Oklahoma Gas & Electric (OG&E) Rate Selection Guide
Oklahoma Gas & Electric (OG&E) is the largest electric utility in Oklahoma, serving roughly 903,000 customers across a 30,000-square-mile regulated territory in Oklahoma and western Arkansas. OG&E operates Advanced Metering Infrastructure (AMI) with 823,000+ smart meters but has not implemented Green Button or a public API, so C&I data access relies on its portal, the Energy Insights tool, and third-party aggregators.
Oklahoma Gas & Electric (OG&E) Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| GS - General Service | commercial | Customer charge + per-kWh energy (see tariff) | Smaller commercial accounts without significant demand |
| PL-1 (Secondary, SL5) | commercial | $91/mo + $16.87/kW summer ($8.87 winter) + 1.10c/kWh | Mid-size commercial loads metered at secondary voltage |
| PL-1 (Transmission, SL1) | industrial | $234/mo + $9.60/kW summer ($4.80 winter) + 0.60c/kWh | Large customers able to take transmission-level service |
| LPL-1 | industrial | $10.20/kW + 0.32c/kWh (70%+ load factor) | High-load-factor industrial operations |
Market Overview
OG&E is a vertically integrated, investor-owned utility regulated by the Oklahoma Corporation Commission (and the Arkansas PSC for its Arkansas territory). There is no competitive retail electricity market in Oklahoma; OG&E is the sole provider of generation, transmission, and distribution in its certified territory. Customers manage cost only through their choice of OG&E rate schedule and demand/load management.
Need to pull your actual usage data to compare rates? See the Oklahoma Gas & Electric (OG&E) Data Access Guide →
Current Rate Schedules
OG&E's C&I rates were reset effective January 1, 2025 under OCC Order No. 745601 (Case PUD 2023-000087), which approved roughly a $126.66M base-rate increase. Commercial and industrial schedules combine a fixed customer charge, seasonal demand (capacity) charges that differ between the five-month summer season (June-October) and seven-month winter season (November-May), and an energy charge, all of which vary by service-voltage level. A separate Fuel Cost Adjustment (FCA) rider is applied to the energy component.
Effective: January 1, 2025 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| GS - General Service | commercial | Small-to-medium commercial customers below the PL-1 demand thresholds. | Monthly customer charge plus an energy charge per kWh; designed for lower-demand commercial accounts. Customer charge was increased under the 2025 rate case. Exact GS figures should be confirmed in the OG&E tariff book (Sheet 6.30, GS-1). | — |
| GS-TOU - General Service Time-of-Use | commercial | Commercial customers electing time-of-use pricing. | Customer charge plus time-differentiated energy charges (on-peak/off-peak) to reward load shifting away from peak periods. See tariff Sheet 6.40. | — |
| PL-1 - Power and Light (Service Level 5, Secondary) | commercial | Commercial/industrial loads of ~10-400 kW (or 400+ kW under 15 GWh/yr), metered at secondary voltage (<2 kV). | Verified (eff. 1/1/2025): Customer charge $91.00/month; Summer Maximum Demand $16.87/kW; Winter Maximum Demand $8.87/kW; Energy 1.10 cents/kWh. Billing demand floored at 25% of prior 12-month peak; power-factor adjustment applies below 90%. | — |
| PL-1 - Power and Light (Service Level 4, Distribution) | commercial | PL-1 customers taking transformed distribution-voltage service. | Verified (eff. 1/1/2025): Customer charge $91.00/month; Summer Demand $12.46/kW; Winter Demand $6.23/kW; Energy 1.10 cents/kWh. | — |
| PL-1 - Power and Light (Service Level 1, Transmission) | industrial | PL-1 customers served by direct tap to transmission (>50 kV). | Verified (eff. 1/1/2025): Customer charge $234.00/month; Summer Demand $9.60/kW; Winter Demand $4.80/kW; Energy 0.60 cents/kWh. Lower energy/demand rates reflect transmission-level service. | — |
| LPL-1 - Large Power and Light | industrial | Large industrial customers with high load factor (70%+). | Verified (per OG&E LPL tariff Sheet 17.00): Maximum Billing Demand charge $10.20/kW per month with an energy charge of 0.32 cents/kWh; limited to consumers with a load factor of 70% or more. Confirm current sheet revision in the tariff book. | — |
| FP / DAP - Flex Pricing & Day Ahead Pricing | commercial | Business customers electing dynamic / market-indexed pricing. | Dynamic, market-indexed energy pricing (day-ahead) layered on demand and customer charges; managed via the Rate Tamer tool. Specific pricing varies daily; see tariff book and Rate Tamer. | — |
Rate Recommendations by Use Case
Mid-size commercial facility (office, retail, light industrial)
A facility with 10-400 kW peak demand on PL-1 should focus on managing summer peaks and verifying it is on the lowest-cost service level and rate.
Summer demand charges of $12.46-$16.87/kW dominate the bill; reducing peak kW and power-factor penalties drives the most savings.
- Track 15-minute interval data via Energy Insights or an aggregator
- Stagger HVAC/equipment startup to shave summer peaks
- Add power-factor correction to stay above 90%
Large industrial / continuous-process plant
High-load-factor industrial sites should evaluate LPL-1 and transmission-level service to minimize unit demand and energy costs.
LPL's $10.20/kW demand and 0.32c/kWh energy reward 70%+ load factor; transmission-level PL-1 cuts energy to 0.60c/kWh.
