North Arkansas Electric Cooperative, Inc. (NAEC) Rate Selection Guide
North Arkansas Electric Cooperative (NAEC) serves roughly 39,000 members across eight Northern Arkansas counties with ~$85.4M in 2024 revenue. Today, data access is limited to a basic PDF billing portal and mobile app, but NAEC migrates to NISC SmartHub in August 2026 — bringing detailed usage data and likely Green Button Download capability for C&I energy teams.
Market Overview
NAEC is a member-owned distribution cooperative in Arkansas's regulated market, with rates and service overseen by the Arkansas Public Service Commission and wholesale power supplied through Arkansas Electric Cooperative Corporation (AECC). There is no retail supplier choice.
Need to pull your actual usage data to compare rates? See the North Arkansas Electric Cooperative, Inc. (NAEC) Data Access Guide →
Current Rate Schedules
NAEC implemented a 12.4% overall rate increase in April 2025 — a 9.4% retail adjustment from a Toth & Associates cost-of-service study plus a 3% wholesale pass-through from Arkansas Electric Cooperative Corporation (AECC), its power supplier. Rates are PSC-regulated and carry three bill adjustments: a Power Cost Adjustment tracking AECC wholesale costs, a Cost of Debt Adjustment, and tax adjustments. The structure is simple: Residential & Small Commercial (seasonal energy blocks, no demand charge), Large Power Service (seasonal demand billing), an optional coincident-peak Large Power rate, and load management credits.
Effective: April 1, 2025 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| Residential & Small Commercial | commercial | Homes and small commercial accounts across NAEC's eight-county northern Arkansas territory. | Daily distribution charge ($1.14 single-phase / $2.29 three-phase), energy at $0.12327/kWh in summer and on the first 500 winter kWh, dropping to $0.10255/kWh on excess winter kWh. Power Cost and Cost of Debt Adjustments apply per kWh. | $0.10255–$0.12327/kWh + adjustments |
| Large Power Service | commercial | Demand-metered commercial and industrial accounts. | Distribution charge of $6.00, seasonal demand charges of $13.33/kW (summer) and $11.30/kW (winter), and energy at $0.06739/kWh on all kWh, plus Power Cost and Cost of Debt Adjustments. | $0.06739/kWh + adjustments+ $13.33/kW summer; $11.30/kW winter |
| Large Power Service — Optional (Coincident Peak) | industrial | Large loads able to manage usage against the cooperative's/AECC's system coincident peak. | Distribution charge of $6.00, $2.00/kW on all kW demand plus $13.68/kW on coincident-peak kW, and $0.06739/kWh on all kWh. Rewards loads that avoid system peak hours. | $0.06739/kWh + adjustments+ $2.00/kW all demand + $13.68/kW coincident-peak demand |
| Off-Peak / Load Management Rates | commercial | Members accepting cooperative load control — off-peak service and credits for controlled air conditioning ($2.31/kVA, M1) and water heating ($4.12/unit, M2). | Off-peak customers may use power only when NAEC/AECC is not peaking; the cooperative may install radio-controlled load switches. Load management credits apply per controlled device. | — |
| Security & Street Lighting | commercial | Member security lights and municipal lighting. | Flat monthly charges per fixture based on 335 burning hours/month; Power Cost and Cost of Debt Adjustments assessed on calculated kWh. See rate schedule. | — |
Rate Recommendations by Use Case
Manufacturing and processing facilities
Demand-metered industrial loads take Large Power Service, where seasonal demand charges ($13.33 summer / $11.30 winter per kW) dominate the bill.
At $0.06739/kWh, LPS energy is roughly 45% cheaper than small commercial — the cost lives in the kW peak. Facilities that can manage load against AECC's system peak should evaluate the optional coincident-peak rate: paying $2.00/kW on all demand plus $13.68/kW only on coincident-peak kW can cut demand costs sharply for flexible operations.
- Model the optional coincident-peak rate using interval data — flexible loads often save 30%+ on demand charges
- Stagger motor starts and HVAC recovery to manage summer peaks, which bill $2/kW higher
- Track the Power Cost Adjustment line; it was rebased in May 2025 and moves with AECC wholesale costs
Small commercial — retail, offices, agricultural operations
Small businesses bill with residential-style seasonal energy blocks and no demand charge.
