Grid Interconnection vs. Behind-the-Meter Power

Two paths to energizing a large load - compared on the dimension that decides projects: time.

The Decision Every Large Load Faces

If you need 100 MW or more by 2028, you have two realistic paths: wait for a utility interconnection, or build dedicated generation on site. The right answer depends on your timeline, your market, and your tolerance for schedule risk - but the comparison should be made with real numbers, not optimism.

This page lays out both paths the way a procurement or diligence team would: step by step, with the schedule drivers named.

5+ yrs

Widely reported interconnection waits for large loads in major U.S. markets

~24 mo

Smartland target from Notice to Proceed to power online

The Two Paths, Step by Step

Path 1: Utility Interconnection

Schedule controlled by the utility and the regional queue.

1

Application and queue position

Load study request, deposits, and a place in line behind every project ahead of you.

2

Studies and system upgrades

Feasibility, system impact, and facilities studies - then transmission or substation upgrades if the grid can't serve the load as-is. This is where years are added.

3

Energization - on the utility's schedule

Timing depends on upgrade construction and queue movement. Waits of five or more years for large loads are widely reported across major markets.

Path 2: Dedicated BTM Power

Schedule controlled by the project, tied to Notice to Proceed.

1

Capacity reservation

Define load, density roadmap, and timeline; reserve capacity at a defined Point of Delivery under contract.

2

Notice to Proceed

From NTP, schedule is driven by permitting, equipment lead times, and site-specific scope - factors a developer manages, not a queue.

3

Power online in ~24 months

Modular 10 MW RICE generation commissioned in blocks, delivered through an N+2 architecture with A/B feeds at the POD, governed by a contract-backed SLA. See the platform →

When Grid Power Is Still the Right Call

Dedicated generation is not the answer to every load. If your timeline is flexible, your market's queue is short, or your load is small enough to be served from existing capacity, a standard interconnection may cost less and carry less complexity.

Where dedicated behind-the-meter (BTM) capacity wins is when the calendar is the constraint: compute roadmaps measured in quarters, contractual go-live dates, or resilience requirements the grid cannot guarantee. Many operators run both paths in parallel - BTM capacity energizes the first phases while the interconnection matures.

What This Means for 2028 Planning

A load that needs power in 2028 and enters a multi-year queue today carries schedule risk no contract can hedge. Smartland Energy's initial capacity is targeted to come online in Q3 2028, with capacity reserved in advance at a defined Point of Delivery.

How to secure 100-400 MW by 2028 →

Download the brief: The 24-Month Path to Power (PDF) →

Common Questions

How long do interconnection queues actually run?

It varies by utility and region, but multi-year waits are standard for loads above 100 MW, and waits of five or more years are widely reported in major markets.

Is BTM reliable enough for compute?

The platform is designed around N+2 redundancy, A/B delivery at the POD, and a contract-backed SLA with defined outage classifications - terms written for procurement and lender review.

Can I do both?

Yes. Dedicated BTM capacity can energize early phases on a known schedule while a utility interconnection matures in parallel. The paths are complementary.

Power online ~24 months from Notice to Proceed.

Initial capacity is targeted to come online in Q3 2028. Contact our team to discuss your power infrastructure requirements and reserve capacity.

Book a 15-Min Call (877) 313-5777