- Maintain high, steady load factor to qualify for LPL
- Pursue transmission/distribution-voltage service if feasible
- Use the Business Advantage Group to model rate options
Energy/sustainability team needing interval data for benchmarking
Since OG&E has no Green Button or public API, set up a Nectar feed to automate billing and 15-minute interval data collection.
Energy Insights is view-only and excludes large C&I; Nectar provides normalized billing and interval data via API with 3+ years of history (see docs.nectarclimate.com).
- Authorize Nectar for each OG&E account — docs.nectarclimate.com
- Confirm 15-minute interval availability for your meter
- Use account-representative access as a fallback
Multi-site C&I customer managing portfolio cost
Centralize data and rate analysis across sites, then prioritize peak-demand and power-factor projects at the highest-cost facilities.
Demand charges scale with each site's peak; portfolio-level visibility highlights where summer peak shaving and PF correction pay back fastest.
- Aggregate interval data via a single aggregator account
- Rank sites by summer demand cost per kW
- Sequence capital projects by payback
Historical Rate Trends
OG&E's most recent general rate case (PUD 2023-000087) reset base rates effective January 1, 2025. Interim rates had been in effect since July 1, 2024 and were affirmed by the OCC in early 2025.
January 1, 2025
New base rates took effect under OCC Order No. 745601 (Case PUD 2023-000087), reflecting an approximately $126.66M revenue increase; PL-1 and other C&I schedules updated to current charges.
+4.5%July 1, 2024
Interim rates implemented pending final OCC decision; later affirmed. Average residential bills rose about $12.65/month (~6.6% residential).
+6.6%Overall trend: Increasing - rates rose under the 2024-2025 rate case after OG&E sought recovery of higher capital and operating costs.
Next expected change: Periodic Fuel Cost Adjustment (FCA) rider updates apply between cases; the next base-rate change will follow OG&E's next general rate filing with the OCC.
Cost Optimization Strategies
Because OG&E C&I bills are dominated by seasonal demand charges and voltage-tiered rates, the largest savings levers for commercial and industrial customers are peak-demand management, summer load shifting, power-factor correction, and selecting the optimal rate schedule and service-voltage level.
Summer Peak Demand Management
For: PL-1 and LPL commercial/industrial customers
Demand (capacity) charges are roughly double in the summer season (June-October) versus winter. Staggering equipment startups, using battery or thermal storage, and curtailing on high-demand days reduces the 15-minute maximum demand that sets the capacity charge.
Power-Factor Correction
For: PL-1 customers (300+ kW have kVAr metering)
PL-1 applies a power-factor penalty when the average lagging power factor falls below 90%, inflating billing demand. Installing capacitor banks to maintain ~95%+ power factor avoids the penalty.
Service-Voltage Optimization
For: Large PL-1 / industrial customers
Both demand and energy rates decline at higher service-voltage levels (e.g., transmission SL1 energy is 0.60c/kWh vs. 1.10c/kWh at secondary SL5). Large facilities that can take service at distribution or transmission voltage may lower unit costs.
Rate Schedule Selection & Dynamic Pricing
For: All C&I customers
Evaluate PL-1 vs. GS-TOU vs. Flex/Day-Ahead Pricing against your load profile. High-load-factor sites may benefit from LPL; flexible loads may benefit from TOU or market-indexed pricing managed via Rate Tamer.
To implement these strategies, you need your 15-minute interval data. Learn how to download Oklahoma Gas & Electric (OG&E) interval data →
Frequently Asked Questions
Can a C&I customer get 15-minute interval data from OG&E in a usable file format?▾
Not directly. OG&E's AMI meters record interval data, but the utility exposes it only through the view-only Energy Insights tool and does not offer Green Button or CSV/ESPI export. To obtain machine-readable 15-minute interval data, most commercial customers authorize Nectar, which delivers normalized billing and interval data via API — see docs.nectarclimate.com.
How does a consultant or energy manager get authorized to access our OG&E account data?▾
OG&E uses a traditional account-representative / Power of Attorney model rather than a standardized API. The customer authorizes the third party (via POA or by adding them as an account representative) through the Business Advantage Group at 888-988-9747, after which the representative can view billing and usage through delegated portal access.
Does OG&E support EDI (814/867/810) for billing or meter data?▾
No. OG&E does not offer ANSI X12 EDI for customer billing or meter-data exchange. Because Oklahoma is a regulated, single-supplier market, there is no competitive-retailer EDI framework. Large customers with bulk data needs should contact the Business Advantage Group directly.
Which rate schedule applies to a mid-size commercial facility?▾
Facilities with a maximum demand of roughly 10-400 kW (or 400+ kW under 15 GWh/year) typically fall under the PL-1 Power and Light schedule, which has a customer charge, seasonal demand (capacity) charges, and an energy charge that vary by service voltage level. General Service (GS) applies to smaller commercial accounts, and large/high-load-factor industrial sites may qualify for LPL. Confirm eligibility with OG&E's Business Advantage Group.
Is interval data eligibility limited for some commercial customers?▾
Yes. Energy Insights is excluded for several segments, including Guaranteed Flat Bill, SmartHours Overnight, renewable-energy customers, large commercial/industrial rate plans, and oil & gas producers. Those customers should plan to use Nectar's API or an account-representative arrangement for usage data.
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