Fayetteville Public Works Commission (PWC) Rate Selection Guide
Fayetteville Public Works Commission (PWC) is North Carolina's largest municipal electric utility, serving roughly 85,000 electric accounts plus water and wastewater in Fayetteville and Cumberland County. PWC is mid-way through a 182,000-meter AMI rollout (2024-2027) with 15-minute interval capability, but offers no Green Button or public API; third-party access is via authorized-representative portal accounts or manual data requests.
Fayetteville Public Works Commission (PWC) Rate Schedule Comparison
| Schedule | Type | Rate | Best For |
|---|---|---|---|
| R.B.2 Small Power Service | Commercial (small) | $0.15560 on-peak / $0.10300 off-peak per kWh; $38-$56/mo BFC; no demand charge | Small commercial sites under 30 kW |
| R.B.3 Medium Power Service | Commercial demand | $17.99/kW demand; energy $0.06495 on-peak / $0.04890 off-peak | Mid-size commercial loads 30-1,000 kW |
| R.B.32 Large General Service | Industrial demand | $6.05/kW customer-peak + CP demand (~$16.92/kW) + $0.04840/kWh | Large industrial loads over 1,000 kW |
| R.B.34 / R.B.6 | Large / transmission | CP-based large-load pricing (see tariff) | Loads over 5 MW or transmission-owning customers |
Market Overview
PWC is a municipal utility with charter authority to set its own electric, water, and wastewater rates after a public hearing and Board approval. It buys wholesale power from Duke Energy Progress under a Power Supply Coordination Agreement. Customers cannot choose a competitive supplier.
Need to pull your actual usage data to compare rates? See the Fayetteville Public Works Commission (PWC) Data Access Guide →
Current Rate Schedules
PWC's non-residential electric rates are effective May 1, 2026, and were adopted February 25, 2026. C&I classes are demand-tiered: Small Power Service (=30 kW), Medium Power Service (>30 to 1,000 kW), and Large General Service (>1,000 kW), with a Greater-than-5MW class and transmission-owning options. All rates are subject to a monthly Power Supply Adjustment (PSA) tied to Duke Energy Progress costs.
Effective: May 1, 2026 · Full Tariff Book →
| Schedule | Type | Applicability | Structure | Rate |
|---|---|---|---|---|
| R.B.2 Small Power Service (SPS) | commercial | Nonresidential service where the lower of contract or metered demand is =30 kW (may be moved to Medium if demand exceeds 35 kW twice or 50 kW once in 12 months). | Basic Facilities Charge $38.00/mo single-phase, $56.00/mo three-phase (+$4.00 Community Street Lighting per meter). Energy: on-peak $0.15560/kWh, off-peak $0.10300/kWh. No demand charge. Subject to PSA. | — |
| R.B.3 Medium Power Service (MPS) | commercial | Nonresidential service where demand exceeds 30 kW but not 1,000 kW (more than twice/yr). | Basic Facilities Charge $46.50/mo single-phase, $65.00/mo three-phase (+$4.00 Community Street Lighting). Energy: on-peak $0.06495/kWh, off-peak $0.04890/kWh. Demand: $17.99 per kW Customer Peak Demand. Subject to PSA. | — |
| R.B.32 Large General Service (LGS) | industrial | Nonresidential service with contract demand >1,000 kW, or metered demand >1,000 kW in 3+ months/yr (to 5,000 kW). | Basic Facilities Charge $348.00/mo (+$4.00 Community Street Lighting). Energy: $0.04840/kWh. Demand: Customer Peak Demand $6.05/kW plus a formula-based CP Demand charge (illustrative $16.92/kW). Primary discount $0.90/kW if served at 7,200 V+. Subject to PSA. | — |
| R.B.34 Large General Service Greater than 5MW | industrial | Nonresidential customers exceeding 5,000 kW (5 MW) of demand at least three times in a calendar year. | Large-load schedule with Basic Facilities Charge, energy charge, and a coincident-peak (CP) plus customer-peak demand structure tied to Duke Energy Progress wholesale costs. See tariff for current values; subject to PSA. | — |
| R.B.27 Small Power Service Whole Business (Optional TOU) | commercial | Optional time-of-use rate for Small Power Service nonresidential customers willing to manage on-peak usage. | Optional whole-business TOU rate with on-peak/off-peak energy pricing designed to reward shifting load out of peak windows. See tariff for current values; subject to PSA. | — |
| R.B.6 Large Power Service Owning Transmission | industrial | Large customers owning transmission facilities (closed - not open to new customers). | Transmission-level large power schedule for customers owning transmission; closed to new customers. See tariff for current values; subject to PSA. | — |
Rate Recommendations by Use Case
Small commercial site under 30 kW
Small offices and retail under 30 kW take R.B.2 Small Power Service, an energy-only rate with no demand charge but a high on-peak energy price.
With no demand charge, the lever is on-peak energy at $0.15560/kWh versus $0.10300 off-peak, so load shifting matters most.
