Georgia Power Company Rate Selection Guide
Georgia Power Company, a Southern Company subsidiary, is Georgia's largest electric utility serving over 2.8 million customers. For commercial and industrial accounts, it offers interval usage data via the EnergyDirect platform, EDI billing for high-volume customers, and a third-party authorization process for energy consultants. Large loads above 900 kW may exercise limited supplier choice under Georgia's Territorial Act.
Georgia Power Company Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| PLM-18 | Commercial (medium) | Basic $152/mo; energy-incl-demand 9.38-15.31¢/kWh (declining blocks); min demand $11.21/kW over 30 kW | Mid-size commercial loads 30-499 kW |
| PLL-18 | Industrial (large) | Basic $256/mo; energy-incl-demand 11.30-18.94¢/kWh (declining blocks); demand $13.63/kW | Large industrial loads 500 kW+ |
| RTP-DA-12 | Commercial/Industrial RTP | Hourly day-ahead marginal-cost prices vs CBL; admin $155-175/mo | Flexible 250 kW+ customers that can shift load to cheap hours |
| RTP-HA-12 | Commercial/Industrial RTP | Hourly hour-ahead marginal-cost prices vs CBL | Highly responsive 250 kW+ customers needing short-notice dispatch |
| TOU-SC-15 | Commercial/Industrial TOU | On-peak/off-peak energy + demand (see tariff) | Customers with predictable off-peak load shifting |
Market Overview
Georgia is a regulated electric market under the Georgia Public Service Commission. Georgia Power has an exclusive franchise territory under the Territorial Electric Service Act. The single exception is large-load choice: customers establishing a new load of 900 kW or more at a premises may choose their electric supplier.
Need to pull your actual usage data to compare rates? See the Georgia Power Company Data Access Guide →
Current Rate Schedules
Georgia Power Company is a fully regulated, vertically integrated utility serving most of Georgia under tariffs approved by the Georgia Public Service Commission (GA PSC). Commercial and industrial customers are segmented chiefly by demand: Power & Light Medium (PLM) for 30-499 kW, Power & Light Large (PLL) for 500 kW and above, plus time-of-use and Real Time Pricing (RTP) options. The PLM/PLL schedules use a combined energy-and-demand charge structure with steeply declining kWh blocks tied to hours-use of billing demand, a strong summer demand ratchet (95% summer / 60% winter), and an excess-kVAR power-factor charge. RTP (day-ahead and hour-ahead) bills hourly marginal-cost prices against a Customer Baseline Load for load-flexible customers 250 kW and above. Rate figures reflect the 2025 tariff filings effective under the 2022 GA PSC rate plan, which the PSC has frozen through at least 2028.
Effective: January 1, 2025 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Schedule PLM-18 - Power & Light Medium | Commercial (medium) | Customers with billing demand of not less than 30 kW but less than 500 kW, at one standard voltage and metering point. | Basic service charge plus a combined energy-and-demand charge: steeply declining kWh blocks for consumption up to 200 hours times billing demand, then very low tail-block rates beyond 200/400/600 hours-use. Strong summer demand ratchet (greatest of current demand, 95% of prior summer peak, or 60% of prior winter peak). Excess-kVAR charge applies below 95% power factor. | Basic Service Charge $152.00/mo. Energy-incl-demand (first 200 hrs x demand): first 3,000 kWh 15.3054¢/kWh, next 7,000 kWh 14.0178¢/kWh, next 190,000 kWh 12.0861¢/kWh, over 200,000 kWh 9.3761¢/kWh; tail blocks 1.5555¢ / 1.1705¢ / 1.0177¢ per kWh. (Eff. Jan 2025; excludes fuel, ECCR, DSM, franchise riders.)+ Minimum-bill demand component $11.21 per kW of billing demand in excess of 30 kW; excess reactive demand billed $0.42 per excess kVAR. |
| Schedule PLL-18 - Power & Light Large | Industrial (large) | Customers with billing demand of 500 kW or greater. Loads with expected total peak demand of 100 MW or greater may take service only if contracted prior to Feb 1, 2025. | Same combined energy-and-demand block structure as PLM but with higher per-kWh block rates and a higher demand charge. Same 95% summer / 60% winter demand ratchet and excess-kVAR provision. Five-year contract term. | Basic Service Charge $256.00/mo. Energy-incl-demand (first 200 hrs x demand): first 3,000 kWh 18.9430¢/kWh, next 7,000 kWh 17.1794¢/kWh, next 190,000 kWh 14.6526¢/kWh, over 200,000 kWh 11.2968¢/kWh; tail blocks 1.9458¢ / 1.4671¢ / 1.1010¢ per kWh. (Eff. Apr 2025; excludes riders.)+ Minimum-bill demand component $13.63 per kW of billing demand; excess reactive demand billed $0.42 per excess kVAR. |
