Satilla Rural Electric Membership Corporation Rate Selection Guide
Satilla REMC is a member-owned electric cooperative serving roughly 59,500 members across nine counties in Southeast Georgia. Data access runs through a SmartHub-style online billing portal and mobile app; the cooperative has no published Green Button, API, or EDI program, so third-party access is handled case-by-case with customer authorization.
Satilla Rural Electric Membership Corporation Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| Schedule 2 - Commercial | Commercial | $32.50/mo + 10.8¢/kWh (+ MAF) | Small commercial sites under 50 kVA |
| Schedule 3 - Large Power | Commercial/Industrial | $75/mo + $6.25/kW + tiered 9.4/7.3/6.7¢/kWh (+ MAF) | Demand-metered C&I over 50 kVA |
| Schedule 10 - Industrial & Large Gov't | Industrial | $350/mo + $4.00/$1.50/$1.35 per kW + 4.5¢/kWh (+ MAF) | Large facilities 900 kW+ |
| Schedule 7 - Large Industrial | Industrial | $1,000/mo + $4.00 & $1.55 per kW + scheduling/retail riders | Very large loads 25 MW+ (contract) |
Market Overview
Georgia operates under the Territorial Electric Service Act; retail customers cannot choose their supplier. Satilla REMC is the exclusive provider in its certificated nine-county territory and is self-governed by a member-elected board, filing public disclosure rate documents with the Georgia PSC.
Need to pull your actual usage data to compare rates? See the Satilla Rural Electric Membership Corporation Data Access Guide →
Current Rate Schedules
Verified from Satilla REMC's Public Disclosure Document filed with the Georgia PSC (effective for billings on or after April 1, 2022). All schedules are subject to the Monthly Adjustment provision (Schedule MAF) for wholesale power-cost changes. Net rates shown; gross rates are ~10% higher if unpaid within 15 days.
Effective: April 1, 2022 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Schedule 2 - Commercial Service | commercial | Commercial/industrial loads requiring 50 kVA or less transformer capacity. | Service Charge $32.50/month; Energy Charge 10.8¢ per kWh. Minimum = service charge (multi-phase: $1.25/kVA of installed transformer capacity). Subject to Schedule MAF. | — |
| Schedule 3 - Large Power Service | commercial | Consumers requiring more than 50 kVA of transformer capacity (demand-metered). | Service Charge $75.00/month; Demand Charge $6.25 per kW of billing demand; Energy: first 200 kWh/kW @ 9.4¢, next 200 kWh/kW @ 7.3¢, over 400 kWh/kW @ 6.7¢. Billing demand based on highest 30-minute kW (with seasonal ratchet). Subject to Schedule MAF. | — |
| Schedule 10 - Industrial & Large Governmental Service | industrial | Industrial/commercial/governmental consumers with connected load 900 kW or greater (initial hourly demand under 5,000 kW); written agreement required. | Service Charge $350.00/month; Power Production Demand $4.00/kW; Transmission Demand $1.50/kW; Non-Coincident Peak (NCP) Demand $1.35/kW; Energy 4.5¢ per kWh; plus GTC transmission facilities charges. Subject to Schedule MAF. | — |
| Schedule 7 - Large Industrial Power Service | industrial | Large industrial consumers with connected load of at least 25 MW under a written Agreement for Electric Service. | Monthly Service Charge $1,000.00; Power Production Demand $4.00/kW; Transmission Service Charge $1.55/kW; Energy Scheduling Charge $0.0005/kWh; Retail Service Charge $0.0011/kWh; contract energy charged per wholesale provider term sheets. | — |
Rate Recommendations by Use Case
Mid-size commercial facility (retail, office, light industrial)
Sites over 50 kVA should be on Schedule 3 and focus on demand control.
The $6.25/kW demand charge plus a 30-minute ratchet means a single uncontrolled peak inflates bills for months; the tiered energy design rewards steady load.
- Track 30-minute demand and stagger HVAC/equipment startups.
- Pursue high load factor to reach the 7.3¢ and 6.7¢ energy tiers.
- Budget for the MAF power-cost rider separately.
Large industrial / institutional load (900 kW+)
Qualify for Schedule 10 and manage coincident peaks against GTC system peaks.
Power Production ($4.00/kW) and Transmission ($1.50/kW) demand are set by demand coincident with GTC's five highest 60-minute peaks, so coincident-peak avoidance is the dominant cost lever.
- Subscribe to GTC Peak Period Notification alerts and curtail during those hours.