- Shift discretionary load out of 3-6 PM summer / 6-9 AM winter
- Watch demand to avoid being reclassified to Medium Power
- Evaluate the optional R.B.27 whole-business TOU rate
Mid-size commercial / light industrial (30-1,000 kW)
Facilities between 30 and 1,000 kW take R.B.3 Medium Power Service, where the $17.99/kW demand charge dominates the bill.
Lower energy rates ($0.06495/$0.04890) come with a substantial demand charge, so peak management drives savings.
- Track and shave the monthly 15-minute peak demand
- Stagger startups and consider battery/peak-shaving
- Request interval data to identify peak drivers
Large industrial customer over 1,000 kW
Loads above 1,000 kW take R.B.32 Large General Service, which adds a Duke Energy Progress coincident-peak (CP) demand charge.
The CP demand component (illustratively ~$16.92/kW) rewards curtailing during the system peak, and a $0.90/kW primary discount applies at 7,200 V+.
- Identify and curtail during DEP system peak hours
- Take primary voltage to capture the $0.90/kW discount
- Model interruptible-load options for very large sites
Consultant or energy manager onboarding a PWC account
With no API or Green Button, use the authorized-representative model and plan for manual interval-data requests.
PWC grants third parties the same portal access as the customer once invited; granular 15-minute data still requires a manual request.
- Have the customer add you as an authorized user in the eportal
- Request granular interval CSV/Excel via customer.service@faypwc.com
- Allow 5-10 business days and budget for a possible fee
Historical Rate Trends
PWC reviews rates annually with a public hearing before Board adoption. The current non-residential rates were adopted February 25, 2026, effective May 1, 2026, with a further set adopted for May 1, 2027. PWC stated a roughly 4% increase phased over two years.
May 1, 2026
Non-residential electric rates effective May 1, 2026 (adopted Feb 25, 2026); ~1,000 kWh residential bill up about $8.02.
~4% over two yearsMay 1, 2027
Adopted non-residential electric rates effective May 1, 2027; ~1,000 kWh residential bill up about $8.59.
Part of ~4% two-year planOverall trend: Rising modestly with wholesale power, capital investment, and inflation; a customer using 1,000 kWh sees about an $8.02 increase in May 2026 and $8.59 in May 2027. PWC remains among the lowest-cost providers in the region.
Next expected change: Adopted non-residential electric rates effective May 1, 2027 are already published.
Cost Optimization Strategies
PWC is a regulated municipal with no supplier choice, so C&I optimization centers on rate-class selection, demand (and coincident-peak) management, and TOU load shifting.
Manage Customer Peak Demand
For: R.B.3 Medium Power Service customers
Medium Power Service bills $17.99/kW on the highest 15-minute demand. Staggering equipment and peak shaving directly reduce this charge.
Target the coincident peak (CP) on Large General Service
For: R.B.32 Large General Service customers
On R.B.32, a CP demand charge is tied to PWC's coincident peak with Duke Energy Progress. Curtailing during the DEP system peak hour reduces the CP demand component.
Shift load with non-residential TOU
For: Small/Medium Power Service with shiftable load
Moving consumption out of on-peak windows (summer 3-6 PM, winter 6-9 AM) cuts on-peak energy cost, especially on Small Power Service where on-peak energy is $0.15560/kWh vs $0.10300 off-peak.
Capture the primary voltage discount
For: R.B.32 customers able to take primary voltage
Large General Service customers taking service at 7,200 V or higher and owning their equipment receive a $0.90/kW reduction on the Customer Peak Demand charge.
To implement these strategies, you need your 15-minute interval data. Learn how to download Fayetteville Public Works Commission (PWC) interval data →
Frequently Asked Questions
Can a consultant access our PWC usage data without our login?▾
Yes, through authorization. The cleanest path is to add the consultant as an authorized representative in the eportal, giving them the same data access as the account holder. Alternatively, submit a signed Power of Attorney or service agreement to customer.service@faypwc.com. Sharing your own login is discouraged.
How do we get granular 15-minute interval data for our facility?▾
PWC's advanced meters capture 15-minute data, but it is not downloadable from the portal. Email customer.service@faypwc.com (or call (910) 483-1382) with the account number, date range, and preferred format (CSV/Excel). Expect 5-10 business days; a fee may apply for large requests.
Which rate schedule applies to a commercial or industrial site?▾
It depends on demand: R.B.2 Small Power Service (=30 kW), R.B.3 Medium Power Service (>30 kW to 1,000 kW), and R.B.32 Large General Service (>1,000 kW). Sites above 5 MW move to R.B.34, and large customers fed directly from transmission may take a transmission-owning schedule.
Does PWC support Green Button or a public API?▾
No. PWC has neither Green Button nor a public developer API. Its systems (Oracle Utilities CC&B, Apogee) have internal APIs that are not externally exposed. Green Button could be added after the AMI rollout completes in 2027, but is not available today.
Can we shop for a competitive electricity supplier?▾
No. North Carolina has no retail choice, and PWC is the sole municipal provider in its territory, purchasing wholesale power from Duke Energy Progress. C&I cost optimization is achieved through rate-schedule selection, demand management, and TOU load shifting.
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