Quick answer
Front-of-meter solar or storage connects on the grid side of the relevant customer consumption meter; project size, ownership, market participation and approvals are separate attributes.
Answer: Front-of-the-meter solar or storage connects on the grid side of the relevant customer consumption meter, rather than primarily serving loads behind that meter. The term describes the connection and metering arrangement, not a minimum project size, ownership rule or guaranteed revenue model. Front-of-meter assets can connect to transmission or distribution networks; their market participation, approvals and payment rules remain project-specific.
What the meter boundary tells you
Identify the customer consumption meter, generation meter and point of interconnection on the project diagram. A power plant may have its own revenue meter and auxiliary loads while still being front-of-meter relative to customer consumption. “Before the meter” does not mean that the facility is unmetered.
Behind-the-meter equipment is on the customer side of the relevant consumption boundary. It can serve site loads and may export electricity if authorized. Exporting alone does not turn a behind-the-meter system into a front-of-meter asset.
The DOE’s distribution-system overview discusses both arrangements on distribution networks, including utility-managed resources and customer assets that can provide grid services. The physical boundary, ownership and service arrangement should each be recorded rather than inferred from one label.
Common front-of-meter configurations
| Configuration | What to verify |
|---|---|
| Solar selling under a PPA | Point-of-delivery energy, price, curtailment treatment and who owns environmental attributes |
| Merchant generation | Market eligibility, settlement interval, realized prices, charges and risk allocation |
| Community solar | Connection and metering arrangement plus the specific subscriber credit and eligibility rules |
| Standalone storage | Charging source, import and export limits, market qualification, efficiency and cycling constraints |
| Co-located solar and storage | Shared connection limits, meter boundaries, charging treatment and dispatch restrictions |
Not every front-of-meter project is large or transmission-connected. Distributed generation may be front-of-meter, and “utility-scale” classification depends on the source and purpose of the definition. Community solar can allocate credits to subscribers without putting the array behind each subscriber’s meter.
Front-of-meter and behind-the-meter economics
| Question | Front-of-meter | Behind-the-meter |
|---|---|---|
| Primary accounting boundary | Grid-side delivery or service settlement | Customer consumption, imports and authorized exports |
| Potential value | Contracted energy, market sales or other eligible services | Avoided purchases, eligible export compensation and other authorized services |
| Price evidence | Applicable contract or market rules | Actual customer tariff and export agreement |
| Storage assessment | Dispatch, settlement, connection and operating constraints | Load timing, tariff, backup requirements and operating constraints |
These are possible value pathways, not guaranteed income. Retail savings depend on load timing and tariff components. Wholesale or contracted sales depend on actual delivered quantities and settlement terms. Neither side has one universal price range, financing structure or permitting timeline.
Worked energy-sales example
Assume a hypothetical 100 MW AC reference capacity and a 24% annual capacity factor defined using net delivered AC energy at the modeled settlement boundary. For a non-leap year:
Annual energy = 100 MW × 0.24 × 8,760 h = 210,240 MWh
Gross energy sales at an assumed $28/MWh
= 210,240 × 28 = $5,886,720The 24% factor and $28 price are illustrative inputs, not a current Texas price quote or a site yield claim. Do not multiply an AC-defined capacity factor by MWdc. If curtailment and losses are already included in net delivered energy, do not subtract them again. With interval-varying prices, calculate each interval’s settled energy times its applicable price.
If the project separately retains and can sell one eligible REC per delivered MWh at an assumed $3/REC, the additional gross amount is $630,720, giving $6,517,440 combined gross sales. This requires verified REC eligibility, issuance and ownership; it is not additional revenue when the PPA already transfers the attributes. Neither total deducts operating, financing, settlement or other project costs.
Storage revenue needs a dispatch model
Energy arbitrage, capacity arrangements and ancillary services can be opportunities where the asset qualifies. They are not automatically additive. Dispatch commitments can compete for the same power, energy or availability, and charging costs, round-trip losses, degradation and market fees affect net value.
A front-of-meter battery does not inherently provide backup to a particular building or island safely. Those functions require the relevant system configuration, controls and approvals.
Development and approval workflow
- Establish site rights, metering boundaries and the proposed connection arrangement.
- Identify the applicable network operator, regulator and interconnection process.
- Obtain the required studies and evaluate connection limits, upgrades, costs and schedule dependencies.
- Confirm land, environmental, building and other project approvals.
- Align offtake, construction and financing assumptions with the actual energy and operating constraints.
- Complete required commissioning and obtain authorization for the permitted operation.
In the United States, FERC’s electric-jurisdiction overview describes its wholesale and transmission responsibilities and limits. The FTM label alone does not establish that every project needs the same federal approval or is governed by the same interconnection process. Determine the applicable authority and local requirements.
Use solar financial modeling to keep delivered-energy, contract and cost assumptions explicit. A preliminary layout or production estimate does not establish connection capacity, a queue outcome or lender acceptance.
Frequently asked questions
Does front-of-meter mean utility-scale?
No. The connection boundary and project scale are different attributes. Front-of-meter assets can connect to distribution as well as transmission networks.
Is exported rooftop energy automatically front-of-meter?
No. A system behind a customer’s consumption meter can export under an approved arrangement while remaining behind-the-meter.
Does FTM storage automatically earn multiple grid-service payments?
No. Eligibility, market rules, contracts and dispatch constraints determine which services can be provided and paid. Avoid double-counting incompatible commitments.
How long does an FTM project take to develop?
There is no universal duration. The connection process, studies, upgrades, permitting, procurement and project scope determine the schedule. Use current operator requirements and documented milestones.
Related Glossary Terms
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CEO & Co-Founder · SurgePV
Keyur Rakholiya is identified by SurgePV as its CEO and a company co-founder. His SurgePV author page lists only role information that can be tied to the public profile below; credentials, project totals, testing claims, media appearances, and speaking engagements are not asserted without retained evidence.
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