El Paso Electric Company Rate Selection Guide
El Paso Electric (EPE) is an investor-owned utility serving roughly 460,000 customers in West Texas and southern New Mexico. It offers strong programmatic data access through Green Button (CMD and DMD) via UtilityAPI, plus an Oracle Energy & Water integration for multi-account C&I customers.
El Paso Electric Company Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| Schedule No. 24 (Standard) | commercial | Customer $60.24/mo; Demand $14.25/kW summer (secondary); tiered energy from $0.06227/kWh | Mid-size C&I, 15-600 kW, with moderate load factor |
| Schedule No. 24 (Alt TOD) | commercial | On-Peak $0.16008/kWh summer; Off-Peak $0.01853/kWh; Demand $14.25/kW | C&I able to shift load off the noon-6pm summer peak; required >300 kW |
| Schedule No. 25 (Large Power) | industrial | Demand-based; voltage-differentiated (see filed sheet) | Large industrial loads >600 kW |
Market Overview
EPE's Texas retail rates are regulated by the PUCT and the City of El Paso. EPE operates outside ERCOT in the Western Interconnection, so there is no retail electric provider (REP) choice for C&I customers in its Texas service area; customers take bundled service under filed tariffs.
Need to pull your actual usage data to compare rates? See the El Paso Electric Company Data Access Guide →
Current Rate Schedules
EPE C&I customers in Texas take bundled, regulated service. Verified figures below are from EPE's filed Schedule No. 24 (General Service, Section 1 Sheet 12, effective for electricity consumed on and after November 3, 2021). Larger loads move to Schedule No. 25 (Large Power) and 25A. NOTE: The PUCT approved a base-rate increase for EPE on February 20, 2026 (≈14% for the average residential customer), with new rates taking effect May 2026; current C&I schedule amounts should be confirmed against the latest filed tariff sheets, as the figures shown predate that order. All bills are also subject to the Fixed Fuel Factor (Schedule No. 98) and other applicable riders.
Effective: November 3, 2021 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Schedule No. 24 — General Service (Standard) | commercial | C&I customers with highest measured demand greater than 15 kW and not exceeding 600 kW. Standard Rates closed to new customers with projected demand 300 kW or greater. | Customer Charge $60.24/meter/mo. Secondary-voltage Demand Charge $14.25/kW summer, $10.38/kW non-summer. Tiered energy: e.g., secondary first-200-hours $0.06227 summer / $0.04157 non-summer per kWh, declining for additional kWh. Primary and transmission voltages have lower charges. Billing demand is the highest of 15 kW, measured 30-minute peak, or 60% of prior summer (Jun-Sep) peak. (Eff. 2021-11-03; subject to 2026 rate-order update.) | — |
| Schedule No. 24 — General Service (Alternative Time-of-Day) | commercial | Mandatory for new C&I customers with projected demand over 300 kW; optional for others. | Customer Charge $60.24/meter/mo. Demand Charge same as Standard ($14.25/kW secondary summer). TOD energy: secondary On-Peak $0.16008/kWh summer, Off-Peak $0.01853/kWh summer and $0.03795/kWh non-summer. On-Peak period is 12:00 PM-6:00 PM MDT Mon-Fri, summer only. (Eff. 2021-11-03.) | — |
| Schedule No. 25 — Large Power Service | industrial | Large C&I customers whose highest measured 30-minute demand exceeds 600 kW for two consecutive months (minimum 12-month term on this schedule). | Demand-based large power tariff with customer, demand, and energy charges differentiated by delivery voltage. Specific current amounts are published in the filed Schedule No. 25 sheet; confirm against the latest tariff and the 2026 rate order. | — |
| Schedule No. 25A — Large Power Experimental Off-Peak | industrial | Large power customers electing the experimental off-peak option (load-factor based). | Experimental off-peak large power rate with on-peak/off-peak demand and energy differentiation. See filed Schedule 25A sheet for current amounts. | — |
| Schedule No. 98 — Fixed Fuel Factor | commercial | All bundled customers; applied on top of base schedules. | Pass-through fuel cost factor per kWh, adjusted periodically by the PUCT. Amount varies; see current fuel factor filing. | — |
Rate Recommendations by Use Case
Mid-size commercial facility (office, retail, light industrial; 15-300 kW)
Take Schedule 24 Standard and focus on trimming the summer peak that sets the demand ratchet.
Standard rates remain open below 300 kW and avoid the steep summer on-peak energy rate of the TOD option.
- Track 15-minute demand via Green Button
- Stagger HVAC and large equipment startups
- Pre-cool before the noon-6pm summer window
Large facility above 300 kW required on Time-of-Day
Engineer operations around the summer on-peak window and consider storage to clip on-peak demand and energy.
