C&I Solar + Storage
The Discovery Tax: $16,500 a month
Hardware costs collapsed. The regulatory work didn't, and it's now one of the most stubborn soft costs in a commercial solar project. This is an anatomy of where that time goes and what it's worth.
A commercial solar project takes 18 to 36 months to develop.1 The panels go up in weeks; most of the rest is process. And that process now runs to 50.1% of system cost2 and the regulatory work is the slice that hasn't come down. With commercial system prices now rising on tariff-driven equipment costs,3 process is the cost lever developers still control.
The slice that won't fall is regulatory: requirements that vary by jurisdiction and aren't written down clearly. Agency processing times have stabilized in recent years, helped by permit software streamlining.4 What remains tricky is the variation. Requirements differ as much from one jurisdiction to the next as the timelines do, and across roughly 28,000 jurisdictions and 3,000 utilities, that variability is what drives compliance cost and time. Reviews routinely add weeks or months per project,5 and peer-reviewed analysis of 248,741 installations found that local requirement variations directly lengthen project durations.6 Storage compounds it: jurisdictions enforce different editions of NFPA 855, so the same battery design can pass in one county and fail next door.7
SEIA and Wood Mackenzie name the same issues, and note that developers navigate them largely through regional expertise and trusted relationships.8 In our interviews with C&I and community-scale developers and their consultants, that reliance showed up as the same four phases on every project:9
~40 hrs of due diligence per project before submission. The hardest hours go to confirming a jurisdiction has no clear pathway at all.
First-pass permit approval as low as ~1 in 10 in tougher markets. Interconnection: 2–3 edit rounds, a fee and weeks per round.
25–40% of projects return for redesign — an overlay district, a comp-plan clause, a county rule layered above a compliant use.
Requirements move while projects sit. One setback shifted to 500 ft over seven months. The project was dead, but they didn’t know until months later.
"The hardest part is proving a negative — that there's no pathway at all."
"The number of times we update drawings on the fly — and that is risky."
An example 1 MW C&I project in Atlanta sells ~1.42 million kWh a year.10 Every month it's stuck in permitting or interconnection instead of producing, that's $16,500 gone, $540 a day at the U.S. average commercial rate.11 That's one project, one month; across a portfolio it adds up fast.
And forgone revenue is only half of it. Once a developer has sunk capital into a project — land, engineering, equipment, deposits — that money carries a cost whether the project is producing or stuck. On a roughly $1.55 million system, the carrying cost alone runs $340 to $425 a day, every day it sits in review.12 Delay doesn't just postpone the upside; it bleeds the balance sheet while you wait.
That's the visible cost. The invisible one is worse: the project that dies after you've spent two years and real money getting it to the finish line.
Complete, current requirements don't change a reviewer's discretion, a hearing schedule, or a utility's study queue. In some territories, interconnection backlogs take years..13 That's the people element: the judgment and relationships your team is right to own, and that no dataset should replace.
What complete requirements do remove is everything upstream: the discovery hours, the resubmissions from wrong or outdated requirements, the redesigns triggered by provisions nobody surfaced, and the projects quietly killed by a code change nobody was tracking. That's the Discovery Tax, and unlike the queue, it's optional.
The requirements intelligence underneath the permit.
Fordje structures the full regulatory picture for a project — the codes, the checklists, the fee schedules, the buried requirements that decide a permit — laddered to the right city, county, state, and utility, and kept current as codes change. Your team has it correct on day one, so you avoid the bottlenecks at permitting and interconnection instead of discovering them there.
- SEIA / Wood Mackenzie, U.S. Solar Market Insight, Q2 2024 (18–36 mo commercial development timelines).
- NREL/TP-7A40-92536 (Jan 2025), Fig. 4: commercial soft cost 50.1% of total installed cost in 2024, near half since 2014.
- SEIA / Wood Mackenzie, SMI Q2 2026: commercial system pricing +4% YoY to $1.67/Wdc; BOS equipment +60% YoY.
- O'Shaughnessy, Barbose & Wiser, "Patience is a virtue," Energy Policy (2020): durations stabilized after streamlining; variation within jurisdictions is as large as across them. Residential data.
- NREL, Solar PII Timelines: jurisdictional reviews routinely add weeks or months per project.
- O'Shaughnessy et al., "Effects of local permitting and interconnection requirements on solar PV installation durations," Energy Policy 161 (2022): 248,741 systems.
- Energy-Storage.News (2026): jurisdictions enforce differing NFPA 855 editions; early AHJ coordination required where adoption lags.
- SEIA / Wood Mackenzie, SMI Q2 2026: permitting headwind through 2031; interconnection delays reduce 2026 commercial installs in NY & MA.
- Interviews conducted by Fordje with C&I and community-scale developers, corporate solar buyers, and consultants, May–June 2026. Practitioner estimates, not audited data.
- NREL PVWatts: 1,000-kWdc fixed open-rack, Atlanta GA = 1,424,945 kWh/yr. Varies by location and design.
- U.S. EIA, Electric Power Monthly, Table 5.6.A: U.S. commercial avg 13.92¢/kWh (Mar 2026), up from 13.16¢ YoY; GA avg 11.57¢.
- NREL/TP-7A40-92536, Table A-1: 2024 commercial benchmark $1.55/Wdc (3-MWdc reference). Carrying cost assumes 8–10% cost of capital (stated assumption).
- IREC, Improving Interconnection Timelines: documented DER backlogs, incl. 300+ projects queued at a single utility.