| Real Time Pricing - Day Ahead (RTP-DA-12) | Commercial/Industrial RTP | New and existing C&I customers able to respond to hourly price signals and maintaining a peak 30-minute demand of at least 250 kW each month. | Customer pays a revenue-neutral Standard Bill on its Customer Baseline Load (CBL) under the applicable firm tariff, plus (or minus) hourly day-ahead marginal-cost prices applied to deviations from the CBL. Hourly prices published by 4 p.m. for the next day. Optional interruptibility via the Demand Plus Energy Credit rider. | Hourly prices set daily from incremental generation, transmission, reliability-capacity costs plus a 3 mill/kWh recovery factor; not a fixed published rate. Standard Bill follows the customer's underlying firm tariff (e.g., PLM/PLL).+ No separate published demand rate; demand recovered through the CBL Standard Bill. Administrative Charge $155/mo (over 1,000 kW) or $175/mo (under 1,000 kW); excess kVAR $0.42. |
| Real Time Pricing - Hour Ahead (RTP-HA-12) | Commercial/Industrial RTP | C&I customers (similar 250 kW minimum) preferring hour-ahead price signals for finer-grained dispatch of flexible load. | Same CBL-based revenue-neutral design as RTP-DA but with hour-ahead marginal-cost prices, giving customers shorter-notice price response. Standard Bill plus hourly deviation charges/credits. | Hourly hour-ahead marginal-cost prices; not a fixed published rate. See tariff for administrative charges and methodology.+ Demand recovered through CBL Standard Bill; administrative charge and excess-kVAR provisions per tariff. |
| Time of Use - Supplier Choice (TOU-SC-15) | Commercial/Industrial TOU | Qualifying C&I customers electing time-of-use pricing with on-peak / off-peak periods. | Time-differentiated energy with on-peak and off-peak periods and a demand component; designed to reward shifting load out of summer on-peak hours. Specific period definitions and $ rates per the TOU-SC-15 tariff. | Time-of-use energy and demand $ values per the GA PSC tariff filing; not reproduced here to avoid asserting unverified figures.+ Demand charge plus TOU energy per tariff; excess-kVAR provisions apply. |
Rate Recommendations by Use Case
Multi-site C&I energy management
Centralize interval and billing data across all facilities for cost tracking and reporting.
EnergyDirect consolidates multi-site accounts and exports interval data, while the third-party authorization form lets consultants pull 12 months of billing history.
- Register all sites in EnergyDirect and link accounts
- Export hourly data to Excel for demand analysis
- Use the third-party form for consultant access
Peak demand reduction
Identify and shave monthly demand peaks driving demand charges.
Demand charges are a major C&I cost; interval data reveals when peaks occur so equipment can be staggered.
- Pull hourly interval data to map peak windows
- Stagger startups of large equipment
- Consider battery storage for peak shaving
Large flexible load on hourly pricing
Expose curtailable load to hourly market prices for savings.
RTP rewards loads that can curtail during high-price hours relative to a customer baseline.
- Model historical RTP prices against your load shape
- Automate curtailment of non-critical loads
- Compare RTP against standard PLL demand rates
Building benchmarking & ESG reporting
Aggregate building energy data for ENERGY STAR scoring and sustainability disclosures.
The Automated Benchmarking Tool produces Portfolio Manager-ready data for multi-tenant buildings.
- Use ABT auto-aggregation for buildings with 5+ tenants
- Collect tenant consents early when required
- Upload aggregated data to ENERGY STAR Portfolio Manager
New large load siting (>=900 kW)
Evaluate supplier choice for a new large load under Georgia's Territorial Act.
New loads of 900 kW or more at a premises may select Georgia Power, an EMC, or a municipal supplier — the only large-customer choice in Georgia.
- Confirm the load qualifies as a new >=900 kW premises load
- Solicit offers from eligible suppliers
- Weigh rate offers against service reliability
Historical Rate Trends
Georgia Power's current C&I tariff levels stem from the 2022 Alternate Rate Plan approved by the GA PSC on December 20, 2022, which phased base-rate increases through 2023, 2024, and 2025. In 2025 the company and PSC staff stipulated to freeze base rates rather than file a new rate case. Bills can still move via fuel, environmental, and storm-cost recovery riders even while base rates are frozen.
