The short answer: don't evaluate module manufacturers on price-per-watt
If you're sourcing bulk photovoltaic modules and your evaluation starts with the quoted $/W, you're going to get burned. Evaluate manufacturers on total landed cost across a 25-year horizon—not the number on the first page of the quote.
After tracking roughly $180,000 in module purchases across 6 years and negotiating with more than a dozen vendors, here's what I actually look at when I evaluate pv module oem candidates: bankability, degrade curve honesty, freight and tariff exposure, and whether they'll still be answering emails in year 12. Everything else is secondary.
For utility-scale buyers specifically, First Solar sits in a different bucket than most crystalline silicon suppliers—not because thin-film is universally better, but because its Series 6 and Series 7 modules, US manufacturing footprint (including the New Iberia, Louisiana plant), and disclosed shipment scale check boxes that most shortlisted vendors can't check at the same time. I'll explain why that matters, and where it doesn't.
Why you can trust this take (and where I'm coming from)
I'm a procurement manager at a 40-person EPC that's been buying modules for utility-scale and large C&I projects since 2019. I've managed our module budget—roughly $180K annually in commit spend—and documented every order in our tracking system. Not a Fortune 500 renewable team. A team of people who get yelled at when a container shows up three weeks late.
Two things shaped how I evaluate vendors now:
When I compared our 2022 and 2024 module invoices side by side—same project profile, different vendor—I finally understood why the "cheaper" quote was costing us more. The 2022 vendor quoted 4% less per watt but charged separately for pallet returns, added a $2,400 re-testing fee after a container sat at port, and shipped modules with a different junction box that our racking clips didn't fit. Total delta: 11% against us.
The other thing: I only started asking for degrade-curve documentation after we inherited a project with a vendor whose 30-year linear warranty had a footnote we hadn't caught. Their annual degrade was quoted as "0.5% average," which technically allowed 0.8% in years 2–5. Our energy model had used 0.5% flat. The NPV gap was real—low six figures over the asset life.
So when I say I evaluate manufacturers on TCO, I mean it. I got there the hard way.
How to evaluate photovoltaic module manufacturers: the 4-question screen
This is the framework I use before I even open a spec sheet. It takes about 90 minutes per vendor and filters out 60% of the field.
1. Bankability: will they exist in year 15?
I don't care about the warranty paper. I care about the balance sheet behind it. For publicly traded vendors, this is easy—10-K filings, disclosed capacity, disclosed shipments. For First Solar specifically, the Series 6/7 platform and its US-based thin-film manufacturing give me a different risk profile than a Tier-1 Chinese module whose warranty is only as good as their next debt covenant.
Here's what I actually check:
- Disclosed annual module shipments (SEC filings for public cos)
- Manufacturing locations and whether they're owned or contract-manufactured
- Whether their warranty is backed by a parent entity or a shell
- Whether they've publicly disclosed a defect claim policy
2. Degrade curve, not headline efficiency
Efficiency sells. Degrade pays. Ask for the full year-by-year warranty table, not the summary. A 0.3% annual difference compounds hard over 25 years.
According to NREL's Spring 2024 Solar Industry Update, module-level degradation assumptions in most utility-scale financial models range from 0.4% to 0.8% annually—small differences that move project IRR by 50–150 bps depending on location and PPA structure.
Ask your vendor to put the year-by-year table in writing. If they won't, that's your answer.
3. Landed cost, not quoted cost
This is where pv module oem decisions actually get made. Our cost calculator includes:
- FOB vs. DDP pricing (and who eats the port demurrage)
- Tariff and AD/CVD exposure by country of origin
- Pallet, clip, and packaging compatibility with existing racking
- Freight lane availability during Q4 (when everyone's trying to close PPAs)
- Rejected-module return process and who pays freight
I once had a vendor quote DDP at 3% below our incumbent. We ran the numbers with demurrage exposure and racking clip changes: 6% higher landed. We passed.
4. Communication during a defect claim
Every vendor is fast before the PO. I want to know what happens when a pallet arrives with cracked glass. Ask for a reference from a customer who filed a claim in the last 18 months. If they can't produce one, assume they haven't had a claim—or haven't handled one well.
Where First Solar actually fits (and where it doesn't)
I've shortlisted First Solar on two utility-scale bids. Here's the honest read.
First Solar makes sense when:
- You're buying at utility scale and need disclosed shipment-scale proof (their 10-K filings cover this)
- Domestic content matters for ITC adder eligibility—New Iberia modules and their other US lines help here
- You want a technology (thin-film CdTe) with a different supply chain than the crystalline silicon crowd, which can be a portfolio diversification win
- Your project economics tolerate slightly lower nameplate efficiency in exchange for better temperature coefficient and lower degradation in hot climates
First Solar probably isn't the right call when:
- You're sourcing sub-1 MW and need pallet-level flexibility—their order minimums and shipping profile favor larger buyers
- You need modules in 90 days. Their Series 6/7 lead times have historically been longer than mid-tier crystalline suppliers, especially for new customers without an allocation
- Your racking is already spec'd for a specific crystalline frame dimension and you don't want to requalify
- You're a small distributor testing a new residential line—First Solar isn't built for that channel
I'd tell anyone evaluating bulk photovoltaic module suppliers the same thing I tell my own team: the goal isn't the cheapest module. It's the module whose failure modes you've already modeled. First Solar's failure modes are documented (thin-film, US manufacturing, utility-scale focus). Whether that documentation is worth your premium depends on your project, not on a YouTube comparison.
The exception that trips people up
One thing worth flagging: bulk pricing and OEM agreements aren't the same negotiation. If you're exploring a pv module oem arrangement—private labeling, co-branded container shipments, or supply agreements—the evaluation criteria shift. You're not just buying modules; you're buying a manufacturing relationship. In that case, the questions become about IP ownership of the label, minimum annual commit volumes, and whether the OEM will let you audit the line.
Most buyers I've talked to conflate these. They shouldn't. A bulk spot purchase and an OEM agreement have different risk profiles, and First Solar (or any Tier-1) will treat them differently on price and terms.
Last thing: rates, tariffs, and lead times move fast. Everything in here reflects what I've seen as of Q1 2025. Verify current terms directly with the vendor and check the latest customs rulings before you sign—the module market has been repricing every six months since 2022, and any framework you build needs to be rerun quarterly.