Georgia Net Metering Policy Explained

Georgia's net metering framework determines how residential and commercial solar customers are compensated for electricity exported to the grid — a question that directly affects the financial return on every grid-tied solar installation in the state. This page covers the policy structure, the mechanics of how credits are calculated and applied, the regulatory entities that govern the process, and the significant tensions between utility interests and ratepayer advocacy that shape the policy's ongoing evolution. Understanding the boundaries of Georgia's net metering rules is essential for interpreting interconnection agreements, utility billing statements, and the economic case for solar adoption.

• Definition and Scope
• Core Mechanics or Structure
• Causal Relationships or Drivers
• Classification Boundaries
• Tradeoffs and Tensions
• Common Misconceptions
• Checklist or Steps
• Reference Table or Matrix

Definition and scope

Net metering is a billing arrangement under which a utility customer with an on-site generation system — most commonly a photovoltaic solar array — receives a credit on their electricity bill for any kilowatt-hours (kWh) exported to the grid in excess of their own consumption during a billing period. The "net" refers to the difference between electricity drawn from the grid and electricity sent to it; the customer is billed only for that net consumption.

In Georgia, net metering does not operate under a single statewide statute that mandates uniform rules across all utilities. Instead, the Georgia Public Service Commission (PSC) regulates investor-owned utilities — principally Georgia Power, a subsidiary of Southern Company — while electric membership corporations (EMCs) and municipal utilities operate under their own boards and the oversight of the Georgia General Assembly. This fragmented structure means net metering terms vary substantially depending on which entity serves a given address.

Scope and coverage limitations: This page addresses net metering policy as it applies within the state of Georgia. Federal interconnection standards — particularly those established under the Federal Energy Regulatory Commission (FERC) and referenced in IEEE Standard 1547-2018 for distributed energy resource interconnection — set a floor for grid safety requirements but do not mandate specific compensation rates. Policies described here do not apply to solar installations in other states, do not constitute legal or financial advice, and do not cover off-grid systems that have no utility interconnection point. For off-grid configurations, see Off-Grid Solar Systems in Georgia. For a broader look at how solar systems interface with Georgia's grid infrastructure, the Regulatory Context for Georgia Solar Energy Systems provides foundational framing.

Core mechanics or structure

Under Georgia Power's net metering tariff (Rate NET, approved by the Georgia PSC), eligible customer-generators install a bidirectional meter that measures both energy imported from the grid and energy exported to it. At the end of each monthly billing cycle:

1. Consumption is measured — total kWh drawn from the grid during the month.
2. Export is measured — total kWh sent to the grid from the solar array.
3. Net position is calculated — if consumption exceeds export, the customer pays for net kWh at the applicable retail rate. If export exceeds consumption, a credit is generated.
4. Credit application — excess generation credits are applied to subsequent monthly bills. Under Georgia Power's current tariff structure, excess credits do not expire within the annual billing cycle but are subject to true-up rules at the program's annual reset date.
5. Credit valuation — critically, excess credits are valued at the avoided-cost rate rather than the full retail rate once monthly consumption has been offset. This distinction — retail rate for same-period offset, avoided-cost rate for surplus carried forward — is one of the most consequential structural features of Georgia's policy.

The avoided-cost rate in Georgia is set by the PSC and reflects what Georgia Power would pay to procure equivalent wholesale electricity. Historically, this rate has been substantially lower than the retail rate. For context on how the generation system interacts with this billing structure, How Georgia Solar Energy Systems Works: Conceptual Overview explains the physical flow of electrons from panel to meter to grid.

Georgia Power's net metering program has a capacity cap. Under the program rules approved by the PSC, the aggregate capacity of net metering systems is limited. Customers seeking interconnection should verify current availability through Georgia Power's interconnection queue, as capacity limits can affect program access. The Georgia Utility Interconnection Requirements page covers the technical interconnection process in detail.