Summer on-peak energy (~$0.16/kWh) is roughly 8x off-peak, so load shifting and battery dispatch pay back quickly.
- Automate load curtailment 12-6pm MDT in summer
- Evaluate battery storage for on-peak clipping
- Maintain power factor ≥90% to avoid the adder
Multi-site / portfolio C&I customer
Use the Oracle Energy & Water + UtilityAPI integration to authorize all accounts at once and pull interval data programmatically.
Single authorization across accounts removes per-meter friction and feeds benchmarking and demand-management tools.
- Request the Oracle/UtilityAPI C&I integration
- Centralize interval data for portfolio peak analysis
- Benchmark sites to find demand-charge outliers
Energy consultant / aggregator serving EPE customers
Onboard via Green Button Connect My Data through UtilityAPI to retrieve authorized meter, bill, and 15-minute interval data.
EPE is Green Button Alliance certified; UtilityAPI provides a standard JSON API (Utility ID EPE) for scalable, multi-customer access.
- Register and validate in sandbox first
- Use Utility ID EPE in API calls
- Set 12-month+ authorization scope for trend analysis
Historical Rate Trends
EPE filed a base-rate case with the PUCT in January 2025 requesting roughly a 23% average residential increase (~$22/mo). On February 20, 2026 the PUCT approved a smaller increase — about 14% (~$13-14/mo) for the average Texas residential customer — reducing requested base-rate revenue by ~$60 million and setting return on equity at 9.4%. New rates take effect May 2026.
February 20, 2026
PUCT approved EPE base-rate increase of roughly 14% for the average Texas residential customer (less than the 23% requested); ROE set at 9.4%. New rates effective May 2026. C&I schedules adjusted accordingly.
+14%November 3, 2021
Effective date of the Schedule No. 24 General Service tariff figures cited on this page (Docket No. 46831 era rate framework).
n/aOverall trend: Rising — base rates increased following the 2026 PUCT order.
Next expected change: New base rates effective May 2026; fuel factor (Schedule 98) continues to adjust periodically.
Cost Optimization Strategies
Because EPE C&I bills are demand- and summer-peak-driven, the biggest savings come from managing peak kW and shifting load off the summer noon-6pm window.
Manage the summer demand ratchet
For: All Schedule 24/25 C&I customers
Under Schedule 24, billing demand can be set at 60% of the prior June-September peak. Reducing your summer peak lowers demand charges for the following 12 months.
Shift load off the summer on-peak window
For: Schedule 24 Alt TOD and >300 kW customers
On the Alternative TOD rate, summer on-peak energy is ~$0.16/kWh vs ~$0.019/kWh off-peak. Moving production or HVAC pre-cooling out of 12-6pm MDT cuts energy cost dramatically.
Correct power factor
For: Larger C&I (≥250 kW)
For demands ≥250 kW, a measured power factor below 90% lagging triggers a demand-charge adder. Installing capacitors avoids the penalty.
Use 15-minute interval data for verification
For: All AMI C&I customers
Pull AMI interval data via Green Button/UtilityAPI to validate demand intervals, detect anomalies, and target peak-shaving and storage dispatch.
To implement these strategies, you need your 15-minute interval data. Learn how to download El Paso Electric Company interval data →
Frequently Asked Questions
Can El Paso Electric C&I customers shop for a competitive electricity supplier?▾
No. EPE operates outside ERCOT in the Western Interconnection, and its Texas service area is not open to retail electric provider competition. C&I customers take bundled, PUCT-regulated service under EPE's filed tariff schedules.
Which rate schedule applies to my commercial or industrial facility?▾
Most C&I customers with demand between 15 kW and 600 kW take Schedule No. 24 (General Service). Loads over 600 kW move to Schedule No. 25 (Large Power). New loads over 300 kW must take the Alternative Time-of-Day option under Schedule 24.
How can a third-party consultant access our interval and billing data?▾
EPE is Green Button Alliance certified and supports Connect My Data through UtilityAPI. Consultants register at the EPE Green Button portal, test in sandbox, then send customers OAuth authorization links to pull 15-minute interval, bill, and meter data via the UtilityAPI JSON API (Utility ID EPE).
What is the best way to manage demand charges on EPE C&I rates?▾
Focus on the summer peak. Schedule 24 sets billing demand at the highest of 15 kW, your measured peak, or 60% of the prior June-September peak, so shaving the summer peak lowers demand charges for the following 12 months. Customers on TOD should also shift load off the noon-6pm summer on-peak window.
Did EPE rates change in 2026?▾
Yes. The PUCT approved an EPE base-rate increase on February 20, 2026 — about 14% for the average Texas residential customer, less than the 23% requested — with new rates effective May 2026. C&I schedule amounts were adjusted accordingly, so confirm current figures against the latest filed tariff sheets.
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