Winter excess energy ($0.10255/kWh) prices below summer/first-block rates ($0.12327/kWh), so summer efficiency delivers outsized savings. Growing accounts should compare against Large Power Service — the ~5.6¢/kWh energy discount can outweigh demand charges at high load factors.
- Prioritize cooling efficiency — every summer kWh costs $0.12327 plus adjustments
- Ask NAEC for a Large Power comparison once peaks regularly exceed ~20–30 kW
- Enroll eligible AC and water heating in load management for monthly credits
Flexible and curtailable loads
Operations that can shed or shift load during peaks can stack the off-peak rate, load management credits, and the coincident-peak option.
NAEC's rate design explicitly compensates flexibility: off-peak service restricts usage to non-peaking hours, load control credits pay per device, and the coincident-peak LPS rate shifts most demand cost onto a single managed window.
- Get AECC peak window patterns from NAEC to plan curtailment schedules
- Verify backup arrangements before accepting load control on critical equipment
- Combine credits with the coincident-peak rate where eligible for compounding savings
Cost Optimization Strategies
After the April 2025 12.4% increase, optimization matters more in NAEC territory. The levers: seasonal demand management (summer kW bills at a premium), the optional coincident-peak rate for flexible loads, load management credits, and careful tracking of the Power Cost and Cost of Debt Adjustments that float on every bill.
Summer peak demand management
For: Large Power Service accounts
Summer demand bills at $13.33/kW versus $11.30 winter. Pre-cool, stagger equipment starts, and schedule energy-intensive work outside afternoon peaks during summer months.
Coincident-peak rate election
For: Flexible industrial and irrigation loads
The optional LPS rate charges $2.00/kW on all demand but $13.68/kW only on coincident-peak kW — loads that avoid the AECC system peak window convert most of their demand cost into an avoidable charge.
Load management enrollment
For: Commercial accounts with eligible HVAC and water heating
Radio-controlled switches on air conditioning ($2.31/kVA credit) and water heating ($4.12/unit credit) earn monthly bill credits for allowing peak-period control.
Adjustment-aware bill auditing
For: All C&I accounts
Bills carry Power Cost, Cost of Debt, and tax adjustments per kWh; the PCA was rebased into rates in May 2025. Separate these riders from base charges when trending costs or verifying the rate increase impact.
Rate-class crossover analysis
For: Growing small commercial accounts
Small commercial pays up to $0.12327/kWh while Large Power pays $0.06739 plus demand. High-load-factor accounts near the threshold should request a comparison — roughly 200+ hours of use per kW of peak typically favors LPS.
To implement these strategies, you need your 15-minute interval data. Learn how to download North Arkansas Electric Cooperative, Inc. (NAEC) interval data →
Frequently Asked Questions
What changes when NAEC moves to SmartHub in August 2026?▾
Everything about data access improves: new account numbers, an enhanced bill with monthly usage graphs and temperature data, detailed usage data in the My Usage tab, a new mobile app, and likely Green Button Download My Data (a standard NISC SmartHub capability, pending NAEC confirmation). C&I teams should plan integrations around the migration and re-register accounts.
Can I get interval data from NAEC today?▾
Not reliably. NAEC hasn't published its AMI deployment status, and the current portal and app only show daily usage views with PDF bills. Confirm with NAEC at (870) 895-3221 whether your meter is interval-metered and at what granularity; raw exports aren't available until at least the SmartHub launch.
How does a consultant access an NAEC member's data?▾
Manually. The customer mails an authorization letter to NAEC (PO Box 1000, Salem, AR 72576) naming the third party, account number, scope, and duration. The consultant then submits the data request with a copy of the authorization. Expect 1-2 weeks, paper-based handling, and a possible retrieval charge — there is no API, aggregator program, or standardized form.
Does NAEC support EDI for commercial accounts?▾
Nothing is documented. No EDI specs, trading partner program, or contacts are published, which is typical for a 39,000-member co-op. The underlying NISC platform may have EDI capability, so large C&I customers should ask Business Services at (870) 895-3221 about 814/810/820/867 support, costs, and connection methods.
How should energy management platforms approach NAEC accounts?▾
NAEC is on Nectar's roadmap. Until SmartHub launches in August 2026, the workable path is customer-authorized PDF bill collection from the billing portal. Post-launch, check for Green Button Download (ESPI XML) and the Green Button Alliance directory for NAEC certification — that unlocks standardized usage ingestion. Re-map account numbers after migration.
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