Causal relationships or drivers

Several structural forces shape why Georgia's net metering policy takes its current form:

Regulatory jurisdiction structure. Because Georgia has not enacted a comprehensive statewide net metering statute applicable to all utility types, policy outcomes are driven by PSC proceedings for Georgia Power and by individual EMC governance for cooperative members. The Georgia Electric Membership Corporation solar policies — covered at Georgia Electric Membership Corporation Solar Policies — diverge significantly from Georgia Power's Rate NET in ways that affect roughly 4.4 million Georgians served by the state's 41 EMCs (Georgia EMC, member cooperative data).

Cost-shifting arguments. Utilities and some PSC filings have argued that net metering at full retail rates causes non-solar customers to subsidize grid infrastructure costs borne by solar adopters. This argument has driven the avoided-cost valuation for surplus credits rather than full retail compensation for all exported energy.

Avoided-cost methodology. The PSC periodically reviews avoided-cost calculations as part of Georgia Power's Integrated Resource Plan (IRP) proceedings. Changes to the IRP — which Georgia Power files approximately every 3 years — can alter the financial calculus for prospective solar adopters.

Solar technology cost trajectories. As solar hardware costs have declined — the National Renewable Energy Laboratory (NREL) tracks installed system cost benchmarks annually — the policy debate has shifted from access to compensation adequacy.

Classification boundaries

Georgia's net metering landscape divides along three primary axes:

By utility type:
- Investor-owned utility (IOU): Georgia Power customers access Rate NET under PSC jurisdiction.
- Electric membership corporations (EMCs): 41 cooperatives in Georgia set individual solar tariffs; policies range from robust buyback programs to avoided-cost-only compensation with no monthly credit rollover.
- Municipal utilities: Set policy independently; not subject to PSC net metering rulings.

By system size:
- Residential systems: Typically under 10 kilowatts (kW) DC capacity.
- Small commercial systems: Generally 10 kW to 100 kW.
- Large commercial/industrial: Above 100 kW; may face additional interconnection study requirements and different tariff schedules.

By interconnection type:
- Grid-tied systems: Eligible for net metering; subject to IEEE 1547-2018 anti-islanding and interconnection requirements.
- Battery-backed grid-tied systems: Eligible, but export from battery storage may be treated differently depending on utility tariff language.
- Off-grid systems: Not eligible for net metering by definition.

For a full classification of system types, Grid-Tied Solar Systems in Georgia and Solar Energy Storage and Battery Systems in Georgia address the boundary cases in detail.

Tradeoffs and tensions

Retail rate versus avoided cost. The central tension in Georgia's net metering policy is compensation valuation. Solar advocates, including the Southern Alliance for Clean Energy, have argued that retail-rate compensation better reflects the grid services — peak demand reduction, transmission deferral — that distributed solar provides. Utilities counter that retail rates include fixed-cost recovery components that solar customers would avoid paying if fully compensated at retail for all exports.

Capacity caps and access equity. Program capacity limits create a first-mover advantage: customers who interconnect before a cap is reached receive program access; later applicants may face different terms or waitlists. This structure has been criticized as inequitable across income levels, since early adopters tend to be higher-income households.

EMC policy fragmentation. The absence of a statewide mandate means a solar customer in one county may receive meaningfully different compensation than a customer five miles away served by a different cooperative. This fragmentation complicates financial modeling for developers and creates inconsistent incentives across the state.

Time-of-use rate interactions. As utilities move toward time-of-use (TOU) rate structures, the value of solar exports becomes dependent on the hour of export, not just the volume. A system that exports heavily at midday may receive a lower per-kWh credit under TOU pricing than under flat-rate billing, altering the economics significantly. Time-of-Use Rates and Solar Optimization in Georgia examines this dynamic in depth.

Grid modernization costs. Bidirectional power flows from high levels of distributed solar require grid upgrades — advanced metering infrastructure, distribution automation — whose costs utilities seek to recover through rate proceedings, creating ongoing tension in PSC dockets.