- Separate NCP management ($1.35/kW) from coincident-peak management.
- Negotiate the written service agreement terms and metering point.
Energy manager needing usage data for analytics
Plan for a manual, authorization-driven data workflow.
With no Green Button, API, or EDI, Satilla data must be pulled from the portal (daily/monthly summaries) or requested manually; interval data is not guaranteed.
- Pull monthly bill PDFs and payment history from the portal per account.
- Submit a written request for interval/CSV exports via (912) 632-7222.
- Maintain customer authorizations on file for any third-party access.
Very large new load (data center / 25 MW+)
Engage early on a Schedule 7 written agreement.
Loads at/above 25 MW are served only under a negotiated Agreement for Electric Service with contract energy priced off wholesale term sheets; terms, metering, and delivery point are bespoke.
- Open discussions with Satilla and Georgia Transmission Corporation early.
- Model scheduling ($0.0005/kWh) and retail ($0.0011/kWh) riders plus $4.00/$1.55 per-kW demand.
- Clarify standby/parallel-operation terms in the agreement.
Historical Rate Trends
Satilla's base schedules in the Georgia PSC public disclosure document are effective for billings on or after April 1, 2022. Month-to-month bill variation is driven primarily by the Monthly Adjustment (MAF) wholesale power-cost rider rather than frequent base-rate changes.
April 1, 2022
Current base rate schedules (Schedules 1-10) became effective for billings on or after this date per the Georgia PSC public disclosure document.
n/aOverall trend: Base rates stable since 2022; effective rates fluctuate with the MAF power-cost adjustment.
Next expected change: Not publicly scheduled; monitor Georgia PSC filings and cooperative board actions.
Cost Optimization Strategies
For Satilla C&I accounts the biggest levers are demand management on Schedules 3/10 and load-factor improvement, since energy tiers and demand charges dominate the bill. The MAF rider cannot be avoided but can be modeled into budgets.
Demand (peak kW) management
For: Schedule 3, 10
Stagger equipment startups and shave coincident peaks to lower billing demand; on Schedule 3 the highest 30-minute kW (with ratchet) drives both the $6.25/kW charge and the energy tier breakpoints.
Improve load factor
For: Schedule 3
Higher, steadier utilization pushes more kWh into Schedule 3's lower 7.3¢ and 6.7¢ tiers (priced per kW of demand), cutting blended energy cost.
Right-size the rate schedule
For: All C&I
Confirm placement matches transformer capacity / connected load (50 kVA, 900 kW, 25 MW thresholds). A mis-classified account can overpay on fixed and demand components.
Coincident-peak avoidance (GTC peak hours)
For: Schedule 10, 7
On Schedules 10/7, Power Production and Transmission demand are set by demand coincident with GTC's five highest 60-minute system peaks; curtailing during Peak Period Notification Hours reduces these charges for the year.
To implement these strategies, you need your 15-minute interval data. Learn how to download Satilla Rural Electric Membership Corporation interval data →
Frequently Asked Questions
Can a C&I customer get 15-minute interval data from Satilla REMC?▾
Not through self-service. The portal shows daily/monthly usage summaries only. Interval data, if available for a metered site, must be requested directly from customer service at (912) 632-7222 and is provided manually (often PDF/CSV/email). Treat availability as case-by-case.
Does Satilla offer Green Button, an API, or EDI for energy managers?▾
No. There is no Green Button (DMD or CMD), no public API or developer portal, and no published EDI/trading-partner program. All programmatic-style access is handled as manual, authorized data requests.
How does a third-party consultant or aggregator obtain a client's Satilla data?▾
Obtain signed written authorization from the account holder (account number, service address, data scope, term), then submit a request on letterhead to customer service. The cooperative may charge a records-request fee and deliver data in PDF or email; bulk/automated access is not currently supported.
Which rate schedules apply to commercial and industrial accounts?▾
Schedule 2 (Commercial, up to 50 kVA), Schedule 3 (Large Power, over 50 kVA, demand-metered), Schedule 10 (Industrial & Large Governmental, 900 kW+), and Schedule 7 (Large Industrial, 25 MW+ under written agreement). Verified figures appear in the rate sections below.
Is there a power-cost adjustment on Satilla bills?▾
Yes. All schedules are subject to the cooperative's Monthly Adjustment provision (Schedule MAF), which increases or decreases the rate based on wholesale power-supply cost changes. Budget for this variable rider on top of the base energy and demand charges.
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