December 20, 2022
GA PSC approved the 2022 Alternate Rate Plan, phasing base-rate increases in over 2023, 2024, and 2025 (the source of current PLM/PLL levels).
Phased over 3 years (2023-2025); class-specificApril 1, 2025
PLL-18 first revision took effect (April 2025 billing month) with the schedule's current energy blocks and $13.63/kW demand charge; PLM-18 original took effect January 2025.
Tariff revision under existing planJuly 1, 2025
GA PSC approved a stipulated plan to freeze Georgia Power base rates through at least 2028; Georgia Power did not file an expected 2025 rate case. Storm costs to be addressed separately.
Base-rate freeze (0% base increase through 2028)Overall trend: stable
Next expected change: On July 1, 2025 the GA PSC approved freezing Georgia Power base rates through at least 2028; no 2025 base-rate case was filed. The next base-rate change is not expected before 2028, though fuel cost recovery, environmental, and storm-cost rider proceedings can adjust bills in the interim.
Cost Optimization Strategies
Because PLM/PLL bills are dominated by billing demand (locked in by a 95% summer / 60% winter ratchet) and steeply declining energy blocks, the largest savings come from shaving summer peak demand, improving power factor, choosing the right schedule, and exploiting RTP for load-flexible operations.
Shave the summer peak demand
For: PLM-18, PLL-18
The 95% summer ratchet means a single high-demand 30-minute interval in June-September sets billing demand for up to a year. Aggressive summer peak management (load staggering, battery storage, curtailment) directly lowers the demand-driven minimum bill.
Correct power factor above 95%
For: PLM-18, PLL-18, RTP
Maintaining power factor at or above 95% lagging avoids the excess reactive demand charge of $0.42 per excess kVAR (billed on kVAR above one-third of measured kW).
Confirm correct PLM vs PLL placement
For: PLM-18, PLL-18
The 500 kW threshold separates PLM and PLL, which have materially different block rates and demand charges. Customers near the boundary should verify they are on the lower-cost applicable schedule given their load profile.
Use Real Time Pricing for flexible load
For: RTP-DA-12, RTP-HA-12
Customers 250 kW+ that can shift or curtail load can adopt RTP-DA or RTP-HA and buy incremental energy at hourly marginal cost, saving when they reduce usage below their CBL in expensive hours (and on the hourly recovery factor of 3 mills/kWh).
Push usage into low-cost energy tail blocks
For: PLM-18, PLL-18
Energy is priced in steeply declining blocks tied to hours-use of demand; high-load-factor operation pushes more kWh into the deeply discounted tail blocks (about 1¢/kWh beyond 600 hours-use), lowering the average energy rate.
To implement these strategies, you need your 15-minute interval data. Learn how to download Georgia Power Company interval data →
Frequently Asked Questions
How do commercial customers get interval data from Georgia Power?▾
Register on EnergyDirect (https://www.energydirect.com/) using your account number and Web Access Code. EnergyDirect provides daily and hourly interval usage, multi-site consolidation, and exports to Excel, CSV, and PDF. Premium Real-Time data is available by subscription for near-real-time usage.
Does Georgia Power support Green Button?▾
No. Georgia Power does not offer consumer-facing Green Button Download My Data or Connect My Data. Equivalent interval data is available via My Power Usage (residential) and EnergyDirect (commercial), and the utility follows ESPI standards only in backend systems.
How can an energy consultant access my account data?▾
Use the Release of Billing History to Third Party form (https://customerservice2.southerncompany.com/LettersForms/Form/TPR). The customer signs to authorize up to 12 months of billing history for one request per 12-month period. Alternatively, share EnergyDirect credentials or authorize an aggregator.
Does Georgia Power offer EDI for business billing?▾
Yes. Georgia Power supports ANSI X12 EDI with 810 (invoice), 820 (payment/remittance), and 997 (acknowledgement) transaction sets via VAN or direct connection. Contact edisupp@southernco.com or 1-888-655-5888 to enroll.
Can I choose a different electricity supplier in Georgia?▾
Generally no — Georgia is a regulated market with exclusive territories under the Territorial Electric Service Act. The only exception is that a new load of 900 kW or more at a single premises may select its electric supplier.
Is there an official API for Georgia Power usage data?▾
Not yet. Southern Company is developing the Energy Information eXchange (EIX) API platform for approved partners. An unofficial community GitHub library exists but scrapes the portal and carries terms-of-service risk; it is not recommended for business use.
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