Common misconceptions

Misconception 1: Georgia has a universal statewide net metering law.
Georgia does not have a single statute requiring all utilities to offer net metering on standardized terms. Georgia Power's Rate NET exists under PSC authority; EMCs and municipal utilities are not obligated to match its terms.

Misconception 2: Excess solar production is credited at the full retail rate.
Georgia Power's tariff credits same-period consumption offset at the retail rate, but surplus exported beyond monthly consumption is credited at the avoided-cost rate — a figure substantially lower than the retail rate.

Misconception 3: Net metering credits never expire.
Credits do carry forward monthly, but terms governing annual true-up or credit expiration vary by utility. Customers should review the specific tariff language of their serving utility rather than assuming indefinite rollover.

Misconception 4: Battery storage automatically qualifies a system for net metering.
Battery-backed systems are grid-tied and generally qualify for interconnection, but whether battery-discharged energy exported to the grid qualifies for the same net metering credits as directly generated solar export depends on utility tariff language and metering configuration.

Misconception 5: Net metering eliminates the electricity bill.
Even customers who generate more electricity annually than they consume owe fixed monthly service charges, which are billed regardless of net generation position. These charges typically range from $10 to $25 per month depending on rate class and utility.

For a broader orientation to the solar ecosystem these policies govern, the Georgia Solar Energy Industry Overview and the main Georgia Solar Authority index provide context.

Checklist or steps

The following sequence describes the process a customer-generator typically moves through to access net metering under Georgia Power's Rate NET program. This is a descriptive framework, not installation or legal guidance.

Phase 1 — Pre-application
- [ ] Confirm the property is served by an eligible utility (Georgia Power for Rate NET; EMC or municipal customers must contact their utility directly)
- [ ] Determine proposed system size (kW DC) to identify applicable interconnection tier
- [ ] Review Georgia Power's current Rate NET tariff sheet via the PSC's official tariff database
- [ ] Assess roof or ground-mount suitability — see Solar Site Assessment and Shading Analysis in Georgia
- [ ] Confirm HOA rules where applicable — see Georgia HOA Rules and Solar Panel Rights

Phase 2 — Permitting and design
- [ ] Obtain required local building permits — see Permitting and Inspection Concepts for Georgia Solar Energy Systems
- [ ] Confirm system design complies with NEC Article 690 (photovoltaic systems) and IEEE 1547-2018
- [ ] Verify inverter equipment meets Georgia Power's interconnection technical requirements

Phase 3 — Interconnection application
- [ ] Submit Georgia Power's Interconnection Request (IR) form with system specifications
- [ ] Await application review — Georgia Power's standard review timeline for systems under 10 kW (Tier 1) is typically shorter than for larger systems requiring full interconnection studies
- [ ] Receive Permission to Operate (PTO) from Georgia Power

Phase 4 — Meter configuration and billing activation
- [ ] Confirm bidirectional meter installation by Georgia Power
- [ ] Verify first billing statement reflects net metering rate structure
- [ ] Review annual true-up terms in the Rate NET tariff to understand credit carry-forward rules

Reference table or matrix

Georgia Net Metering Policy Comparison by Utility Type

Key Rate and Policy Benchmarks

References

• Georgia Public Service Commission (PSC) — Tariff Database and Docket Records
• Georgia Power Rate NET Tariff — Filed with Georgia PSC
• Georgia EMC — Electric Membership Corporation Directory and Member Data
• IEEE Standard 1547-2018 — Standard for Interconnection and Interoperability of Distributed Energy Resources
• National Renewable Energy Laboratory (NREL) — U.S. Solar Photovoltaic System and Energy Storage Cost Benchmarks
• Federal Energy Regulatory Commission (FERC) — Order 2023, Small Generator Interconnection Procedures (18 C.F.R. Part 36)
• NFPA 70 — National Electrical Code, Article 690 (Photovoltaic Systems)
• Southern Alliance for Clean Energy — Georgia Solar Policy Resources
• Georgia General Assembly — O.C.G.A. Title 46 (Public Utilities and Public Transportation)