every filing, every model package.
OEM
DATA MOAT
VENDOR DATABASE
Protection systems, power plant controllers, fault recorders catalogued by OEM, model, and settings. No other firm has built this corpus.
PSCAD
+ PSS®E + UDM FLUENCY
Custom user-defined models that preserve OEM IP via black-box embedding. Studies clear utility review the first time, not the third.
7 / 7
NERC LEVEL 3 ACTIONS
Modeling data, studies, qualified change, commissioning, protection, fault recording, operational communication. All seven are in scope from day one.
01
LOAD CHARACTERIZATION
Full electrical characterization of power electronics, UPS, cooling, auxiliary loads. Harmonic profiles, fault current contribution, dynamic response.
02
EMT MODEL DEVELOPMENT
Detailed electromagnetic transient models capturing converter switching, control loops, and protection scheme behavior at sub-cycle resolution.
03
INTERCONNECTION STUDIES
Power flow, short circuit, stability, ride-through analysis. Grid impact studies per ISO/RTO requirements with full documentation.
04
COMPLIANCE & FILING
Ride-through compliance demonstration, NERC standard mapping, regulatory filing support. Audit-ready documentation from day one.
From kickoff to TO approval. Audit-ready by design, not by retrofit.
EMT MODELING DEPTH
We build EMT models that pass utility review the first time. PSCAD, PSS®E, and custom UDMs that preserve OEM IP. Sub-cycle resolution where it matters.
FIRST PASS
Studies clear utility review
REGULATORY FLUENCY
Every NERC standard, every regional rule, every active rulemaking, indexed and cited. We know which paragraph of which order applies before the kickoff call.
91,000+
Requirements indexed
SPEED TO STUDY
Pre-staged model libraries, parameter packages drawn from our database, audit-ready documentation by default. Weeks where competitors take months.
WEEKS
Not months
VENDOR KNOWLEDGE
Protection systems, power plant controllers, fault recorders. Every major OEM, every model, every setting catalogued. The only firm that has built this database.
OEM
Vendor-equipment data moat
01
LOAD CHARACTERIZATION
We document your facility's electrical behavior: composition, ride-through capability, ramp envelopes. Output is the parameter package your TO will need on day one of the interconnection conversation.
02
EMT MODEL
Custom EMT model in PSCAD or PSS®E, validated against manufacturer data, packaged for utility submission. Black-box wrapping if OEM IP is sensitive.
03
INTEGRATED STUDY
Ride-through, voltage sag, harmonic, short-circuit, and stability analyses. One coordinated package, one responsible firm, one set of citations.
04
FILING & APPROVAL
Compliance demonstration, regulatory filing support, TO/RTO/ISO review cycles closed out. Every assertion tied back to a NERC standard or regional rule.
Filing-ready package in months, not years. We stay through commissioning, PTO, and post-energization data verification.
LET'S TALK
30-minute discovery call. You bring the questions, we'll bring the data.
TOM SCARAMELLINO
CEO
tom@gridstrong.ai
RYAN QUINT
President & Chief Engineer
ryan.quint@elevate.energy
gridstrong.ai/contact